SECURITIES AND EXCHANGE COMMISSION

FORM 10-Q Quarterly report pursuant to sections 13 or 15(d)

Filing Date: 2019-10-24 | Period of Report: 2019-09-30 SEC Accession No. 0000007332-19-000066

(HTML Version on secdatabase.com)

FILER SOUTHWESTERN ENERGY CO Mailing Address Business Address 10000 ENERGY DRIVE 10000 ENERGY DRIVE CIK:7332| IRS No.: 710205415 | State of Incorp.:DE | Fiscal Year End: 1231 SPRING TX 77389 SPRING TX 77389 Type: 10-Q | Act: 34 | File No.: 001-08246 | Film No.: 191166881 832-796-4700 SIC: 1311 Crude & natural gas

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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 September 30, 2019

Or

☐ Transition Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the transition period from ______to ______

Commission file number: 001-08246

Southwestern Energy Company (Exact name of registrant as specified in its charter)

Delaware 71-0205415

(State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)

10000 Energy Drive Spring, Texas 77389

(Address of principal executive offices) (Zip Code)

(832) 796-1000 (Registrant’s telephone number, including area code)

Not Applicable (Former name, former address and former fiscal year, if changed since last report)

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

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Title of each class Trading Symbol(s) Name of each exchange on which registered Common Stock, Par Value $0.01 SWN New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

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

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 Exchange Act). Yes ☐ No ☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:

Class Outstanding as of October 22, 2019 Common Stock, Par Value $0.01 541,296,926

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SOUTHWESTERN ENERGY COMPANY

INDEX TO FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2019

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Item 1. Financial Statements 3 Consolidated Statements of Operations 3 Consolidated Statements of Comprehensive Income 4 Consolidated Balance Sheets 5 Consolidated Statements of Cash Flows 6 Consolidated Statements of Changes in Equity 7 Notes to Consolidated Financial Statements 9 Note 1. Basis of Presentation 9 Note 2. Divestitures 9 Note 3. Restructuring Charges 10 Note 4. Leases 11 Note 5. Revenue Recognition 13 Note 6. Cash and Cash Equivalents 15 Note 7. Natural Gas and Oil Properties 15 Note 8. Earnings per Share 15 Note 9. Derivatives and Risk Management 16 Note 10. Reclassifications From Accumulated Other Comprehensive Income (Loss) 23 Note 11. Fair Value Measurements 23 Note 12. Debt 26 Note 13. Commitments and Contingencies 28 Note 14. Income Taxes 29 Note 15. Pension Plan and Other Postretirement Benefits 30 Note 16. Stock-Based Compensation 30 Note 17. Segment Information 33 Note 18. New Accounting Pronouncements 34 Note 19. Condensed Consolidated Financial Information 35 Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations 42 Results of Operations 44 Liquidity and Capital Resources 53 Item 3. Quantitative and Qualitative Disclosures About Market Risk 57 Item 4. Controls and Procedures 57

PART II – OTHER INFORMATION

Item 1. Legal Proceedings 58 Item 1A. Risk Factors 59 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds 59 Item 3. Defaults Upon Senior Securities 59 Item 4. Mine Safety Disclosures 59 Copyright © 2019 www.secdatabase.com. All Rights Reserved. Item 5. Other Information Please Consider the Environment Before Printing This Document 59 Item 6. Exhibits 59 CAUTIONARY STATEMENT ABOUT FORWARD-LOOKING STATEMENTS

All statements, other than historical fact or present financial information, may be deemed to be forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements that address activities, outcomes and other matters that should or may occur in the future, including, without limitation, statements regarding the financial position, business strategy, production and reserve growth and other plans and objectives for our future operations, are forward-looking statements. Although we

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believe the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance. We have no obligation and make no undertaking to publicly update or revise any forward-looking statements, except as may be required by law.

Forward-looking statements include the items identified in the preceding paragraph, information concerning possible or assumed future results of operations and other statements in this Quarterly Report on Form 10-Q identified by words such as “anticipate,” “intend,” “plan,” “project,” “estimate,” “continue,” “potential,” “should,” “could,” “may,” “will,” “objective,” “guidance,” “outlook,” “effort,” “expect,” “believe,” “predict,” “budget,” “projection,” “goal,” “forecast,” “target” or similar words.

You should not place undue reliance on forward-looking statements. They are subject to known and unknown risks, uncertainties and other factors that may affect our operations, markets, products, services and prices and cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward- looking statements. In addition to any assumptions and other factors referred to specifically in connection with forward-looking statements, risks, uncertainties and factors that could cause our actual results to differ materially from those indicated in any forward- looking statement include, but are not limited to: • the timing and extent of changes in market conditions and prices for natural gas, oil and natural gas liquids (“NGLs”) (including regional basis differentials); • our ability to fund our planned capital investments; • a change in our credit rating, an increase in interest rates and any adverse impacts from the discontinuation of the London Interbank Offered Rate (“LIBOR”); • the extent to which lower commodity prices impact our ability to service or refinance our existing debt; • the impact of volatility in the financial markets or other global economic factors; • difficulties in appropriately allocating capital and resources among our strategic opportunities; • the timing and extent of our success in discovering, developing, producing and estimating reserves; • our ability to maintain leases that may expire if production is not established or profitably maintained; • our ability to realize the expected benefits from acquisitions; • our ability to transport our production to the most favorable markets or at all; • availability and costs of personnel and of products and services provided by third parties; • the impact of government regulation, including changes in law, the ability to obtain and maintain permits, any increase in severance or similar taxes, and legislation or regulation relating to , climate and over-the-counter derivatives; • the impact of the adverse outcome of any material litigation against us or judicial decisions that affect us or our industry generally; • the effects of weather; • increased competition; • the financial impact of accounting regulations and critical accounting policies; • the comparative cost of alternative fuels; • credit risk relating to the risk of loss as a result of non-performance by our counterparties; and • any other factors listed in the reports we have filed and may file with the Securities and Exchange Commission (“SEC”).

Should one or more of the risks or uncertainties described above or elsewhere in this Quarterly Report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document statements. We specifically disclaim all responsibility to update publicly any information contained in a forward-looking statement or any forward-looking statement in its entirety and therefore disclaim any resulting liability for potentially related damages.

All forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement.

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PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended For the nine months ended September 30, September 30,

(in millions, except share/per share amounts) 2019 2018 2019 2018

Operating Revenues: Gas sales $ 238 $ 465 $ 943 $ 1,412 Oil sales 67 62 153 141 NGL sales 52 112 191 252 Marketing 279 287 1,004 805 Gas gathering — 25 — 73 Other — — 2 4 636 951 2,293 2,687 Operating Costs and Expenses: Marketing purchases 288 288 1,022 808 Operating expenses 189 206 523 588 General and administrative expenses 42 51 119 165 Loss on sale of operating assets — — 3 — Restructuring charges 4 2 9 20 Depreciation, depletion and amortization 125 151 352 426 Impairments 2 161 8 171 Taxes, other than income taxes 15 26 51 64 665 885 2,087 2,242

Operating Income (Loss) (29) 66 206 445 Interest Expense: Interest on debt 42 56 125 180 Other interest charges 2 2 5 6 Interest capitalized (27) (29) (84) (86) 17 29 46 100

Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on Early Extinguishment of Debt 7 — 7 (8) Other Income (Loss), Net (2) (1) (7) 1

Income (Loss) Before Income Taxes 59 (29) 380 230 Provision (Benefit) for Income Taxes Current (1) — (1) — Deferred 11 — (400) — 10 — (401) —

Net Income (Loss) $ 49 $ (29) $ 781 $ 230

Participating securities – mandatory convertible preferred stock — — — 1

Net Income (Loss) Attributable to Common Stock $ 49 $ (29) $ 781 $ 229

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Earnings (Loss) Per Common Share

Basic $ 0.09 $ (0.05) $ 1.45 $ 0.40

Diluted $ 0.09 $ (0.05) $ 1.44 $ 0.39

Weighted Average Common Shares Outstanding:

Basic 539,221,101 581,171,753 539,315,170 577,912,421

Diluted 540,038,187 581,171,753 540,442,649 579,828,858 The accompanying notes are an integral part of these consolidated financial statements.

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)

For the three months ended For the nine months ended September 30, September 30, (1) (1) (in millions) 2019 2018 2019 2018

Net income (loss) $ 49 $ (29) $ 781 $ 230

Change in value of pension and other postretirement liabilities: Amortization of prior service cost and net loss included in net periodic pension 1 4 5 4 (2) cost

Comprehensive income (loss) $ 50 $ (25) $ 786 $ 234

(1) In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

(2) Primarily related to settlement of pension assets in 2019 and the curtailment of pension assets in 2018. Net of less than $1 million and $1 million in taxes for the three months ended September 30, 2019 and 2018, respectively, and $2 million and $1 million in taxes for the nine months ended September 30, 2019 and 2018, respectively.

The accompanying notes are an integral part of these consolidated financial statements.

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document September 30, December 31, 2019 2018

ASSETS (in millions) Current assets: Cash and cash equivalents $ 29 $ 201 Accounts receivable, net 323 581 Derivative assets 239 130 Other current assets 42 44

Total current assets 633 956 Natural gas and oil properties, using the full cost method, including $1,518 million as of September 30, 2019 25,060 24,180 and $1,755 million as of December 31, 2018 excluded from amortization Other 522 525 Less: Accumulated depreciation, depletion and amortization (20,383) (20,049)

Total property and equipment, net 5,199 4,656 Deferred tax assets 398 — Other long-term assets 368 185

TOTAL ASSETS $ 6,598 $ 5,797

LIABILITIES AND EQUITY Current liabilities: Current portion of long-term debt $ 52 $ — Accounts payable 539 609 Taxes payable 55 58 Interest payable 57 52 Derivative liabilities 85 79 Other current liabilities 92 48

Total current liabilities 880 846 Long-term debt 2,219 2,318 Pension and other postretirement liabilities 39 46 Other long-term liabilities 325 225

Total long-term liabilities 2,583 2,589 Commitments and contingencies (Note 13) Equity: Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 585,637,420 shares as of September 6 6 30, 2019 and 585,407,107 shares as of December 31, 2018 Additional paid-in capital 4,723 4,715 Accumulated deficit (1,361) (2,142) Accumulated other comprehensive loss (31) (36) Common stock in treasury, 44,353,224 shares as of September 30, 2019 and 39,092,537 shares as of December (202) (181) 31, 2018 Total equity 3,135 2,362

TOTAL LIABILITIES AND EQUITY $ 6,598 $ 5,797 Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The accompanying notes are an integral part of these consolidated financial statements.

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the nine months ended September 30,

(in millions) 2019 2018

Cash Flows From Operating Activities: Net income $ 781 $ 230 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 352 426 Amortization of debt issuance costs 5 6 Impairments 8 171 Deferred income taxes (400) — (Gain) loss on derivatives, unsettled (108) 113 Stock-based compensation 6 12 (Gain) loss on early extinguishment of debt (7) 8 Loss on sale of assets 3 — Other 11 7 Change in assets and liabilities: Accounts receivable 257 (7) Accounts payable (124) 60 Taxes payable (3) — Interest payable 2 (5) Inventories (2) (9) Other assets and liabilities (42) (41)

Net cash provided by operating activities 739 971

Cash Flows From Investing Activities: Capital investments (877) (1,008) Proceeds from sale of property and equipment 42 9 Other — 4

Net cash used in investing activities (835) (995)

Cash Flows From Financing Activities: Payments on long-term debt (43) (1,191) Payments on revolving credit facility — (1,122) Borrowings under revolving credit facility — 1,482 Change in bank drafts outstanding (11) 10 Debt issuance costs — (9) Purchase of treasury stock (21) (25) Preferred stock dividend — (27) Cash paid for tax withholding (1) (1)

Net cash used in financing activities (76) (883)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Decrease in cash and cash equivalents Please Consider the Environment Before Printing This Document (172) (907) Cash and cash equivalents at beginning of year 201 916

Cash and cash equivalents at end of period $ 29 $ 9 The accompanying notes are an integral part of these consolidated financial statements. ?

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Common Stock in Accumulated Common Stock Treasury Additional Other Shares Paid-In Accumulated Comprehensive Issued Amount Capital Deficit Income (Loss) Shares Amount Total

(in millions, except share amounts)

Balance at December 31, 2018 585,407,107 $ 6 $ 4,715 $ (2,142) $ (36) 39,092,537 $ (181) $ 2,362

Comprehensive income:

Net income — — — 594 — — — 594

Other comprehensive income — — — — — — — —

Total comprehensive income — — — — — — — 594

Stock-based compensation — — 3 — — — — 3

Issuance of restricted stock 8,798 — — — — — — —

Cancellation of restricted stock (128,324) — — — — — — —

Treasury stock — — — — — 5,260,687 (21) (21)

Performance units vested 535,802 — — — — — — —

Tax withholding – stock compensation (274,657) — (1) — — — — (1)

Balance at March 31, 2019 585,548,726 $ 6 $ 4,717 $ (1,548) $ (36) 44,353,224 $ (202) $ 2,937

Comprehensive income:

Net income — — — 138 — — — 138

Other comprehensive income — — — — 4 — — 4

Total comprehensive income — — — — — — — 142

Stock-based compensation — — 3 — — — — 3

Issuance of restricted stock 6,424 — — — — — — —

Cancellation of restricted stock (72,555) — — — — — — —

Tax withholding – stock compensation (4,250) — — — — — — —

Balance at June 30, 2019 585,478,345 $ 6 $ 4,720 $ (1,410) $ (32) 44,353,224 $ (202) $ 3,082

Comprehensive income:

Net income — — — 49 — — — 49

Other comprehensive income — — — — 1 — — 1

Total comprehensive income — — — — — — — 50

Stock-based compensation — — 3 — — — — 3

Issuance of restricted stock 205,883 — — — — — — —

Cancellation of restricted stock (33,851) — — — — — — —

Tax withholding – stock compensation (12,957) — — — — — — —

Balance at September 30, 2019 585,637,420 $ 6 $ 4,723 $ (1,361) $ (31) 44,353,224 $ (202) $ 3,135

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (CONTINUED) (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Preferred Common Stock in Accumulated Common Stock Stock Treasury Additional Other Shares Shares Paid-In Accumulated Comprehensive Issued Amount Issued Capital Deficit Income (Loss) Shares Amount Total

(in millions, except share amounts)

Balance at December 31, 2017 512,134,311 $ 5 1,725,000 $ 4,698 $ (2,679) $ (44) 31,269 $ (1) $ 1,979

Comprehensive income:

Net income — — — — 208 — — — 208

Other comprehensive income — — — — — — — — —

Total comprehensive income — — — — — — — — 208

Stock-based compensation — — — 7 — — — — 7

Conversion of preferred stock 74,998,614 1 (1,725,000) (1) — — — — —

Issuance of restricted stock 5,076 — — — — — — — —

Cancellation of restricted stock (160,168) — — — — — — — —

Performance units vested 214,866 — — — — — — — —

Tax withholding – stock (338,808) — — (1) — — — — (1) compensation

Balance at March 31, 2018 586,853,891 $ 6 — $ 4,703 $ (2,471) $ (44) 31,269 $ (1) $ 2,193

Comprehensive income:

Net income — — — — 51 — — — 51

Other comprehensive income — — — — — — — — —

Total comprehensive income — — — — — — — — 51

Stock-based compensation — — — 6 — — — — 6

Issuance of restricted stock 307,743 — — — — — — — —

Cancellation of restricted stock (722,465) — — — — — — — —

Tax withholding – stock (9,068) — — — — — — — — compensation

Balance at June 30, 2018 586,430,101 $ 6 — $ 4,709 $ (2,420) $ (44) 31,269 $ (1) $ 2,250

Comprehensive loss

Net loss — — — — (29) — — — (29)

Other comprehensive income — — — — — 4 — — 4

Total comprehensive loss — — — — — — — — (25)

Stock-based compensation — — — 5 — — — — 5

Preferred stock dividend — — — — — — — — —

Issuance of restricted stock 30,924 — — — — — — — —

Cancellation of restricted stock (248,342) — — — — — — — —

Treasury stock — — — — — — 4,829,011 (25) (25)

Tax withholding – stock (17,521) — — — — — — — — compensation

Balance at September 30, 2018 586,195,162 $ 6 — $ 4,714 $ (2,449) $ (40) 4,860,280 $ (26) $ 2,205

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The accompanying notes are an integral part of these consolidated financial statements.

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SOUTHWESTERN ENERGY COMPANY AND SUBSIDIARIES NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

(1) BASIS OF PRESENTATION

Southwestern Energy Company (including its subsidiaries, collectively “Southwestern” or the “Company”) is an independent energy company engaged in natural gas, oil and natural gas liquid (“NGL”) exploration, development and production (“E&P”). The Company is also focused on creating and capturing additional value through its marketing business (“Midstream”). Southwestern conducts most of its business through subsidiaries and operates principally in two segments: E&P and Midstream. The Company’s historical financial and operating results include its Fayetteville Shale E&P and related midstream gathering businesses, which were sold in early December 2018 (the “Fayetteville Shale sale”). The sale is discussed in further detail in Note 2.

E&P. Southwestern’s primary business is the exploration for and production of natural gas, oil and NGLs, with ongoing operations focused on the development of unconventional natural gas and oil reservoirs located in and West Virginia. The Company’s operations in northeast Pennsylvania, herein referred to as “Northeast Appalachia,” are primarily focused on the unconventional natural gas reservoir known as the Marcellus Shale. Operations in West Virginia and southwest Pennsylvania, herein referred to as “Southwest Appalachia,” are focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and oil reservoirs. Collectively, Southwestern refers to its properties located in Pennsylvania and West Virginia as the “Appalachian Basin.” The Company also operates drilling rigs located in Pennsylvania and West Virginia, and provides certain oilfield products and services, principally serving the Company’s E&P operations through vertical integration.

Midstream. Southwestern’s marketing activities capture opportunities that arise through the marketing and transportation of natural gas, oil and NGLs primarily produced in its E&P operations.

The accompanying consolidated financial statements were prepared using accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission. Certain information relating to the Company’s organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been appropriately condensed or omitted in this Quarterly Report. The Company believes the disclosures made are adequate to make the information presented not misleading.

The consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair statement of the financial position, results of operations and cash flows for the interim periods presented herein. It is recommended that these consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018 (“2018 Annual Report”).

The Company’s significant accounting policies, which have been reviewed and approved by the Audit Committee of the Company’s Board of Directors, are summarized in Note 1 in the Notes to the Consolidated Financial Statements included in the Company’s 2018 Annual Report.

Certain reclassifications have been made to the prior year financial statements to conform to the 2019 presentation. The effects of the reclassifications were not material to the Company’s consolidated financial statements.

(2) DIVESTITURES

On August 30, 2018, the Company entered into an agreement with Flywheel Energy Operating, LLC to sell 100% of the equity in the Company’s subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets for $1,865 million in cash, subject to customary closing adjustments, with an economic effective date of July 1, 2018. On December 3, 2018, the Company closed on the Fayetteville Shale sale and received approximately $1,650 million, which included purchase price adjustments of approximately $215 million primarily related to the net cash flows from the economic effective date to the closing date.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The Company retained certain contractual commitments related to firm transportation, with the buyer obligated to pay the transportation provider directly for these charges. As of September 30, 2019, approximately $135 million of these contractual commitments remain of which the Company will reimburse the buyer for certain of these potential obligations up to approximately $70 million through 2020 depending on the buyer’s actual use. At September 30, 2019, the Company has recorded a $57 million liability for the estimated future payments.

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In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool included in the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, the Company determined the carrying value of certain non-full cost pool assets exceeded the fair value less costs to sell. As a result, an impairment charge of $161 million was recorded during the three and nine months ended September 30, 2018, of which $145 million related to midstream gathering assets held for sale and $15 million related to E&P assets held for sale. Additionally, the Company recorded a $1 million impairment related to other non-core assets that were not included in the sale.

From the proceeds received, $914 million was used to repurchase $900 million of the Company’s outstanding senior notes, including premiums and $9 million in accrued interest paid in December 2018. In addition, $201 million, including approximately $1 million in commissions, was used to repurchase approximately 44 million shares of the Company’s outstanding common stock, including $21 million during the first quarter of 2019. The Company earmarked the remaining net proceeds from the sale to supplement Appalachian Basin development and for general corporate purposes.

In June 2019, the Company sold non-core acreage for $25 million. There was no production or proved reserves associated with this acreage. In addition, during July 2019, the Company sold the land associated with its headquarters office building for $16 million, and recognized a $2 million gain on the sale. The Company also from time to time sells leases and other properties whose value, individually, is not material but is reflected in the Company’s financial statements.

(3) RESTRUCTURING CHARGES

In June 2018, the Company notified affected employees of a workforce reduction plan, which resulted primarily from a previously announced study of structural, process and organizational changes to enhance shareholder value and continues with respect to other aspects of the Company’s business activities. Affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited.

In December 2018, the Company closed on the sale of the equity in certain of its subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets in Arkansas. As part of the transaction, most employees associated with those assets became employees of the buyer although the employment of some was terminated. All affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited. As of September 30, 2019, the Company has substantially completed the Fayetteville Shale sale-related employment terminations.

In July 2019, the Company terminated its existing lease agreement on its headquarters office building and entered into a new 10- year lease agreement for a smaller portion of the building. Approximately $3 million of the fees associated with the Company’s office consolidation are reflected as restructuring charges for the three months ended September 30, 2019. The Company also recognized additional severance costs in the third quarter of 2019, related to continued organizational restructuring, for which a liability of $1 million has been accrued as of September 30, 2019.

The following table presents a summary of the restructuring charges included in Operating Income (Loss) for the three and nine months ended September 30, 2019 and 2018:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended September 30, For the nine months ended September 30,

(in millions) 2019 2018 2019 2018

Severance (including payroll taxes) $ 1 $ 1 $ 4 $ 18 Office consolidation 3 — 5 — Professional fees — 1 — 2 (1) Total restructuring charges $ 4 $ 2 $ 9 $ 20

(1) Total restructuring charges were $4 million and $9 million for the Company’s E&P segment for the three and nine months ended September 30, 2019, respectively. Total restructuring charges were $2 million for the Company’s E&P segment for the three months ended September 30, 2018, and $18 million and $2 million for the Company’s E&P and Midstream segments, respectively, for the nine months ended September 30, 2018.

The following table presents a reconciliation of the liability associated with the Company’s restructuring activities at September 30, 2019, which is reflected in accounts payable on the consolidated balance sheet:

(in millions) Liability at December 31, 2018 $ 5 Additions 9 Distributions (13)

Liability at September 30, 2019 $ 1

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(4) LEASES

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. The codification was amended through additional ASUs. For public entities, Update 2016-02 became effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company adopted ASC 842 with an effective date of January 1, 2019 using the modified retrospective approach for all leases that existed at the date of initial application. The Company elected to apply the transition as of the beginning of the period of adoption. For leases that existed at the period of adoption on January 1, 2019, the incremental borrowing rate as of the application date was used to calculate the present value of remaining lease payments.

The standard provides optional practical expedients to ease the burden of transition. The Company has adopted the following practical expedients through implementation:

• an election not to apply the recognition requirements in the leases standard to short-term leases and recognize lease payments in the consolidated statement of operations (a lease that at commencement date has an initial term of 12 months or less and does not contain a purchase option that the Company is reasonably certain to exercise);

• a package of practical expedients to not reassess: whether a contract is or contains a lease, lease classification and initial direct costs;

• a practical expedient that permits combining lease and non-lease components in a contract and accounting for the combination as a lease (elected by asset class);

• a practical expedient to not reassess certain land easements in existence prior to January 1, 2019; and

• an election to adopt the modified retrospective approach for all leases existing at or entered into after the initial date of adoption which does not require a restatement of prior period. No cumulative-effect adjustment to retained earnings was required as a result of the modified retrospective approach.

Upon adoption of ASC 842, the Company recognized a discounted right-of-use asset and corresponding lease liability with opening balances of approximately $105 million as of January 1, 2019. The adoption of the standard did not materially change the Company’s consolidated statement of operations or its consolidated statement of cash flows.

The Company determines if a contract contains a lease at inception. A lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment (an identified asset) for a period of time in exchange for consideration. A right-of-use asset and corresponding lease liability are recognized on the balance sheet at commencement at an amount based on the present value of the remaining lease payments over the lease term. As the implicit rate of the lease is not always readily determinable, the Company uses the incremental borrowing rate to calculate the present value of the lease payments based on information available at commencement date. Operating right-of-use assets are included in other long-term assets while operating lease liabilities are included in other current and other long-term liabilities on the consolidated balance sheet. The Company does not have any financing lease type of arrangements as of September 30, 2019. By policy election, leases with an initial term of twelve months or less are not recorded on the balance sheet. The Company recognizes lease expense for these leases on a straight-line basis, and variable lease payments are recognized in the period as incurred.

Certain leases contain both lease and non-lease components. The Company has chosen to account for most of these leases as a single lease component instead of bifurcating lease and non-lease components. However, for compression service leases and fleet vehicle leases, the lease and non-lease components are accounted for separately.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The Company leases drilling rigs, pressure pumping equipment, vehicles, office space, certain water transportation lines, an aircraft and other equipment under non-cancelable operating leases expiring through 2032. Certain lease agreements include options to renew the lease, early terminate the lease or purchase the underlying asset(s). The Company determines the lease term at the lease commencement date as the non-cancelable period of the lease, including options to extend or terminate the lease when such an option is reasonably certain to be exercised. The Company’s water transportation lines are the only leases with renewal options that are reasonably certain to be exercised. These renewal options are reflected in the right-of-use asset and lease liability balances.

In July 2019, the Company terminated its existing lease agreement and entered into a new 10-year lease agreement for a smaller portion of the headquarters office building, which resulted in the Company making a $6 million residual value guarantee short-fall payment to the building’s previous lessor. The net impact to the Company’s right of use asset balance increased $56 million in the third quarter of 2019 as a result of entering into the new lease agreement, which was partially offset

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by the early lease termination of the previous lease. The Company’s variable lease costs are primarily comprised of variable operating charges incurred in connection with the new building lease which are expected to continue throughout the lease term. There are currently no material residual value guarantees in the Company’s existing leases.

The components of lease costs are shown below:

For the nine months ended (in millions) September 30, 2019 Operating lease cost $ 33 Short-term lease cost 49 Variable lease cost 1

Total lease cost $ 83

As of September 30, 2019, the Company has operating leases of $20 million, related primarily to compressor leases, that have been executed but not yet commenced. These operating leases are planned to commence during 2019 with lease terms expiring through 2023. The Company’s existing operating leases do not contain any material restrictive covenants.

Supplemental cash flow information related to leases is set forth below:

For the nine months ended (in millions) September 30, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 34

Right-of-use assets obtained in exchange for new operating liabilities: Operating leases $ 88

Supplemental balance sheet information related to leases is as follows:

Right-of-use asset balance: (in millions) September 30, 2019 Operating leases $ 164

Lease liability balance: (in millions) Short-term operating leases $ 35 Long-term operating leases 124 Total operating leases $ 159

Weighted average remaining lease term: (years) Operating leases 6.8

Weighted average discount rate: Operating leases 5.54 %

Maturity analysis of operating lease liabilities:

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2019 $ 12 2020 40 2021 31 2022 21 2023 19 2024 15 Thereafter 52 Total undiscounted lease liability 190 Imputed interest (31)

Total discounted lease liability $ 159

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(in millions) December 31, 2018

2019 $ 38 2020 28 2021 14 2022 6 2023 5 Thereafter 4

Total minimum payments required $ 95

(5) REVENUE RECOGNITION

Revenues from Contracts with Customers

Natural gas and liquids. Natural gas, oil and NGL sales are recognized when control of the product is transferred to the customer at a designated delivery point. The pricing provisions of the Company’s contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, quality of the product and prevailing supply and demand conditions in the geographic areas in which the Company operates. Under the Company’s sales contracts, the delivery of each unit of natural gas, oil and NGLs represents a separate performance obligation, and revenue is recognized at the point in time when the performance obligations are fulfilled. There is no significant financing component to the Company’s revenues as payment terms are typically within 30 to 60 days of control transfer. Furthermore, consideration from a customer corresponds directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognizes revenue in the amount to which the Company has a right to invoice and has not disclosed information regarding its remaining performance obligations.

The Company records revenue from its natural gas and liquids production in the amount of its net revenue interest in sales from its properties. Accordingly, natural gas and liquid sales are not recognized for deliveries in excess of the Company’s net revenue interest, while natural gas and liquid sales are recognized for any under-delivered volumes. Production imbalances are recorded as receivables and payables and not contract assets or contract liabilities as the imbalances are between the Company and other working interest owners, not the end customer.

Marketing. The Company, through its marketing affiliate, generally markets natural gas, oil and NGLs for its affiliated E&P company as well as other joint interest owners who choose to market with Southwestern. In addition, the Company markets some products purchased from third parties. Marketing revenues for natural gas, oil and NGL sales are recognized when control of the product is transferred to the customer at a designated delivery point. The pricing provisions of the Company’s contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, quality of the product and prevailing supply and demand conditions. Under the Company’s marketing contracts, the delivery of each unit of natural gas, oil and NGLs represents a separate performance obligation, and revenue is recognized at the point in time when the performance obligations are fulfilled. Customers are invoiced and revenues are recorded each month as natural gas, oil and NGLs are delivered, and payment terms are typically within 30 to 60 days of control transfer. Furthermore, consideration from a customer corresponds directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognizes revenue in the amount to which the Company has a right to invoice and has not disclosed information regarding its remaining performance obligations.

Gas gathering. Prior to the Fayetteville Shale sale in December 2018, the Company, through its gathering affiliate, gathered natural gas pursuant to a variety of contracts with customers, including an affiliated E&P company. The performance obligations for gas gathering services included delivery of each unit of natural gas to the designated delivery point, which may include treating of certain natural gas units to meet interstate pipeline specifications. Revenue was recognized at the point in time when performance obligations

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document were fulfilled. Under the Company’s gathering contracts, customers were invoiced and revenue was recognized each month based on the volume of natural gas transported and treated at a contractually agreed upon price per unit. Payment terms were typically within 30 to 60 days of completion of the performance obligations. Furthermore, consideration from a customer corresponded directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognized revenue in the amount to which the Company had a right to invoice and had not disclosed information regarding its remaining performance obligations. Any imbalances were settled on a monthly basis by cashing-out with the respective shipper. Accordingly, there were no contract assets or contract liabilities related to the Company’s gas gathering revenues.

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Disaggregation of Revenues

The Company presents a disaggregation of E&P revenues by product on the consolidated statements of operations net of intersegment revenues. The following table reconciles operating revenues as presented on the consolidated statements of operations to the operating revenues by segment:

Intersegment (in millions) E&P Midstream Revenues Total

Three months ended September 30, 2019 Gas sales $ 230 $ — $ 8 $ 238 Oil sales 66 — 1 67 NGL sales 52 — — 52 Marketing — 592 (313) 279

Total $ 348 $ 592 $ (304) $ 636

Three months ended September 30, 2018 Gas sales $ 460 $ — $ 5 $ 465 Oil sales 61 — 1 62 NGL sales 112 — — 112 Marketing — 846 (559) 287 (1) Gas gathering — 66 (41) 25

Total $ 633 $ 912 $ (594) $ 951

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Intersegment (in millions) E&P Midstream Revenues Total Nine months ended September 30, 2019 Gas sales $ 918 $ — $ 25 $ 943 Oil sales 151 — 2 153 NGL sales 191 — — 191 Marketing — 2,158 (1,154) 1,004 (2) Other 1 1 — 2 Total $ 1,261 $ 2,159 $ (1,127) $ 2,293

Nine months ended September 30, 2018 Gas sales $ 1,395 $ — $ 17 $ 1,412 Oil sales 139 — 2 141 NGL sales 252 — — 252 Marketing — 2,403 (1,598) 805 (1) Gas gathering — 202 (129) 73 (2) Other 4 — — 4 Total $ 1,790 $ 2,605 $ (1,708) $ 2,687

(1) The Company’s gas gathering assets were divested in December 2018 as part of the Fayetteville Shale sale.

(2) Other E&P revenues consists primarily of water sales to third-party operators, and other Midstream revenues consists primarily of sales of gas from storage.

Associated E&P revenues are also disaggregated for analysis on a geographic basis by the core areas in which the Company operates, which are in Pennsylvania and West Virginia. In December 2018, the Company sold 100% of its Fayetteville Shale assets.

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Northeast Appalachia $ 175 $ 254 $ 740 $ 794 Southwest Appalachia 173 235 519 557 Fayetteville Shale — 140 — 431 Other — 4 2 8

Total $ 348 $ 633 $ 1,261 $ 1,790

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Receivables from Contracts with Customers

The following table reconciles the Company’s receivables from contracts with customers to consolidated accounts receivable as presented on the consolidated balance sheet:

(in millions) September 30, 2019 December 31, 2018

Receivables from contracts with customers $ 235 $ 494 Other accounts receivable 88 87

Total accounts receivable $ 323 $ 581

Amounts recognized against the Company’s allowance for doubtful accounts related to receivables arising from contracts with customers were immaterial for the three and nine months ended September 30, 2019 and 2018. The Company has no contract assets or contract liabilities associated with its revenues from contracts with customers.

(6) CASH AND CASH EQUIVALENTS

The following table presents a summary of cash and cash equivalents as of September 30, 2019 and December 31, 2018:

(in millions) September 30, 2019 December 31, 2018

Cash $ 9 $ 32 (1) Marketable securities 20 169

Total $ 29 $ 201

(1) Consists of government stable value money market funds.

(7) NATURAL GAS AND OIL PROPERTIES

The Company utilizes the full cost method of accounting for costs related to the exploration, development and acquisition of natural gas and oil properties. Under this method, all such costs (productive and nonproductive), including salaries, benefits and other internal costs directly attributable to these activities, are capitalized on a country-by-country basis and amortized over the estimated lives of the properties using the units-of-production method. These capitalized costs are subject to a ceiling test that limits such pooled costs, net of applicable deferred taxes, to the aggregate of the present value of future net revenues attributable to proved natural gas, oil and NGL reserves discounted at 10% (standardized measure). Any costs in excess of the ceiling are written off as a non-cash expense. The expense may not be reversed in future periods, even though higher natural gas, oil and NGL prices may subsequently increase the ceiling. Companies using the full cost method are required to use the average quoted price from the first day of each month from the previous 12 months, including the impact of derivatives designated for hedge accounting, to calculate the ceiling value of their reserves.

Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $2.87 per MMBtu, West Texas Intermediate oil of $57.77 per Bbl and NGLs of $12.59 per Bbl, adjusted for differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount at September 30, 2019. The Company had no derivative positions that were designated for hedge accounting as of September 30, 2019. Decreases in market prices as well as changes in production rates, levels of reserves, evaluation of costs excluded from amortization, future development costs and production costs could result in future ceiling test impairments. Should market prices continue below the average of the previous 12-months, as was the case in the third quarter of 2019, such impairments may occur in upcoming quarters.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $2.91 per MMBtu, West Texas Intermediate oil of $63.43 per Bbl and NGLs of $17.47 per Bbl, adjusted for differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount at September 30, 2018. The Company had no derivative positions that were designated for hedge accounting as of September 30, 2018.

(8) EARNINGS PER SHARE

Basic earnings per common share is computed by dividing net income attributable to common stock by the weighted average number of common shares outstanding during the reportable period. The diluted earnings per share calculation adds to the weighted average number of common shares outstanding: the incremental shares that would have been outstanding assuming the exercise of dilutive stock options, the vesting of unvested restricted shares of common stock, performance units and the assumed conversion of mandatory convertible preferred stock. An antidilutive impact is an increase in earnings per share or a reduction in net loss per share resulting from the conversion, exercise or contingent issuance of certain securities.

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In January 2015, the Company issued 34,500,000 depositary shares that entitled the holder to a proportional fractional interest in the rights and preferences of the mandatory convertible preferred stock, including conversion, dividend, liquidation and voting rights. The mandatory convertible preferred stock had the non-forfeitable right to participate on an as-converted basis at the conversion rate then in effect in any common stock dividends declared and, therefore, was considered a participating security. Accordingly, it has been included in the computation of basic and diluted earnings per share, pursuant to the two-class method. In the calculation of basic earnings per share attributable to common shareholders, earnings are allocated to participating securities based on actual dividend distributions received plus a proportionate share of undistributed net income attributable to common shareholders, if any, after recognizing distributed earnings. The Company’s participating securities do not participate in undistributed net losses because they are not contractually obligated to do so. On January 12, 2018, all outstanding shares of mandatory convertible preferred stock converted to 74,998,614 shares of the Company’s common stock. The Company paid out its last dividend payment of approximately $27 million associated with the depositary shares in January 2018.

During the second half of 2018, the Company repurchased 39,061,269 shares of its outstanding common stock for approximately $180 million at an average price of $4.63 per share. In the first quarter of 2019, the Company completed its share repurchase program by purchasing 5,260,687 shares of its outstanding common stock for approximately $21 million at an average price of $3.84 per share.

The following table presents the computation of earnings per share for the three and nine months ended September 30, 2019 and 2018:

For the three months ended For the nine months ended September 30, September 30,

(in millions, except share/per share amounts) 2019 2018 2019 2018

Net income (loss) $ 49 $ (29) $ 781 $ 230 Participating securities – mandatory convertible preferred stock — — — 1

Net income (loss) attributable to common stock $ 49 $ (29) $ 781 $ 229

Number of common shares: Weighted average outstanding 539,221,101 581,171,753 539,315,170 577,912,421 Issued upon assumed exercise of outstanding stock options — — — — Effect of issuance of non-vested restricted common stock 187,706 — 400,120 640,365 Effect of issuance of non-vested performance units 629,380 — 727,359 1,276,072

Weighted average and potential dilutive outstanding 540,038,187 581,171,753 540,442,649 579,828,858

Earnings per common share Basic $ 0.09 $ (0.05) $ 1.45 $ 0.40

Diluted $ 0.09 $ (0.05) $ 1.44 $ 0.39

The following table presents the common stock shares equivalent excluded from the calculation of diluted earnings per share for the three and nine months ended September 30, 2019 and 2018, as they would have had an antidilutive effect:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended For the nine months ended September 30, September 30,

2019 2018 2019 2018

Unexercised stock options 5,102,882 717 5,115,334 — Unvested share-based payment 2,136,453 3,463,802 1,797,963 4,246,492 Performance units 240,450 2,000,553 247,443 856,703 Mandatory convertible preferred stock — — — 3,296,642

Total 7,479,785 5,465,072 7,160,740 8,399,837

(9) DERIVATIVES AND RISK MANAGEMENT

The Company is exposed to volatility in market prices and basis differentials for natural gas, oil and NGLs which impacts the predictability of its cash flows related to the sale of those commodities. These risks are managed by the Company’s use of certain derivative financial instruments. As of September 30, 2019, the Company’s derivative financial instruments consisted of fixed price swaps, two-way costless collars, three-way costless collars, basis swaps, call options and interest rate swaps. A description of the Company’s derivative financial instruments is provided below:

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Fixed price swaps If the Company sells a fixed price swap, the Company receives a fixed price for the contract and pays a floating market price to the counterparty. If the Company purchases a fixed price swap, the Company receives a floating market price for the contract and pays a fixed price to the counterparty.

Two-way costless collars Arrangements that contain a fixed floor price (purchased put option) and a fixed ceiling price (sold call option) based on an index price which, in aggregate, have no net cost. At the contract settlement date, (1) if the index price is higher than the ceiling price, the Company pays the counterparty the difference between the index price and ceiling price, (2) if the index price is between the floor and ceiling prices, no payments are due from either party, and (3) if the index price is below the floor price, the Company will receive the difference between the floor price and the index price.

Three-way costless Arrangements that contain a purchased put option, a sold call option and a sold put option based on an index collars price which, in aggregate, have no net cost. At the contract settlement date, (1) if the index price is higher than the sold call strike price, the Company pays the counterparty the difference between the index price and sold call strike price, (2) if the index price is between the purchased put strike price and the sold call strike price, no payments are due from either party, (3) if the index price is between the sold put strike price and the purchased put strike price, the Company will receive the difference between the purchased put strike price and the index price, and (4) if the index price is below the sold put strike price, the Company will receive the difference between the purchased put strike price and the sold put strike price.

Basis swaps Arrangements that guarantee a price differential for natural gas from a specified delivery point. If the Company sells a basis swap, the Company receives a payment from the counterparty if the price differential is greater than the stated terms of the contract and pays the counterparty if the price differential is less than the stated terms of the contract. If the Company purchases a basis swap, the Company pays the counterparty if the price differential is greater than the stated terms of the contract and receives a payment from the counterparty if the price differential is less than the stated terms of the contract.

Call options The Company purchases and sells call options in exchange for a premium. If the Company purchases a call option, the Company receives from the counterparty the excess (if any) of the market price over the strike price of the call option at the time of settlement, but if the market price is below the call’s strike price, no payment is due from either party. If the Company sells a call option, the Company pays the counterparty the excess (if any) of the market price over the strike price of the call option at the time of settlement, but if the market price is below the call’s strike price, no payment is due from either party.

Interest rate swaps Interest rate swaps are used to fix or float interest rates on existing or anticipated indebtedness. The purpose of these instruments is to manage the Company’s existing or anticipated exposure to unfavorable interest rate changes.

The Company chooses counterparties for its derivative instruments that it believes are creditworthy at the time the transactions are entered into, and the Company actively monitors the credit ratings and credit default swap rates of these counterparties where applicable. However, there can be no assurance that a counterparty will be able to meet its obligations to the Company. The Company presents its derivative positions on a gross basis and does not net the asset and liability positions.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document As part of the Fayetteville Shale sale, the Company entered into certain natural gas derivative positions that were subsequently novated to the buyer in conjunction with finalization of the sale. The derivatives that were novated to the buyer are not included in the tables below.

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The following tables provide information about the Company’s financial instruments that are sensitive to changes in commodity prices and that are used to protect the Company’s exposure. None of the financial instruments below are designated for hedge accounting treatment. The tables present the notional amount, the weighted average contract prices and the fair value by expected maturity dates as of September 30, 2019:

Financial Protection on Production Weighted Average Price per MMBtu Fair Value at Volume Purchased Basis September 30, 2019 (Bcf) Swaps Sold Puts Puts Sold Calls Differential (in millions)

Natural Gas 2019 Fixed price swaps 61 $ 2.89 $ — $ — $ — $ — $ 28 Two-way costless collars 6 — — 2.78 2.92 — 2 Three-way costless collars 44 — 2.43 2.82 3.15 — 13 Total 111 $ 43 2020 (1) Fixed price swaps 151 $ 2.58 $ — $ — $ — $ — $ 45 Three-way costless collars 209 — 2.34 2.67 2.98 — 22 Total 360 $ 67 2021 Three-way costless collars 134 $ — $ 2.27 $ 2.55 $ 2.85 $ — $ (1) 2022 Three-way costless collars 23 $ — $ 2.30 $ 2.70 $ 3.14 $ — $ —

Basis Swaps 2019 35 $ — $ — $ — $ — $ (0.40) $ 9 2020 141 — — — — (0.31) (13) 2021 65 — — — — (0.48) (1) 2022 45 — — — — (0.50) — Total 286 $ (5)

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

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Weighted Average Strike Price per Bbl Fair Value at Volume Purchased September 30, 2019 (MBbls) Swaps Sold Puts Puts Sold Calls (in millions) Oil 2019 (1) Fixed price swaps 632 $ 60.65 $ — $ — $ — $ 4 Two-way costless collars 382 — — 61.45 67.16 3 Three-way costless collars 138 — 45.00 55.00 63.67 — Total 1,152 $ 7 2020 Fixed price swaps 1,556 $ 60.18 $ — $ — $ — $ 14 Two-way costless collars 366 — — 60.00 69.80 4 Three-way costless collars 915 — 45.00 55.00 61.75 3 Total 2,837 $ 21 2021 Three-way costless collars 730 $ — $ 45.00 $ 53.00 $ 59.50 $ 1

Propane 2019 Fixed price swaps 978 $ 30.18 $ — $ — $ — $ 11 Two-way costless collars 138 — — 25.62 28.77 1 Total 1,116 $ 12 2020 Fixed price swaps 2,928 $ 25.58 $ — $ — $ — $ 18 Two-way costless collars 366 — — 25.20 $ 29.40 2 Total 3,294 $ 20 2021 Fixed price swaps 456 $ 22.24 $ — $ — $ — $ 1

Ethane 2019 Fixed price swaps 2,194 $ 10.53 $ — $ — $ — $ 6 2020 Fixed price swaps 3,843 $ 9.80 $ — $ — $ — $ 7

(1) Includes 69 MBbls of purchased fixed price oil swaps hedged at $69.10 per Bbl with a fair value of ($1) million and 701 MBbls of sold fixed price oil swaps hedged at $61.48 per Bbl with a fair value of $5 million.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Other Derivative Contracts Weighted Average Volume Strike Price per Fair Value at September (Bcf) MMBtu 30, 2019 (in millions)

Purchased Call Options – Natural Gas 2019 5 $ 3.50 $ — 2020 68 3.63 1 2021 57 3.52 2 Total 130 $ 3

Sold Call Options – Natural Gas 2019 13 $ 3.50 $ — 2020 137 3.39 (5) 2021 114 3.33 (6) 2023 6 3.00 (1) 2024 9 3.00 (2) Total 279 $ (14)

?

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Weighted Average Fair Value at Volume Strike Price per Basis Differential per September 30, 2019 (in (Bcf) MMBtu MMBtu millions) (1) Storage 2019 Purchased fixed price swaps — $ 2.90 $ — $ — Purchased basis swaps — — (0.61) — Total — $ — 2020 Purchased fixed price swaps — $ 2.37 $ — $ — Purchased basis swaps — — (0.32) — Sold fixed price swaps 2 3.06 — 1 Sold basis swaps — — (0.32) — Total 2 $ 1

(1) The Company has entered into certain derivatives to protect the value of volumes of natural gas injected into a storage facility that will be withdrawn at a later date.

At September 30, 2019, the net fair value of the Company’s financial instruments related to commodities was a $169 million asset.

As of September 30, 2019, the Company had no positions designated for hedge accounting treatment. Gains and losses on derivatives that are not designated for hedge accounting treatment, or do not meet hedge accounting requirements, are recorded as a component of gain (loss) on derivatives on the consolidated statements of operations. Accordingly, the gain (loss) on derivatives component of the statement of operations reflects the gain and losses on both settled and unsettled derivatives. The Company calculates gains and losses on settled derivatives as the summation of gains and losses on positions which have settled within the reporting period. Only the settled gains and losses are included in the Company’s realized commodity price calculations.

The Company is a party to interest rate swaps that were entered into to mitigate the Company’s exposure to volatility in interest rates. The interest rate swaps have a notional amount of $170 million and expire in June 2020. The Company did not designate the interest rate swaps for hedge accounting treatment. Changes in the fair value of the interest rate swaps are included in gain (loss) on derivatives on the consolidated statements of operations.

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The balance sheet classification of the assets and liabilities related to derivative financial instruments (none of which are designated for hedge accounting treatment) is summarized below as of September 30, 2019 and December 31, 2018:

Derivative Assets Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: (1) Fixed price swaps – natural gas Derivative assets $ 68 $ 32 Fixed price swaps – oil Derivative assets 15 13 Fixed price swaps – propane Derivative assets 25 11 Fixed price swaps – ethane Derivative assets 12 7 Two-way costless collars – natural gas Derivative assets 2 11 Two-way costless collars – oil Derivative assets 6 6 Two-way costless collars – propane Derivative assets 3 — Three-way costless collars – natural gas Derivative assets 84 41 Three-way costless collars – oil Derivative assets 5 — Basis swaps – natural gas Derivative assets 17 8 Purchased call options – natural gas Derivative assets 1 — Storage – fixed price swaps Derivative assets 1 — Interest rate swaps Derivative assets — 1 Fixed price swaps – natural gas Other long-term assets 5 6 Fixed price swaps – oil Other long-term assets 4 6 Fixed price swaps – propane Other long-term assets 5 — Fixed price swaps – ethane Other long-term assets 1 1 Two-way costless collars – oil Other long-term assets 1 5 Three-way costless collars – natural gas Other long-term assets 63 34 Three-way costless collars – oil Other long-term assets 8 — Basis swaps – natural gas Other long-term assets 7 3 Purchased call options – natural gas Other long-term assets 2 6

Total derivative assets $ 335 $ 191

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative Liabilities Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: Purchased fixed price swap – oil Derivative liabilities $ 1 $ 6 Fixed price swaps – natural gas Derivative liabilities — 9 Fixed price swaps – ethane Derivative liabilities — 3 Two-way costless collars – natural gas Derivative liabilities — 7 Three-way costless collars – natural gas Derivative liabilities 53 33 Three-way costless collars – oil Derivative liabilities 3 — Basis swaps – natural gas Derivative liabilities 24 18 Sold call options – natural gas Derivative liabilities 4 3 Fixed price swaps – natural gas Other long-term liabilities — 1 Two-way costless collars – oil Other long-term liabilities — 1 Three-way costless collars – natural gas Other long-term liabilities 60 35 Three-way costless collars – oil Other long-term liabilities 6 — Basis swap – natural gas Other long-term liabilities 5 4 Sold call options – natural gas Other long-term liabilities 10 19

Total derivative liabilities $ 166 $ 139

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

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The following tables summarize the before-tax effect of the Company’s derivative instruments on the consolidated statements of operations for the three and nine months ended September 30, 2019 and 2018:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Unsettled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Unsettled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ 5 $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives (19) (17) 36 (46) Fixed price swaps – oil Gain (Loss) on Derivatives 8 — — — Fixed price swaps – propane Gain (Loss) on Derivatives 10 (10) 19 (19) Fixed price swaps – ethane Gain (Loss) on Derivatives 1 (27) 8 (29) Two-way costless collars – natural gas Gain (Loss) on Derivatives (11) 2 (2) 4 Two-way costless collars – oil Gain (Loss) on Derivatives — — (3) — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 3 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 3 (7) 27 (36) Three-way costless collars – oil Gain (Loss) on Derivatives 3 — 4 — Basis swaps – natural gas Gain (Loss) on Derivatives 12 (5) 6 11 Purchased call options – natural gas Gain (Loss) on Derivatives (1) (2) (3) 2 Sold call options – natural gas Gain (Loss) on Derivatives 2 5 8 2 Sold call options – oil Gain (Loss) on Derivatives — 1 — (5) Storage – fixed price swap Gain (Loss) on Derivatives 2 — 1 — Interest rate swaps Gain (Loss) on Derivatives 1 1 (1) 3

Total gain (loss) on unsettled derivatives $ 12 $ (59) $ 108 $ (113)

(1) Settled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Settled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ (2) $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives 45 5 53 18 Fixed price swaps – oil Gain (Loss) on Derivatives 3 — 7 — Fixed price swaps – propane Gain (Loss) on Derivatives 11 (5) 20 (6) Fixed price swaps – ethane Gain (Loss) on Derivatives 6 (6) 12 (6) Two-way costless collars – natural gas Gain (Loss) on Derivatives 10 — 12 4 Two-way costless collars – oil Gain (Loss) on Derivatives 2 — 4 — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 1 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 15 5 19 24 Basis swaps – natural gas Gain (Loss) on Derivatives (3) (4) (11) (28) (2) (2) (3) Purchased call options – natural gas Gain (Loss) on Derivatives (1) — (1) 2 Sold call options – natural gas Gain (Loss) on Derivatives — — (1) (1) Copyright © 2019 www.secdatabase.com. All Rights Reserved. Sold call options – oil PleaseGain Consider (Loss) the on Environment Derivatives Before Printing This Document— (1) — (2) Storage – fixed price swap Gain (Loss) on Derivatives (1) — (1) — Total gain (loss) on settled derivatives $ 88 $ (6) $ 112 $ 5

Total gain (loss) on derivatives $ 100 $ (65) $ 220 $ (108) (1) The Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that settled within the period.

(2) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the three and nine months ended September 30, 2019, which is included in gain (loss) on derivatives on the consolidated statements of operations.

(3) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the nine months ended September 30, 2018, which is included in gain (loss) on derivatives on the consolidated statements of operations.

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(10) RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

In the first half of 2019, changes in accumulated other comprehensive income primarily related to settlements in the Company’s pension and other postretirement benefits. The following tables detail the components of accumulated other comprehensive income and the related tax effects for the nine months ended September 30, 2019:

Pension and Other Foreign (in millions) Postretirement Currency Total

Beginning balance December 31, 2018 $ (22) $ (14) $ (36) Other comprehensive income before reclassifications — — — (1) Amounts reclassified from other comprehensive income 5 — 5

Net current-period other comprehensive income 5 — 5

Ending balance September 30, 2019 $ (17) $ (14) $ (31)

(1) See separate table below for details about these reclassifications.

Details about Accumulated Other Affected Line Item in the Amount Reclassified from Accumulated Comprehensive Income Consolidated Statement of Operations Other Comprehensive Income

For the nine months ended September 30, 2019

(in millions) Pension and other postretirement: (1) Amortization of prior service cost and net loss Other Income, Net $ 7 Provision for income taxes 2

Net income $ 5

Total reclassifications for the period Net income $ 5

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(1) See Note 15 for additional details regarding the Company’s pension and other postretirement benefit plans.

(11) FAIR VALUE MEASUREMENTS

Assets and liabilities measured at fair value on a recurring basis

The carrying amounts and estimated fair values of the Company’s financial instruments as of September 30, 2019 and December 31, 2018 were as follows:

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Carrying Fair Carrying Fair (in millions) Amount Value Amount Value

Cash and cash equivalents $ 29 $ 29 $ 201 $ 201 2018 revolving credit facility due April 2023 — — — — (1) Senior notes 2,292 2,109 2,342 2,190 (2) (2) Derivative instruments, net 169 169 52 52

(1) Excludes unamortized debt issuance costs and debt discounts.

(2) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet.

The fair value hierarchy prioritizes the inputs to valuation techniques used to measure fair value. As presented in the tables below, this hierarchy consists of three broad levels:

Level 1 valuations - Consist of unadjusted quoted prices in active markets for identical assets and liabilities and have the highest priority.

Level 2 valuations - Consist of quoted market information for the calculation of fair market value.

Level 3 valuations - Consist of internal estimates and have the lowest priority.

The carrying values of cash and cash equivalents, including marketable securities, accounts receivable, other current assets, accounts payable and other current liabilities on the consolidated balance sheets approximate fair value because of their short-term nature. For debt and derivative instruments, the following methods and assumptions were used to estimate fair value:

Debt: The fair values of the Company’s senior notes were based on the market value of the Company’s publicly traded debt as determined based on the market prices of the Company’s senior notes. These instruments were previously classified as a Level 2 measurement but substantially all senior notes were updated to a Level 1 measurement in the second quarter of 2018

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as the market activity of the Company’s debt has resulted in timely quoted prices. The 3.42% Senior Notes due January 2020 remain a Level 2 measurement due to relative market inactivity.

The carrying values of the borrowings under the Company’s revolving credit facility (to the extent utilized) approximates fair value because the interest rate is variable and reflective of market rates. The Company considers the fair value of its revolving credit facility to be a Level 1 measurement on the fair value hierarchy.

Derivative Instruments: The fair value of all derivative instruments is the amount at which the instrument could be exchanged currently between willing parties. The amounts are based on quoted market prices, best estimates obtained from counterparties and an option pricing model, when necessary, for price option contracts.

The Company has classified its derivatives into these levels depending upon the data utilized to determine their fair values. The Company’s fixed price swaps (Level 2) are estimated using third-party discounted cash flow calculations using the New York Mercantile Exchange (“NYMEX”) futures index for natural gas and oil derivatives and Oil Price Information Service (“OPIS”) for ethane and propane derivatives. The Company utilizes discounted cash flow models for valuing its interest rate derivatives (Level 2). The net derivative values attributable to the Company’s interest rate derivative contracts as of September 30, 2019 are based on (i) the contracted notional amounts, (ii) active market-quoted LIBOR yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve.

The Company’s call options, two-way costless collars and three-way costless collars (Level 2) are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contract terms, including maturity, and market parameters, including assumptions of the NYMEX and OPIS futures index, interest rates, volatility and credit worthiness. The Company’s basis swaps (Level 2) are estimated using third-party calculations based upon forward commodity price curves. These instruments were previously classified as a Level 3 measurement in the fair value hierarchy but were updated to a Level 2 measurement in the second quarter of 2018 as a result of the Company’s ability to derive volatility inputs and forward commodity price curves from directly observable sources.

Inputs to the Black-Scholes model, including the volatility input, are obtained from a third-party pricing source, with independent verification of the most significant inputs on a monthly basis. An increase (decrease) in volatility would result in an increase (decrease) in fair value measurement, respectively.

Assets and liabilities measured at fair value on a recurring basis are summarized below:

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Fair Value Measurements Using:

Quoted Prices in Significant Other Significant Assets Active Markets Observable Inputs Unobservable Inputs (Liabilities) at (in millions) (Level 1) (Level 2) (Level 3) Fair Value

Assets (1) Fixed price swap – natural gas $ — $ 73 $ — $ 73 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 30 — 30 Fixed price swap – ethane — 13 — 13 Two-way costless collar – natural gas — 2 — 2 Two-way costless collar – oil — 7 — 7 Two-way costless collar – propane — 3 — 3 Three-way costless collar – natural gas — 147 — 147 Three-way costless collar – oil — 13 — 13 Basis swap – natural gas — 24 — 24 Purchased call option – natural gas — 3 — 3 Storage – fixed price swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (1) — (1) Three-way costless collar – natural gas — (113) — (113) Three-way costless collar – oil — (9) — (9) Basis swap – natural gas — (29) — (29) Sold call option – natural gas — (14) — (14)

Total $ — $ 169 $ — $ 169

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

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December 31, 2018

Fair Value Measurements Using:

Quoted Prices in Significant Other Significant Assets Active Markets Observable Inputs (Level Unobservable Inputs (Liabilities) at (in millions) (Level 1) 2) (Level 3) Fair Value

Assets Fixed price swap – natural gas $ — $ 38 $ — $ 38 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 11 — 11 Fixed price swap – ethane — 8 — 8 Two-way costless collar – natural gas — 11 — 11 Two-way costless collar – oil — 11 — 11 Three-way costless collar – natural gas — 75 — 75 Basis swap – natural gas — 11 — 11 Purchased call option – natural gas — 6 — 6 Interest rate swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (6) — (6) Fixed price swap – natural gas — (10) — (10) Fixed price swap – ethane — (3) — (3) Two-way costless collar – natural gas — (7) — (7) Two-way costless collar – oil — (1) — (1) Three-way costless collar – natural gas — (68) — (68) Basis swap – natural gas — (22) — (22) Sold call option – natural gas — (22) — (22)

Total $ — $ 52 $ — $ 52

The table below presents reconciliations for the change in net fair value of derivative assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the nine months ended September 30, 2019 and 2018. There were no derivatives presented as Level 3 in the third quarters of 2019 and 2018. The fair values of Level 3 derivative instruments were estimated using proprietary valuation models that utilized both market observable and unobservable parameters. Level 3 instruments presented in the table consisted of net derivatives valued using pricing models incorporating assumptions that, in the Company’s judgment, reflected reasonable assumptions a marketplace participant would have used as of September 30, 2018. Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

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Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the nine months ended September 30,

(in millions) 2019 2018

Balance at beginning of period $ — $ 22 Total gains (losses): Included in earnings — (17) (1) Settlements — 1 (2) Transfers into/out of Level 3 — (6)

Balance at end of period $ — $ —

Change in gains (losses) included in earnings relating to derivatives still held as of September 30 $ — $ —

(1) Includes $1 million amortization of premiums paid related to certain purchased natural gas call options for the nine months ended September 30, 2018.

(1) Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

Assets and liabilities measured at fair value on a nonrecurring basis

In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool included in the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, the Company determined the carrying value of certain non-full cost pool assets exceeded the fair value less costs to sell, the Company recorded an impairment charge of $161 million during the third quarter of 2018, of which $145 million related to midstream gathering assets and $15 million related to E&P assets which were both reflected as assets held for sale as of September 30, 2018. Additionally, the Company recorded an $1 million impairment related to other non-core assets that were not included in the sale. The estimated fair value

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of the gathering assets was based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of natural gas reserves, operating costs, projections of future rates of production, inflation factors and risk adjusted discount rates.

(12) DEBT

The components of debt as of September 30, 2019 and December 31, 2018 consisted of the following:

September 30, 2019

Unamortized Issuance Unamortized (in millions) Debt Instrument Expense Debt Discount Total Current portion of long-term debt: (1) 4.05% Senior Notes due January 2020 $ 52 $ — $ — $ 52

Total current portion of long-term debt $ 52 $ — $ — $ 52

Long-term debt: (2) Variable rate (3.420% at September 30, 2019) 2018 $ — $ — $ — $ — revolving credit facility, due April 2023 4.10% Senior Notes due March 2022 213 (1) — 212 (1)(3) 4.95% Senior Notes due January 2025 896 (7) (1) 888 (3) 7.50% Senior Notes due April 2026 639 (7) — 632 (3) 7.75% Senior Notes due October 2027 492 (5) — 487

Total long-term debt $ 2,240 $ (20) $ (1) $ 2,219

Total debt $ 2,292 $ (20) $ (1) $ 2,271

December 31, 2018

Unamortized Issuance Unamortized (in millions) Debt Instrument Expense Debt Discount Total Long-term debt: (2) Variable rate (3.920% at December 31, 2018) 2018 term $ — $ — $ — $ — loan facility, due April 2023 (1) 4.05% Senior Notes due January 2020 52 — — 52 4.10% Senior Notes due March 2022 213 (1) — 212 (1) 4.95% Senior Notes due January 2025 927 (7) (1) 919 7.50% Senior Notes due April 2026 650 (8) — 642 7.75% Senior Notes due October 2027 500 (7) — 493

Total long-term debt $ 2,342 $ (23) $ (1) $ 2,318

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (1) In February and June 2016, Moody’s and S&P downgraded certain senior notes, increasing the interest rates by 175 basis points effective July 2016. As a result of the downgrades, interest rates increased to 5.80% for the 2020 Notes and 6.70% for the 2025 Notes. S&P and Moody’s upgraded certain senior notes in April and May 2018, respectively. As a result of these upgrades, interest rates decreased to 5.30% for the 2020 Notes and 6.20% for the 2025 Notes effective July 2018. The first coupon payment to the bondholders at the lower interest rate was paid in January 2019.

(2) At September 30, 2019 and December 31, 2018, unamortized issuance expense of $9 million and $12 million, respectively, associated with the 2018 revolving credit facility is classified as other long-term assets on the consolidated balance sheets.

(3) During the third quarter of 2019, the Company purchased $31 million in 2025 Notes, $11 million in 2026 Notes and $8 million in 2027 Notes for $43 million in cash, reducing the Company’s outstanding debt by $50 million. This resulted in a gain on early extinguishment of debt of $7 million for the three and nine months ended September 30, 2019.

Credit Facilities

2018 Revolving Credit Facility

In April 2018, the Company replaced its 2016 credit facility (which consisted of a $1,191 million secured term loan and an unsecured $743 million revolving credit facility) with a new revolving credit facility (the “2018 credit facility”). Concurrent with the closing of the 2018 credit facility agreement on April 26, 2018, the Company repaid the $1,191 million secured term loan balance and recognized a loss on early debt extinguishment of $8 million on the consolidated income statement related to the unamortized issuance expense. In addition, approximately $4 million of unamortized issuance expense associated with the closed $743 million revolving credit facility was carried forward into the unamortized issuance expenses of the 2018 credit facility.

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The 2018 credit facility has an aggregate maximum revolving credit amount of $3.5 billion with a current aggregate commitment of $2.0 billion and a borrowing base (limit on availability) that is redetermined each April and October. The 2018 credit facility is secured by substantially all of the assets owned by the Company and its subsidiaries. The permitted lien provisions in the senior note indentures currently limit liens securing indebtedness to the greater of $2.0 billion and 25% of adjusted consolidated net tangible assets. On October 8, 2019, the Company entered into an amendment to the 2018 credit facility that, among other things, established the October 2019 borrowing base at $2.1 billion and extended the maturity date to April 2024.

Loans under the 2018 credit facility are subject to varying rates of interest based on whether the loan is a Eurodollar loan or an alternate base rate loan. Eurodollar loans bear interest at the Eurodollar rate, which is adjusted LIBOR for such interest period plus the applicable margin (as those terms are defined in the 2018 credit facility documentation). The applicable margin for Eurodollar loans under the 2018 credit facility ranges from 1.50% to 2.50% based on the Company’s utilization of the borrowing base under the 2018 credit facility. Alternate base rate loans bear interest at the alternate base rate plus the applicable margin. The applicable margin for alternate base rate loans under the 2018 credit facility ranges from 0.50% to 1.50% based on the Company’s utilization of the borrowing base under the 2018 credit facility.

The 2018 credit facility contains customary representations and warranties and contains covenants including, among others, the following:

• a prohibition against incurring debt, subject to permitted exceptions;

• a restriction on creating liens on assets, subject to permitted exceptions;

• restrictions on mergers and asset dispositions;

• restrictions on use of proceeds, investments, transactions with affiliates, or change of principal business; and

• maintenance of the following financial covenants, commencing with the fiscal quarter ending June 30, 2018:

1. Minimum current ratio of no less than 1.00 to 1.00, whereby current ratio is defined as the Company’s consolidated current assets (including unused commitments under the credit agreement, but excluding non-cash derivative assets) to consolidated current liabilities (excluding non-cash derivative obligations and current maturities of long-term debt).

2. Maximum total net leverage ratio of no greater than (i) with respect to each fiscal quarter ending during the period from June 30, 2018 through March 31, 2019, 4.50 to 1.00, (ii) with respect to each fiscal quarter ending during the period from June 30, 2019 through March 31, 2020, 4.25 to 1.00, and (iii) with respect to each fiscal quarter ending on or after June 30, 2020, 4.00 to 1.00. Total net leverage ratio is defined as total debt less cash on hand (up to the lesser of 10% of credit limit or $150 million) divided by consolidated EBITDAX for the last four consecutive quarters. EBITDAX, as defined in the Company’s 2018 credit agreement, excludes the effects of interest expense, depreciation, depletion and amortization, income tax, any non-cash impacts from impairments, certain non-cash hedging activities, stock-based compensation expense, non-cash gains or losses on asset sales, unamortized issuance cost, unamortized debt discount and certain restructuring costs.

The 2018 credit facility contains customary events of default that include, among other things, the failure to comply with the financial covenants described above, non-payment of principal, interest or fees, violation of covenants, inaccuracy of representations and warranties, bankruptcy and insolvency events, material judgments and cross-defaults to material indebtedness. If an event of default occurs and is continuing, all amounts outstanding under the 2018 credit facility may become immediately due and payable. As of September 30, 2019, the Company was in compliance with all of the covenants of the credit agreement.

Each United States domestic subsidiary of the Company for which the Company owns 100% guarantees the 2018 credit facility. Pursuant to requirements under the indentures governing its senior notes, each subsidiary that became a guarantor of the 2018 credit facility also became a guarantor of each of the Company’s senior notes. See Note 19 for the Company’s Condensed Consolidated Financial Information, presented in accordance with Rule 3-10 of Regulation S-X.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document As of September 30, 2019, the Company had $172 million in letters of credit and no borrowings outstanding under the 2018 revolving credit facility.

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Senior Notes

In January 2015, the Company completed a public offering of $850 million aggregate principal amount of its 4.05% senior notes due 2020 (the “2020 Notes”) and $1.0 billion aggregate principal amount of its 4.95% senior notes due 2025 (the “2025 Notes” together with the 2020 Notes, the “Notes”). The interest rates on the Notes are determined based upon the public bond ratings from Moody’s and S&P. Downgrades on the Notes from either rating agency increase interest costs by 25 basis points per downgrade level and upgrades decrease interest costs by 25 basis points per upgrade level, up to the stated coupon rate, on the following semi-annual bond interest payment. In February and June 2016, Moody’s and S&P downgraded the Notes, increasing the interest rates by 175 basis points effective July 2016. As a result of these downgrades, interest rates increased to 5.80% for the 2020 Notes and 6.70% for the 2025 Notes. In the event of future downgrades, the coupons for this series of notes are capped at 6.05% and 6.95%, respectively. The first coupon payment to the bondholders at the higher interest rates was paid in January 2017. S&P and Moody’s upgraded the Notes in April and May 2018, respectively. As a result of these upgrades, interest rates decreased to 5.30% for the 2020 Notes and 6.20% for the 2025 Notes effective July 2018. The first coupon payment to the bondholders at the lower interest rates was paid in January 2019.

In the third quarter of 2019, the Company repurchased $31 million of its 4.95% Senior Notes due 2025, $11 million of its 7.50% Senior Notes due 2025 and $8 million of its 7.75% Senior Notes due 2026 for $43 million, and recognized a $7 million gain on the extinguishment of debt.

(13) COMMITMENTS AND CONTINGENCIES

Operating Commitments and Contingencies

As of September 30, 2019, the Company’s contractual obligations for demand and similar charges under firm transportation and gathering agreements to guarantee access capacity on natural gas and liquids pipelines and gathering systems totaled approximately $8.2 billion, $752 million of which related to access capacity on future pipeline and gathering infrastructure projects that still require the granting of regulatory approvals and additional construction efforts. The Company also had guarantee obligations of up to $323 million of that amount. As of September 30, 2019, future payments under non-cancelable firm transportation and gathering agreements were as follows:

Payments Due by Period

Less than 1 More than 8 (in millions) Total Year 1 to 3 Years 3 to 5 Years 5 to 8 Years Years

Infrastructure currently in service $ 7,442 $ 681 $ 1,272 $ 1,075 $ 1,528 $ 2,886 (1) Pending regulatory approval and/or construction 752 19 73 75 139 446

Total transportation charges $ 8,194 $ 700 $ 1,345 $ 1,150 $ 1,667 $ 3,332

(1) Based on estimated in-service dates as of September 30, 2019.

In December 2018, the Company closed the Fayetteville Shale sale. The Company retained certain contractual commitments related to firm transportation, with the buyer obligated to pay the transportation provider directly for these charges. As of September 30, 2019, approximately $135 million of these contractual commitments remain of which the Company will reimburse the buyer for certain of these potential obligations up to approximately $70 million through December 2020 depending on the buyer’s actual use, and has recorded a $57 million liability for the estimated future payments, down from $88 million recorded at December 31, 2018.

In the first quarter of 2019, the Company agreed to purchase firm transportation with pipelines in the Appalachian Basin starting in 2021 and running through 2032 totaling $357 million in total contractual commitments, which is presented in the table above; the seller has agreed to reimburse $133 million of these commitments.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document In July 2019, the Company terminated its existing lease agreement and entered into a new lease agreement for a smaller portion of the headquarters office building, resulting in a contractual commitment totaling $87 million over the next ten years as of September 30, 2019.

Environmental Risk

The Company is subject to laws and regulations relating to the protection of the environment. Environmental and cleanup related costs of a non-capital nature are accrued when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. Management believes any future remediation or other compliance related costs will not have a material effect on the financial position, results of operations or cash flows of the Company.

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Litigation

The Company is subject to various litigation, claims and proceedings that have arisen in the ordinary course of business, such as for alleged breaches of contract, miscalculation of royalties, employment matters, traffic accidents, pollution, contamination, encroachment on others’ property or nuisance. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. As of September 30, 2019, the Company does not currently have any material amounts accrued related to litigation matters. For any matters not accrued for, it is not possible at this time to estimate the amount of any additional loss, or range of loss, that is reasonably possible, but, based on the nature of the claims, management believes that current litigation, claims and proceedings, individually or in aggregate and after taking into account insurance, are not likely to have a material adverse impact on the Company’s financial position, results of operations or cash flows, for the period in which the effect of that outcome becomes reasonably estimable. Many of these matters are in early stages, so the allegations and the damage theories have not been fully developed, and are all subject to inherent uncertainties; therefore, management’s view may change in the future.

As of September 30, 2019, all certified class actions against the Company regarding royalty payments in Arkansas have been resolved favorably to the Company or settled. Some actions filed on behalf of mineral interest owners who opted out of the class actions remain pending, but the Company does not expect these cases to have a material impact on its financial position, results of operations, or cash flows.

Indemnifications

The Company has provided certain indemnifications to various third parties, including in relation to asset and entity dispositions, securities offerings and other financings. In the case of asset dispositions, these indemnifications typically relate to disputes, litigation or tax matters existing at the date of disposition. The Company likewise obtains indemnification for future matters when it sells assets, although there is no assurance the buyer will be capable of performing those obligations. In the case of equity offerings, these indemnifications typically relate to claims asserted against underwriters in connection with an offering. No material liabilities have been recognized in connection with these indemnifications.

(14) INCOME TAXES

The Company’s effective tax rate was approximately 18% and 0% for the three months ended September 30, 2019 and 2018, respectively, and (105)% and 0% for the nine months ended September 30, 2019 and 2018, respectively. The change in the effective tax rate for the three and nine months ended September 30, 2019 was primarily the effect of releasing the valuation allowances previously recorded against the Company’s deferred tax assets. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgment regarding future taxable income, and considers the tax consequences in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is required. Such evidence can include current financial position, results of operations, both actual and forecasted, the reversal of deferred tax liabilities and tax planning strategies as well as the current and forecasted business economics of the oil and gas industry.

For the year ended December 31, 2018, the Company maintained a full valuation allowance against its deferred tax assets based on its conclusion, considering all available evidence (both positive and negative), that it was more likely than not that the deferred tax assets would not be realized. A significant item of objective negative evidence considered was the cumulative pre-tax loss incurred over the three-year period ended December 31, 2018, primarily due to impairments of proved natural gas and oil properties recognized in 2015 and 2016. As of the first quarter of 2019, the Company had sustained a three-year cumulative level of profitability. Based on this factor and other positive evidence including forecasted income, the Company concluded that it was more likely than not that the deferred tax assets would be realized and determined $522 million of the valuation allowance will be released. For the nine months ended September 30, 2019, the Company recorded a discrete tax benefit of $399 million, with the remainder being recognized through current period activity.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The Company expects to retain a valuation allowance of $87 million related to net operating losses in jurisdictions in which it no longer operates.

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(15) PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS

The Company maintains defined pension and other postretirement benefit plans, which cover substantially all of the Company’s employees. Net periodic pension costs include the following components for the three and nine months ended September 30, 2019 and 2018:

Consolidated Statements of For the three months ended For the nine months ended Operations Classification of September 30, September 30, (in millions) Net Periodic Benefit Cost 2019 2018 2019 2018 Service cost General and administrative expenses $ 1 $ 2 $ 5 $ 8 Interest cost Other Income (Loss), Net 2 1 4 4 Expected return on plan assets Other Income (Loss), Net (1) (2) (4) (6) Amortization of prior service cost Other Income (Loss), Net — — — — Amortization of net loss Other Income (Loss), Net — 1 1 1 Settlement loss Other Income (Loss), Net 1 — 5 —

Net periodic benefit cost $ 3 $ 2 $ 11 $ 7

The Company recognized a $5 million non-cash settlement loss related to $19 million of lump sum payments from the pension plan for the nine months ended September 30, 2019 for employees who were terminated primarily as a result of the Fayetteville Shale sale.

The Company’s other postretirement benefit plan had a net periodic benefit cost of less than $1 million for the three months ended September 30, 2019 and 2018 and a net periodic benefit cost of $1 million and $2 million for the nine months ended September 30, 2019 and 2018, respectively.

As of September 30, 2019, the Company has contributed $12 million to the pension and other postretirement benefit plans and does not expect to further contribute to its pension plan during the remainder of 2019. The Company recognized liabilities of $26 million and $13 million related to its pension and other postretirement benefits, respectively, as of September 30, 2019, compared to liabilities of $34 million and $13 million as of December 31, 2018, respectively.

The Company maintains a non-qualified deferred compensation supplemental retirement savings plan (“Non-Qualified Plan”) for certain key employees who may elect to defer and contribute a portion of their compensation, as permitted by the Non-Qualified Plan. Shares of the Company’s common stock purchased under the terms of the Non-Qualified Plan are included in treasury stock and totaled 5,115 shares and 10,653 shares at September 30, 2019 and December 31, 2018, respectively.

(16) STOCK-BASED COMPENSATION

The Company recognized the following amounts in total employee stock-based compensation costs for the three and nine months ended September 30, 2019 and 2018:

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Stock-based compensation cost – expensed $ 1 $ 7 $ 12 $ 20 Stock-based compensation cost – capitalized 1 3 7 10

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The Company’s stock-based compensation is classified as either equity awards or liability awards in accordance with GAAP. The fair value of an equity-classified award is determined at the grant date and is amortized to general and administrative expense and capitalized expense on a straight-line basis over the vesting period of the award. The fair value of a liability-classified award is determined on a quarterly basis beginning at the grant date until final vesting. Changes in the fair value of liability-classified awards are recorded to general and administrative expense over the vesting period of the award. A portion of this general and administrative expense is capitalized into natural gas and oil properties, included in property and equipment. Generally, stock options granted to employees and directors vest ratably over three years from the grant date and expire seven years from the date of grant. The Company issues shares of restricted stock or restricted stock units to employees and directors which generally vest over four years. Restricted stock, restricted stock units and stock options granted to participants under the 2013 Incentive Plan, as amended and restated, immediately vest upon death, disability or retirement (subject to a minimum of three years of service). The Company issues performance unit awards to employees which historically have vested at or over three years.

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In December 2018, the Company closed the sale of the equity in certain of its subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets in Arkansas. As part of this transaction, most employees associated with those assets became employees of the buyer although the employment of some was terminated. All affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited. Stock-based compensation costs recognized prior to the cancellation as either general and administrative expense or capitalized expense were reversed and the severance payments were subsequently recognized as restructuring charges for the year ended December 31, 2018 and the nine months ended September 30, 2019 on the consolidated statements of operations.

Equity-Classified Awards

The Company recognized the following amounts in employee equity-classified stock-based compensation costs for the three and nine months ended September 30, 2019 and 2018:

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Equity-classified awards – expensed $ 2 $ 3 $ 6 $ 12 Equity-classified awards – capitalized 1 2 3 6

As of September 30, 2019, there was $9 million of total unrecognized compensation cost related to the Company’s unvested equity- classified stock option grants, equity-classified restricted stock grants and equity-classified performance units. This cost is expected to be recognized over a weighted-average period of 1.1 years.

Equity-Classified Stock Options

The following table summarizes equity-classified stock option activity for the nine months ended September 30, 2019 and provides information for options outstanding and options exercisable as of September 30, 2019:

Number Weighted Average of Options Exercise Price

(in thousands) Outstanding at December 31, 2018 5,178 $ 17.06 Granted — $ — Exercised — $ — Forfeited or expired (76) $ 19.38

Outstanding at September 30, 2019 5,102 $ 17.02

Exercisable at September 30, 2019 4,680 $ 17.85

Equity-Classified Restricted Stock

The following table summarizes equity-classified restricted stock activity for the nine months ended September 30, 2019 and provides information for unvested shares as of September 30, 2019:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Number Weighted Average of Shares Fair Value

(in thousands) Unvested shares at December 31, 2018 2,717 $ 7.91 Granted 477 $ 3.09 Vested (1,101) $ 7.02 Forfeited (210) $ 8.38

Unvested shares at September 30, 2019 1,883 $ 7.17

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Equity-Classified Performance Units

The following table summarizes equity-classified performance unit activity for the nine months ended September 30, 2019 and provides information for unvested units as of September 30, 2019. The performance unit awards granted in 2017 include a market condition based exclusively on the fair value of the Total Shareholder Return (“TSR”), as calculated by a Monte Carlo model. The total fair value of the performance units is amortized to compensation expense on a straight line basis over the vesting period of the award. The grant date fair value is calculated using the closing price of the Company’s common stock at the grant date.

Number Weighted Average (1) of Shares Fair Value

(in thousands) Unvested units at December 31, 2018 598 $ 10.01 Granted — $ — Vested (371) $ 9.73 Forfeited (30) $ 10.47

Unvested units at September 30, 2019 197 $ 10.47

(1) The actual payout of shares may range from a minimum of zero shares to a maximum of two shares per unit contingent upon TSR. The performance units have a three-year vesting term and the actual disbursement of shares, if any, is determined during the first quarter following the end of the three-year vesting period.

Liability-Classified Awards

The Company recognized the following amounts in employee liability-classified stock-based compensation costs for the three and nine months ended September 30, 2019:

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Liability-classified stock-based compensation cost – expensed $ (1) $ 4 $ 6 $ 8 Liability-classified stock-based compensation cost – capitalized — 1 4 4

Liability-Classified Restricted Stock Units

In the first quarter of 2019 and 2018, the Company granted restricted stock units that vest over a period of four years and are payable in either cash or shares at the option of the Compensation Committee of the Company’s Board of Directors. The Company has accounted for these as liability-classified awards, and accordingly changes in the market value of the instruments will be recorded to general and administrative expense and capitalized expense over the vesting period of the award. As of September 30, 2019, there was $22 million of total unrecognized compensation cost related to liability-classified restricted stock units that is expected to be recognized over a weighted- average period of 3.0 years. The amount of unrecognized compensation cost for liability-classified awards will fluctuate over time as they are marked to market.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Number Weighted Average of Units Fair Value

(in thousands) Unvested shares at December 31, 2018 8,202 $ 3.41 Granted 8,659 $ 4.34 Vested (2,624) $ 4.09 Forfeited (1,000) $ 2.51

Unvested units at September 30, 2019 13,237 $ 1.93

Liability-Classified Performance Units

In 2019 and 2018, the Company granted performance units that vest at the end of, or over, a three-year period and are payable in either cash or shares at the option of the Compensation Committee of the Company’s Board of Directors. The Company has accounted for these as liability-classified awards, and accordingly changes in the fair market value of the instruments will be recorded to general and administrative expense and capitalized expense over the vesting period of the awards. The performance unit awards granted in 2018 include a performance condition based on cash flow per debt-adjusted share and two market conditions, one based on absolute TSR and the other on relative TSR as compared to a group of the Company’s peers. The performance unit awards granted in 2019 include a performance condition based on return on average capital employed and two market conditions, one based on absolute TSR and the other on relative TSR. The fair values of the two market conditions are calculated by Monte Carlo models on a quarterly basis. As of September 30, 2019, there was $7 million of total unrecognized compensation cost related to liability-classified performance units. This cost is expected to be

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recognized over a weighted-average period of 2.2 years. The amount of unrecognized compensation cost for liability-classified awards will fluctuate over time as they are marked to market. The final value of the performance unit awards is contingent upon the Company’s actual performance against these performance measures.

Number Weighted Average of Shares Fair Value

(in thousands) Unvested shares at December 31, 2018 2,803 $ 3.41 Granted 2,757 $ 4.34 Vested — $ — Forfeited (119) $ 4.65

Unvested units at September 30, 2019 5,441 $ 1.93

(17) SEGMENT INFORMATION

The Company’s reportable business segments have been identified based on the differences in products or services provided. Revenues for the E&P segment are derived from the production and sale of natural gas and liquids. The Midstream segment generates revenue through the marketing of both Company and third-party produced natural gas and liquids volumes.

Prior to December 2018, the Midstream segment included the Company’s natural gas gathering business associated with its Fayetteville Shale assets. With the closing of the Fayetteville Shale sale in December 2018, the Company’s marketing business comprises substantially all of the Company’s Midstream segment.

Summarized financial information for the Company’s reportable segments is shown in the following table. The accounting policies of the segments are the same as those described in Note 1 of the Notes to Consolidated Financial Statements included in Item 8 of the 2018 Annual Report. Management evaluates the performance of its segments based on operating income, defined as operating revenues less operating costs. Income before income taxes, for the purpose of reconciling the operating income amount shown below to consolidated income before income taxes, is the sum of operating income, interest expense, gain (loss) on derivatives and other income (loss). The “Other” column includes items not related to the Company’s reportable segments, including real estate and corporate items.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document E&P Midstream Other Total

Three months ended September 30, 2019 (in millions) Revenues from external customers $ 357 $ 279 $ — $ 636 Intersegment revenues (9) 313 — 304 Depreciation, depletion and amortization expense 123 2 — 125 Impairments — 2 — 2 (1) Operating loss (21) (8) — (29) (2) Interest expense 17 — — 17 Gain on derivatives 100 — — 100 Gain on extinguishment of debt — — 7 7 Other income (loss), net (4) — 2 (2) (2) Provision for income taxes 10 — — 10 (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 239 — 1 240

Three months ended September 30, 2018 Revenues from external customers $ 639 $ 312 $ — $ 951 Intersegment revenues (6) 600 — 594 Depreciation, depletion and amortization expense 140 11 — 151 Impairments 15 145 1 161 (6) (1) Operating income (loss) 175 (108) (1) 66 (2) Interest expense 29 — — 29 Loss on derivatives (65) — — (65) Other loss, net — (1) — (1) (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 295 — 3 298

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E&P Midstream Other Total

Nine months ended September 30, 2019 (in millions) Revenues from external customers $ 1,288 $ 1,005 $ — $ 2,293 Intersegment revenues (27) 1,154 — 1,127 Depreciation, depletion and amortization expense 345 7 — 352 Impairments 6 2 — 8 (1) Operating income (loss) 219 (13) — 206 (2) Interest expense 46 — — 46 Gain on derivatives 220 — — 220 Gain on early extinguishment of debt — — 7 7 Other income (loss), net (8) — 1 (7) (2) Benefit from income taxes (401) — — (401) (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 931 — 2 933

Nine months ended September 30, 2018 Revenues from external customers $ 1,809 $ 878 $ — $ 2,687 Intersegment revenues (19) 1,727 — 1,708 Depreciation, depletion and amortization expense 383 43 — 426 (8) Impairments 15 155 1 171 (6) (1) (9) Operating income (loss) 510 (64) (1) 445 (2) Interest expense 100 — — 100 Loss on derivatives (108) — — (108) Loss on early extinguishment of debt — — (8) (8) Other income (loss), net 3 (2) — 1 (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 1,025 9 5 1,039

(1) Operating income for the E&P segment includes $4 million and $2 million of restructuring charges for the three months ended September 30, 2019 and 2018, respectively, and $9 million and $18 million of restructuring charges for the nine months ended September 30, 2019 and 2018, respectively.

(2) Interest expense and provision (benefit) for income taxes by segment is an allocation of corporate amounts as they are incurred at the corporate level.

(3) E&P assets includes office, technology, water infrastructure, drilling rigs and other ancillary equipment not directly related to natural gas and oil properties. This also includes deferred tax assets which are an allocation of corporate amounts as they are incurred at the corporate level. At September 30, 2018, E&P assets included $106 million of assets held for sale.

(4) Other assets represent corporate assets not allocated to segments and assets for non-reportable segments. At September 30, 2019 and 2018, other assets included approximately $29 million and $9 million, respectively, in cash and cash equivalents, $61 million and $89 million, respectively, in income taxes receivable, $31 million and $69 million, respectively, in property, plant and equipment, $9 million and $12 million, respectively, in unamortized debt expense, $7 million and $12

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document million, respectively, in prepayments and $7 million and $8 million, respectively, in a non-qualified retirement plan. Additionally, the September 30, 2019 asset balance includes $84 million in right-of-use lease assets.

(5) Capital investments include decreases of $53 million and $31 million for the three months ended September 30, 2019 and 2018, respectively, and increases of $52 million and $21 million for the nine months ended September 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between years.

(6) Includes the impact of Fayetteville Shale-related E&P and Midstream operations which were divested on December 3, 2018.

(7) Midstream assets includes $738 million of assets held for sale at September 30, 2018.

(8) Includes a $10 million impairment related to certain non-core gathering assets.

(9) Operating loss for the Midstream segment includes a $10 million impairment related to certain non-core gathering assets and $2 million related to restructuring charges for the nine months ended September 30, 2018.

Included in intersegment revenues of the Midstream segment are $313 million and $559 million for the three months ended September 30, 2019 and 2018, respectively, and $1,154 million and $1,598 million for the nine months ended September 30, 2019 and 2018, respectively, for marketing of the Company’s E&P sales. Corporate assets include cash and cash equivalents, furniture and fixtures and other assets. Corporate general and administrative costs, depreciation expense and taxes, other than income taxes, are allocated to the segments.

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(18) NEW ACCOUNTING PRONOUNCEMENTS

New Accounting Standards Implemented

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. The codification was amended through additional ASUs. For public entities, Update 2016-02 became effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company adopted ASC 842 with an effective date of January 1, 2019 using the modified retrospective approach for all leases that existed at the date of initial application. The Company elected to apply the transition as of the beginning of the period of adoption. For leases that existed at the period of adoption on January 1, 2019, the incremental borrowing rate as of the application date was used to calculate the present value of remaining lease payments. Upon adoption of ASC 842, the Company recognized a discounted right-of-use asset and corresponding lease liability with opening balances of approximately $105 million as of January 1, 2019. The adoption of the standard did not materially change the Company’s consolidated statement of operations or its consolidated statement of cash flows. Please refer to Note 4 – “Leases” for full disclosure.

New Accounting Standards Not Yet Implemented

In June 2016, the FASB issued Accounting Standards Update No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“Update 2016-13”). Update 2016-13 replaces the incurred loss model with an expected loss model, which is referred to as the current expected credit loss (“CECL”) model. The CECL model is applicable to the measurement of credit losses on financial assets measured at amortized cost, including but not limited to trade receivables.

From evaluation of the Company’s current credit portfolio, which includes trade receivables from commodity sales, joint interest billings due from partners and other receivables, historical credit losses have been de minimis. The Company believes that its expected future credit losses will not be significant, and therefore Southwestern does not believe the adoption of the standard will have a material impact on its consolidated financial statements. The Company will continue to monitor changes in its credit portfolio as evaluation progresses. For public business entities, the new standard is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period.

(19) CONDENSED CONSOLIDATING FINANCIAL INFORMATION

In April, 2018, the Company entered into the 2018 credit facility. Pursuant to requirements under the indentures governing the Company’s senior notes, each 100% owned subsidiary that became a guarantor of the 2018 credit facility also became a guarantor of each of the Company’s senior notes (the “Guarantor Subsidiaries”). The Guarantor Subsidiaries also granted liens and security interests to support their guarantees under the 2018 credit facility but not of the senior notes. These guarantees are full and unconditional and joint and several among the Guarantor Subsidiaries. Certain of the Company’s operating units which are accounted for on a consolidated basis do not guarantee the 2018 credit facility and senior notes (“Non-Guarantor Subsidiaries”). See Note 12 – Debt for additional information on the Company’s 2018 credit facility and senior notes. At the closing of the Fayetteville Shale sale in December 2018, its subsidiaries being sold were released from these guarantees. See Note 2 for additional information on the divestiture of the Company’s Fayetteville Shale-related subsidiaries.

The following financial information reflects consolidating financial information of Southwestern Energy Company (the parent and issuer company), its Guarantor Subsidiaries on a combined basis and the Non-Guarantor Subsidiaries on a combined basis, prepared on the equity basis of accounting. The information is presented in accordance with the requirements of Rule 3-10 under the SEC’s Regulation S-X. The financial information may not necessarily be indicative of results of operations, cash flows or financial position had the Guarantor Subsidiaries operated as independent entities.

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 238 $ — $ — $ 238 Oil sales — 67 — — 67 NGL sales — 52 — — 52 Marketing — 279 — — 279

— 636 — — 636 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 189 — — 189 General and administrative expenses — 42 — — 42 Restructuring charges — 4 — — 4 Depreciation, depletion and amortization — 124 1 — 125 Impairments — 2 — — 2 Taxes, other than income taxes — 15 — — 15

— 664 1 — 665

Operating Loss — (28) (1) — (29)

Interest Expense, Net 17 — — — 17 Gain on Derivatives — 100 — — 100 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (2) — — (2) Equity in Earnings of Subsidiaries 59 (1) — (58) —

Income (Loss) Before Income Taxes 49 69 (1) (58) 59 Provision for Income Taxes — 10 — — 10

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49 Other Comprehensive Income 1 — — — 1

Comprehensive Income (Loss) $ 50 $ 59 $ (1) $ (58) $ 50

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 465 $ — $ — $ 465 Oil sales — 62 — — 62 NGL sales — 112 — — 112 Marketing — 287 — — 287 Gas gathering — 25 — — 25

— 951 — — 951 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 206 — — 206 General and administrative expenses — 51 — — 51 Restructuring charges — 2 — — 2 Depreciation, depletion and amortization — 151 — — 151 Impairments — 161 — — 161 Taxes, other than income taxes — 26 — — 26

— 885 — — 885

Operating Income — 66 — — 66

Interest Expense, Net 29 — — — 29 Loss on Derivatives — (65) — — (65) Other Loss, Net — (1) — — (1) Equity in Earnings of Subsidiaries — — — — —

Loss Before Income Taxes (29) — — — (29) Provision for Income Taxes — — — — —

Net Loss $ (29) $ — $ — $ — $ (29)

Net Loss $ (29) $ — $ — $ — $ (29) Other Comprehensive Income 4 — — — 4

Comprehensive Loss $ (25) $ — $ — $ — $ (25)

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 943 $ — $ — $ 943 Oil sales — 153 — — 153 NGL sales — 191 — — 191 Marketing — 1,004 — — 1,004 Other — 2 — — 2 — 2,293 — — 2,293 Operating Costs and Expenses: Marketing purchases — 1,022 — — 1,022 Operating expenses — 523 — — 523 General and administrative expenses — 119 — — 119 Loss on sale of operating assets — 3 — — 3 Restructuring charges — 9 — — 9 Depreciation, depletion and amortization — 351 1 — 352 Impairments — 8 — — 8 Taxes, other than income taxes — 51 — — 51 — 2,086 1 — 2,087

Operating Income (Loss) — 207 (1) — 206 Interest Expense, Net 46 — — — 46 Gain on Derivatives — 220 — — 220 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (7) — — (7) Equity in Earnings of Subsidiaries 820 (1) — (819) —

Income (Loss) Before Income Taxes 781 419 (1) (819) 380 Benefit from Income Taxes — (401) — — (401) Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781

Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781 Other Comprehensive Income 5 — — — 5

Comprehensive Income (Loss) $ 786 $ 820 $ (1) $ (819) $ 786

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 1,412 $ — $ — $ 1,412 Oil sales — 141 — — 141 NGL sales — 252 — — 252 Marketing — 805 — — 805 Gas gathering — 73 — — 73 Other — 4 — — 4 — 2,687 — — 2,687 Operating Costs and Expenses: Marketing purchases — 808 — — 808 Operating expenses — 588 — — 588 General and administrative expenses — 165 — — 165 Restructuring charges — 20 — — 20 Depreciation, depletion and amortization — 426 — — 426 Impairments — 171 — — 171 Taxes, other than income taxes — 64 — — 64 — 2,242 — — 2,242

Operating Income — 445 — — 445 Interest Expense, Net 100 — — — 100 Loss on Derivatives — (108) — — (108) Loss on Early Extinguishment of Debt (8) — — — (8) Other Income, Net — 1 — — 1 Equity in Earnings of Subsidiaries 338 — — (338) —

Income (Loss) Before Income Taxes 230 338 — (338) 230 Provision for Income Taxes — — — — — Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230

Participating securities – mandatory convertible 1 — — — 1 preferred stock

Net Income (Loss) Attributable to Common Stock $ 229 $ 338 $ — $ (338) $ 229

Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230 Other Comprehensive Income 4 — — — 4

Comprehensive Income (Loss) $ 234 $ 338 $ — $ (338) $ 234

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated September 30, 2019 ASSETS Cash and cash equivalents $ 29 $ — $ — $ — $ 29 Accounts receivable, net — 323 — — 323 Other current assets 6 275 — — 281 Total current assets 35 598 — — 633

Intercompany receivables 7,957 — — (7,957) —

Natural gas and oil properties, using the full cost — 25,006 54 — 25,060 method Other 179 314 29 — 522 Less: Accumulated depreciation, depletion and (149) (20,176) (58) — (20,383) amortization Total property and equipment, net 30 5,144 25 — 5,199

Investments in subsidiaries (equity method) — 23 — (23) — Other long-term assets 99 667 — — 766

TOTAL ASSETS $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

LIABILITIES AND EQUITY Current portion of long-term debt $ 52 $ — $ — $ — $ 52 Accounts payable 77 462 — — 539 Other current liabilities 130 159 — — 289 Total current liabilities 259 621 — — 880

Intercompany payables — 7,955 2 (7,957) —

Long-term debt 2,219 — — — 2,219 Pension and other postretirement liabilities 39 — — — 39 Other long-term liabilities 87 238 — — 325 Negative carrying amount of subsidiaries, net 2,382 — — (2,382) — Total long-term liabilities 4,727 238 — (2,382) 2,583 Commitments and contingencies Total equity (accumulated deficit) 3,135 (2,382) 23 2,359 3,135

TOTAL LIABILITIES AND EQUITY $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated December 31, 2018 ASSETS Cash and cash equivalents $ 201 $ — $ — $ — $ 201 Accounts receivable, net 4 577 — — 581 Other current assets 8 166 — — 174

Total current assets 213 743 — — 956

Intercompany receivables 7,932 — — (7,932) —

Natural gas and oil properties, using the full cost — 24,128 52 — 24,180 method Other 197 301 27 — 525 Less: Accumulated depreciation, depletion and (154) (19,840) (55) — (20,049) amortization Total property and equipment, net 43 4,589 24 — 4,656

Investments in subsidiaries (equity method) — 24 — (24) — Other long-term assets 19 166 — — 185

TOTAL ASSETS $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

LIABILITIES AND EQUITY Accounts payable $ 113 $ 496 $ — $ — $ 609 Other current liabilities 115 122 — — 237

Total current liabilities 228 618 — — 846

Intercompany payables — 7,932 — (7,932) —

Long-term debt 2,318 — — — 2,318 Pension and other postretirement liabilities 46 — — — 46 Other long-term liabilities 54 171 — — 225 Negative carrying amount of subsidiaries, net 3,199 — — (3,199) —

Total long-term liabilities 5,617 171 — (3,199) 2,589 Commitments and contingencies Total equity (accumulated deficit) 2,362 (3,199) 24 3,175 2,362

TOTAL LIABILITIES AND EQUITY $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

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CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Net cash provided by (used in) operating activities $ 1,154 $ 404 $ — $ (819) $ 739 Investing activities: Capital investments — (875) (2) — (877) Proceeds from sale of property and equipment — 42 — — 42

Net cash used in investing activities — (833) (2) — (835) Financing activities: Intercompany activities (1,250) 429 2 819 — Payments on long-term debt (43) — — — (43) Change in bank drafts outstanding (11) — — — (11) Purchase of treasury stock (21) — — — (21) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (1,326) 429 2 819 (76)

Decrease in cash and cash equivalents (172) — — — (172) Cash and cash equivalents at beginning of year 201 — — — 201

Cash and cash equivalents at end of period $ 29 $ — $ — $ — $ 29

Nine months ended September 30, 2018 Net cash provided by (used in) operating activities $ 57 $ 1,396 $ — $ (482) $ 971 Investing activities: Capital investments (12) (996) — — (1,008) Proceeds from sale of property and equipment — 9 — 9 Other 4 — — — 4

Net cash used in investing activities (8) (987) — — (995) Financing activities: Intercompany activities (71) (411) — 482 — Payments on long-term debt (1,191) — — — (1,191) Payments on revolving credit facility (1,122) — — — (1,122) Borrowings under revolving credit facility 1,482 — — — 1,482 Change in bank drafts outstanding 10 — — — 10 Debt issuance costs (9) — — — (9) Purchase of treasury stock (25) — — — (25) Preferred stock dividend (27) — — — (27) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (954) (411) — 482 (883)

Decrease in cash and cash equivalents (905) (2) — — (907) Cash and cash equivalents at beginning of year 914 2 — — 916

Cash and cash equivalents at end of period $ 9 $ — $ — $ — $ 9

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following updates information as to Southwestern Energy Company’s financial condition provided in our 2018 Annual Report and analyzes the changes in the results of operations between the three and nine month periods ended September 30, 2019 and 2018. For definitions of commonly used natural gas and oil terms used in this Quarterly Report, please refer to the “Glossary of Certain Industry Terms” provided in our 2018 Annual Report.

The following discussion contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those anticipated in forward-looking statements for many reasons, including the risks described in “Cautionary Statement About Forward-Looking Statements” in the forepart of this Quarterly Report, in Item 1A, “Risk Factors” in Part I and elsewhere in our 2018 Annual Report, and Item 1A, “Risk Factors” in Part II in this Quarterly Report and any other quarterly report on Form 10-Q filed during the fiscal year. You should read the following discussion with our consolidated financial statements and the related notes included in this Quarterly Report.

OVERVIEW

Background

Southwestern Energy Company (including its subsidiaries, collectively, “we,” “our,” “us,” “the Company” or “Southwestern”) is an independent energy company engaged in natural gas, oil and natural gas liquids (“NGL”) exploration, development and production, which we refer to as “E&P.” We are also focused on creating and capturing additional value through our marketing business, which we refer to as “Midstream.” We conduct most of our businesses through subsidiaries, and we currently operate exclusively in the lower 48 United States. Our historical financial and operating results include the Fayetteville Shale E&P and related midstream gathering businesses, which were sold in early December 2018.

E&P. Our primary business is the exploration for and production of natural gas, oil and NGLs, with our ongoing operations focused on the development of unconventional natural gas reservoirs located in Pennsylvania and West Virginia. Our operations in northeast Pennsylvania, which we refer to as “Northeast Appalachia,” are primarily focused on the unconventional natural gas reservoir known as the Marcellus Shale. Our operations in West Virginia and southwest Pennsylvania, which we refer to as “Southwest Appalachia,” are focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and oil reservoirs. Collectively, our properties in Pennsylvania and West Virginia are herein referred to as the “Appalachian Basin.” We also operate drilling rigs located in Pennsylvania and West Virginia, and we provide certain oilfield products and services, principally serving our E&P operations through vertical integration.

Midstream. Our marketing activities capture opportunities that arise through the marketing and transportation of natural gas, oil and NGLs primarily produced in our E&P operations. In December 2018, we divested almost all of our gathering assets as part of the Fayetteville Shale sale.

Recent Financial and Operating Results

Significant third quarter 2019 operating and financial results include:

Total Company

• Net income attributable to common stock of $49 million, or $0.09 per diluted share, increased 269% compared to net loss attributable to common stock of $29 million, or ($0.05) per diluted share, for the same period in 2018. The increase was primarily due to a $165 million positive impact of derivatives, including a $94 million improvement in settled derivatives as compared to the same period in 2018, which was partially offset by decreased operating income and the divestiture of the Fayetteville Shale E&P and related midstream gathering assets on December 3, 2018.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document • Operating loss of $29 million decreased 144% compared to operating income of $66 million for the same period in 2018 on a consolidated basis. The decrease was primarily due to lower margins associated with reduced commodity prices and the divestiture of the Fayetteville Shale E&P and related midstream gathering assets in December 2018.

• Net cash provided by operating activities of $196 million decreased 36% from $307 million for the same period in 2018 primarily due to the decrease in operating income net of depreciation, depletion and amortization and impairments, partially offset by the improvement in settled derivatives discussed above.

• Total capital investing of $240 million decreased 19% from $298 million for the same period in 2018.

• We repurchased $50 million of our senior notes at a discount and recognized a gain on the extinguishment of debt of $7 million.

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E&P

• E&P segment operating loss of $21 million decreased 112% from an operating income of $175 million for the same period in 2018.

• Total net production of 202 Bcfe was comprised of 78% natural gas and 22% oil and NGLs. E&P segment production volumes of 252 Bcfe for the third quarter of 2018 included 65 Bcf of production related to our operations in the Fayetteville Shale, which was sold in December 2018. Excluding the impact of the production related to the sold Fayetteville Shale assets, our production increased 8% from 187 Bcfe in the same period in 2018, and our liquids production increased 19% over the same period.

• Excluding the effect of derivatives, our realized natural gas price of $1.45 per Mcf decreased 32% from the same period in 2018, our realized oil price of $46.54 per Bbl decreased 24% from the same period in 2018 and our realized NGL price of $8.89 per Bbl decreased 59% from the same period in 2018. Our total weighted average realized price excluding the effect of derivatives of $1.72 per Mcfe decreased 31% from the same period in 2018.

• E&P segment invested $239 million in capital; drilling 24 wells, completing 30 wells and placing 34 wells to sales.

Outlook

We expect to continue to exercise capital discipline through a fully-funded 2019 capital investment program, and we expect to apply the same principles in 2020. We remain committed to our focus on optimizing our portfolio by concentrating our efforts on our highest return investment opportunities, looking for ways to maximize margins and optimize our cost structure in each core area of our business and further developing our knowledge of our asset base.

Lower natural gas, oil and NGL prices presents challenges to our industry and our Company, as do changes in laws, regulations and investor sentiment and other key factors described in “Risk Factors” in our 2018 Annual Report. In 2019, gains on derivatives have offset the majority of the impact of the recent decline in prices, and we currently have derivative positions in place for portions of our expected 2020 and 2021 production at prices above current market levels. There can be no assurance that we will be able to add derivative positions to cover the remainder of our expected production at favorable prices. See “Quantitative and Qualitative Disclosures About Market Risk” in Item 3 and Note 9, in the consolidated financial statements included in this Quarterly Report for further details.

RESULTS OF OPERATIONS

The following discussion of our results of operations for our segments is presented before intersegment eliminations. We evaluate our segments as if they were stand-alone operations and accordingly discuss their results prior to any intersegment eliminations. Restructuring charges, interest expense, gain (loss) on derivatives, loss on early extinguishment of debt and income tax expense are discussed on a consolidated basis.

E&P

The 2018 information in the table below includes the financial results from E&P assets in the Fayetteville Shale that were sold in December 2018.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Revenues $ 348 $ 633 $ 1,261 $ 1,790 Operating costs and expenses 369 458 1,042 1,280

Operating income $ (21) $ 175 $ 219 $ 510

(1) Gain on derivatives, settled $ 88 $ (6) $ 112 $ 5

(1) Represents the gain on settled commodity derivatives.

Operating Income

• E&P segment operating income for the third quarter of 2018 included $23 million related to our operations in the Fayetteville Shale, which was sold in December 2018. Excluding amounts relating to the Fayetteville Shale, E&P segment operating income decreased $173 million for the three months ended September 30, 2019, compared to the same period in 2018, primarily due to lower margins associated with decreased commodity pricing.

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• Operating income for the E&P segment included $74 million related to our operations in the Fayetteville Shale for the nine months ended September 30, 2018. Excluding the amounts related to the Fayetteville Shale, operating income for the E&P segment decreased $217 million for the nine months ended September 30, 2019, compared to the same period in 2018, primarily due to lower margins associated with decreased commodity pricing.

Revenues

The following illustrates the effects on sales revenues associated with changes in commodity prices and production volumes:

Three months ended September 30,

Natural (in millions except percentages) Gas Oil NGLs Total

2018 sales revenues $ 460 $ 61 $ 112 $ 633 (1) Changes associated with the Fayetteville Shale sale (140) — — (140) 2018 sales revenues, net of Fayetteville Shale revenues 320 61 112 493 Changes associated with prices (107) (21) (75) (203) Changes associated with production volumes 17 26 15 58

2019 sales revenues $ 230 $ 66 $ 52 $ 348

Increase (decrease) from 2018, net of Fayetteville Shale revenues (28)% 8 % (54)% (29)%

(1) This amount represents the revenues associated with the Fayetteville Shale assets, which were sold on December 3, 2018. There were no Fayetteville Shale revenues in 2019.

Nine months ended September 30,

Natural (in millions except percentages) Gas Oil NGLs Total (1) 2018 sales revenues $ 1,395 $ 139 $ 252 $ 1,786 (2) Changes associated with the Fayetteville Shale sale (431) — — (431) 2018 sales revenues, net of Fayetteville Shale revenues 964 139 252 1,355 Changes associated with prices (128) (40) (109) (277) Changes associated with production volumes 82 52 48 182 (3) 2019 sales revenues $ 918 $ 151 $ 191 $ 1,260

Increase (decrease) from 2018, net of Fayetteville Shale revenues (5)% 9 % (24)% (7)%

(1) Excludes $4 million in other operating revenues for the nine months ended September 30, 2018 related to third-party water sales.

(2) This amount represents the revenues associated with the Fayetteville Shale assets, which were sold on December 3, 2018. There were no Fayetteville Shale revenues in 2019.

(3) Excludes $1 million in other operating revenues for the nine months ended September 30, 2019 related to third-party water sales.

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Production Volumes

For the three months ended For the nine months ended

September 30, Increase/ September 30, Increase/ Production volumes: 2019 2018 (Decrease) 2019 2018 (Decrease)

Natural Gas (Bcf) Northeast Appalachia 118 121 (2)% 343 341 1% Southwest Appalachia 40 29 38% 106 73 45% (1) Fayetteville Shale — 65 (100)% — 199 (100)%

Total 158 215 (27)% 449 613 (27)%

Oil (MBbls) Southwest Appalachia 1,413 989 43% 3,193 2,290 39% Other 6 9 (33)% 17 44 (61)% Total 1,419 998 42% 3,210 2,334 38%

NGL (MBbls) Southwest Appalachia 5,908 5,180 14% 17,003 14,248 19% Other 3 1 200% 8 24 (67)% Total 5,911 5,181 14% 17,011 14,272 19%

Production volumes by area: (Bcfe) (2) Northeast Appalachia 118 121 (2)% 343 341 1% (2) Southwest Appalachia 84 66 27% 227 172 32% (1) Fayetteville Shale — 65 (100)% — 199 (100)%

Total 202 252 (20)% 570 712 (20)%

Production percentage: (Bcfe) Natural gas 78 % 86 % 79 % 86 % Oil 4 % 2 % 3 % 2 % NGL 18 % 12 % 18 % 12 % Total 100 % 100 % 100 % 100 %

(1) The Fayetteville Shale assets were sold on December 3, 2018.

(2) Approximately 201 Bcfe and 569 Bcfe for the three and nine months ended September 30, 2019, respectively, and approximately 186 Bcfe and 511 Bcfe for the three and nine months ended September 30, 2018, respectively, was produced from the Marcellus Shale formation.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document • E&P segment production volumes for the third quarter of 2018 included 65 Bcf of production related to our operations in the Fayetteville Shale, which was sold in December 2018. Excluding this amount, production volumes for our E&P segment increased by 15 Bcfe for the three months ended September 30, 2019, compared to the same period in 2018, primarily due to a 27% increase in production volumes from Southwest Appalachia.

• E&P segment production volumes for the nine months ended September 30, 2018 included 199 Bcf of production related to our operations in the Fayetteville Shale, which was sold in December 2018. Excluding this amount, production volumes for our E&P segment increased by 57 Bcfe for the nine months ended September 30, 2019 compared to the same period in 2018, primarily due to a 32% increase in production volumes from Southwest Appalachia.

• Oil and NGL production increased 42% and 14%, respectively, for the three months ended September 30, 2019, compared to the same period in 2018, reflecting our shifting commodity production mix towards liquids.

• Oil and NGL production increased 38% and 19%, respectively, for the nine months ended September 30, 2019, compared to the same period in 2018.

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Commodity Prices

The price we expect to receive for our production is a critical factor in determining the capital investments we make to develop our properties. Commodity prices fluctuate due to a variety of factors we cannot control or predict, including increased supplies of natural gas, oil or NGLs due to greater exploration and development activities, weather conditions, political and economic events, and competition from other energy sources. These factors impact supply and demand, which in turn determine the sales prices for our production. In addition to these factors, the prices we realize for our production are affected by our hedging activities as well as locational differences in market prices, including basis differentials. We will continue to evaluate the commodity price environments and adjust the pace of our activity in order to maintain appropriate liquidity and financial flexibility.

For the three months ended For the nine months ended

September 30, Increase/ September 30, Increase/ 2019 2018 (Decrease) 2019 2018 (Decrease) Natural Gas Price: (1) NYMEX Henry Hub Price ($/MMBtu) $ 2.23 $ 2.90 (23)% $ 2.67 $ 2.90 (8)% (2) Discount to NYMEX (0.78) (0.76) 3% (0.63) (0.62) 2%

Average realized gas price, excluding derivatives ($/Mcf) $ 1.45 $ 2.14 (32)% $ 2.04 $ 2.28 (11)%

Loss on settled financial basis derivatives ($/Mcf) (0.01) (0.03) (0.02) (0.04)

Gain on settled commodity derivatives ($/Mcf) 0.43 0.05 0.18 0.07

Average realized gas price, including derivatives ($/Mcf) $ 1.87 $ 2.16 (13)% $ 2.20 $ 2.31 (5)%

Oil Price:

WTI oil price ($/Bbl) $ 56.45 $ 69.50 (19)% $ 57.06 $ 66.75 (15)% Discount to WTI (9.91) (8.30) 19% (9.92) (7.24) 37%

Average oil price, excluding derivatives ($/Bbl) $ 46.54 $ 61.20 (24)% $ 47.14 $ 59.51 (21)%

Gain (loss) on settled derivatives ($/Bbl) 3.13 (1.24) 2.60 (0.82)

Average oil price, including derivatives ($/Bbl) $ 49.67 $ 59.96 (17)% $ 49.74 $ 58.69 (15)%

NGL Price:

Average net realized NGL price, excluding derivatives ($/ $ 8.89 $ 21.60 (59)% $ 11.24 $ 17.65 (36)% Bbl)

Gain (loss) on settled derivatives ($/Bbl) 3.04 (2.17) 1.94 (0.90)

Average net realized NGL price, including derivatives ($/ $ 11.93 $ 19.43 (39)% $ 13.18 $ 16.75 (21)% Bbl) Percentage of WTI, excluding derivatives 16 % 31 % 20 % 26 %

Total Weighted Average Realized Price:

Excluding derivatives ($/Mcfe) $ 1.72 $ 2.51 (31)% $ 2.21 $ 2.51 (12)%

Including derivatives ($/Mcfe) $ 2.16 $ 2.48 (13)% $ 2.41 $ 2.51 (4)%

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (1) Based on last day settlement prices from monthly futures contracts.

(2) This discount includes a basis differential, a heating content adjustment, physical basis sales, third-party transportation charges and fuel charges, and excludes financial basis hedges.

We receive a sales price for our natural gas at a discount to average monthly NYMEX settlement prices based on heating content of the gas, locational basis differentials and transportation and fuel charges. Additionally, we receive a sales price for our oil and NGLs at a difference to average monthly West Texas Intermediate settlement and Mont Belvieu NGL composite prices, respectively, due to a number of factors including product quality, composition and types of NGLs sold, locational basis differentials, transportation and fuel charges.

We regularly enter into various hedging and other financial arrangements with respect to a portion of our projected natural gas, oil and NGL production in order to ensure certain desired levels of cash flow and to minimize the impact of price fluctuations, including fluctuations in locational market differentials. We refer you to Item 3, “Quantitative and Qualitative Disclosures About Market Risk” and Note 9 to the consolidated financial statements, included in this Quarterly Report.

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The table below presents the amount of our future production in which the basis is protected as of September 30, 2019:

Volume (Bcf) Basis Differential Basis Swaps – Natural Gas 2019 35 $ (0.40) 2020 141 (0.31) 2021 65 (0.48) 2022 45 (0.50)

Total 286

Physical NYMEX Sales Arrangements – Natural Gas 2019 81 $ (0.07) 2020 143 (0.06)

Total 224

In addition to protecting basis, the table below presents the amount of our future production in which price is financially protected as of September 30, 2019:

Remaining Full Year Full Year Full Year 2019 2020 2021 2022

Natural gas (Bcf) 111 360 134 23

Oil (MBbls) 1,152 2,837 730 —

Propane (MBbls) 1,116 3,294 456 —

Ethane (MBbls) 2,194 3,843 — —

Total financial protection on future production (Bcfe) 138 420 141 23

We refer you to Note 9 of the consolidated financial statements included in this Quarterly Report for additional details about our derivative instruments.

Operating Costs and Expenses

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September 30, Increase/ September 30, Increase/ (in millions except percentages) 2019 2018 (Decrease) 2019 2018 (Decrease) Lease operating expenses $ 189 $ 232 (19)% $ 524 $ 660 (21)% (1) (1) (2) General & administrative expenses 39 44 (11)% 108 145 (26)% Restructuring charges 4 2 100% 9 18 (50)% Taxes, other than income taxes 14 25 (44)% 50 59 (15)% Full cost pool amortization 123 131 (6)% 328 356 (8)% Non-full cost pool DD&A — 9 (100)% 17 27 (37)% Impairments — 15 (100)% 6 15 (60)%

Total operating costs $ 369 $ 458 (19)% $ 1,042 $ 1,280 (19)%

(1) Includes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building and $3 million of legal settlement charges for the three and nine months ended September 30, 2019.

(2) Includes $8 million of legal settlement charges for the nine months ended September 30, 2018.

For the three months ended For the nine months ended September 30, Increase/ September 30, Increase/

Average unit costs per Mcfe: 2019 2018 (Decrease) 2019 2018 (Decrease) (1) Lease operating expenses $ 0.94 $ 0.92 2% $ 0.92 $ 0.93 (1)% (2) (3) (3) (4) General & administrative expenses $ 0.15 $ 0.18 (17)% $ 0.17 $ 0.19 (11)% (5) Taxes, other than income taxes $ 0.08 $ 0.09 (11)% $ 0.09 $ 0.08 13% Full cost pool amortization $ 0.58 $ 0.52 12% $ 0.57 $ 0.50 14%

(1) Includes post-production costs such as gathering, processing, fractionation and compression.

(2) Excludes restructuring charges.

(3) Excludes a $6 million residual value guarantee short-fall payment to the previous lessor of our headquarters building and $3 million of legal settlement charges for the three and nine months ended September 30, 2019.

(4) Excludes $17 million of restructuring charges and $8 million of legal settlement charges for the nine months ended September 30, 2018.

(5) Excludes $1 million of restructuring charges for the nine months ended September 30, 2018.

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Lease Operating Expenses

• Lease operating expenses per Mcfe increased $0.02 for the three months ended September 30, 2019, compared to the same period of 2018, as a $0.04 per Mcfe increase primarily related to increased compression charges and a shift towards liquids production, which includes processing fees, was partially offset by a $0.02 per Mcfe decrease associated with the Fayetteville Shale sale.

• Lease operating expenses per Mcfe decreased $0.01 for the nine months ended September 30, 2019, compared to the same period of 2018, as a $0.02 per Mcfe decrease associated with the Fayetteville Shale sale was partially offset by a $0.01 per Mcfe increase primarily related to a shift towards liquids production, which includes processing fees.

General and Administrative Expenses

• General and administrative expenses in the third quarter of 2019 included a $6 million residual value guarantee shortfall payment to the previous lessor of our headquarters building and $3 million in legal settlement charges. Excluding these amounts, general and administrative expenses decreased $14 million for the three months ended September 30, 2019, respectively, compared to the same period in 2018, primarily due to decreased personnel costs and the implementation of cost reduction initiatives.

• General and administrative expenses in the first three quarters of 2019 included a $6 million residual value guarantee shortfall payment to the previous lessor of our headquarters building and $3 million in legal settlement charges. The first three quarters of 2018 included $8 million in legal settlement charges. Excluding these amounts, general and administrative expenses decreased $38 million for the nine months ended September 30, 2019, compared to the same period of 2018, primarily due to decreased personnel costs and the implementation of cost reduction initiatives.

Taxes, Other than Income Taxes

• On a per Mcfe basis, taxes, other than income taxes, may vary from period to period due to changes in ad valorem and severance taxes that result from the mix of our production volumes and fluctuations in commodity prices. Taxes, other than income taxes, decreased $0.01 for the three months ended September 30, 2019, compared to the same period of 2018, primarily due to lower effective severance tax rates in Southwest Appalachia.

• Taxes, other than income taxes, per Mcfe increased $0.01 for the nine months ended September 30, 2019, compared to the same period of 2018, primarily due to an $8 million severance tax refund received in the second quarter of 2018.

Full Cost Pool Amortization

• Our full cost pool amortization rate increased $0.06 per Mcfe and $0.07 per Mcfe for the three and nine months ended September 30, 2019, respectively, as compared to the same periods of 2018. The average amortization rate increased primarily as a result of the impact of capital investment and the further evaluation of our unproved properties during the past twelve months and the impact of the Fayetteville Shale sale, which reduced our total natural gas reserves along with the carrying value of our full cost pool assets.

• The amortization rate is impacted by the timing and amount of reserve additions and the costs associated with those additions, revisions of previous reserve estimates due to both price and well performance, write-downs that result from full cost ceiling impairments, proceeds from the sale of properties that reduce the full cost pool, and the levels of costs subject to amortization. We cannot predict our future full cost pool amortization rate with accuracy due to the variability of each of the factors discussed above, as well as other factors, including but not limited to the uncertainty of the amount of future reserve changes.

• Unevaluated costs excluded from amortization were $1.5 billion at September 30, 2019, compared to $1.8 billion at December 31, 2018. The unevaluated costs excluded from amortization decreased as the impact of $207 million of unevaluated capital invested during the period was more than offset by the evaluation of previously unevaluated properties totaling $444 million.

Impairments

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document • During the nine months ended September 30, 2019, we recognized a $6 million impairment to non-core gathering assets.

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• In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool associated with the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, we determined the carrying value of certain non-full cost pool E&P assets exceeded the fair value less costs to sell. As a result, an impairment charge of $15 million was recorded during the three and nine months ended September 30, 2018.

Midstream

For the three months ended For the nine months ended

September 30, Increase/ September 30, Increase/ (in millions except percentages) 2019 2018 (Decrease) 2019 2018 (Decrease) Marketing revenues $ 592 $ 846 (30)% $ 2,158 $ 2,403 (10)% (1) (1) Gas gathering revenues — 66 (100)% — 202 (100)% Other operating revenues — — —% 1 — 100% Marketing purchases 592 833 (29)% 2,148 2,368 (9)% (1) (1) (2) Operating costs and expenses 6 42 (86)% 19 146 (87)% (5) (3)(5) Impairments 2 145 (99)% 2 155 (99)% Loss on sale of operating assets — — 100% 3 — 100%

Operating loss $ (8) $ (108) (93)% $ (13) $ (64) (80)%

(4) (4) Volumes marketed (Bcfe) 279 301 (7)% 823 855 (4)% (1) (1) Volumes gathered (Bcf) — 103 (100)% — 311 (100)%

(4) (4) Percent natural gas marketed from affiliated E&P 81 % 95 % 77 % 95 % operations Affiliated E&P oil and NGL production marketed 73 % 65 % 74 % 67 %

(1) Reflects the sale of our Fayetteville Shale-related gathering business, which was sold in December 2018.

(2) Includes $2 million of restructuring charges for the nine months ended September 30, 2018.

(3) Includes a $10 million impairment related to certain non-core gathering assets for the nine months ended September 30, 2018.

(4) Includes the effect of the purchase and sale of a portion of the production from the buyer of the Fayetteville Shale, which was sold in December 2018.

(5) Includes a $145 million impairment related to the gathering assets associated with the Fayetteville Shale sale in December 2018.

Operating Income

• Midstream operating loss for the third quarter of 2018 included a $114 million loss related to our gathering operations in the Fayetteville Shale, which were sold in December 2018. Excluding this amount, operating income decreased $14 million for the three months ended September 30, 2019, compared to the same period in 2018, primarily due to a $13 million decrease in the marketing margin and $2 million in impairments recorded in the third quarter of 2019, partially offset by a $1 million decrease in depreciation, depletion and amortization expense.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document • Midstream operating income for the nine months ended September 30, 2018 included a $72 million loss related to our gathering operations in the Fayetteville Shale, which we sold in December 2018. Excluding this amount, operating income decreased $21 million for the nine months ended September 30, 2019, compared to the same period in 2018, primarily due to a $25 million decrease in the marketing margin, a $3 million loss on sale of operating assets and a $2 million increase in allocated corporate expenses, partially offset by an $8 million decrease in non-Fayetteville Shale impairments associated with non-core assets and a $1 million gain on the sale of gas in storage.

• The margin generated from marketing activities was immaterial for the three months ended September 30, 2019, $13 million for the three months ended September 30, 2018, and $10 million and $35 million for the nine months ended September 30, 2019 and 2018, respectively.

Margins are driven primarily by volumes marketed and may fluctuate depending on the prices paid for commodities, related cost of transportation and the ultimate disposition of those commodities. Increases and decreases in marketing revenues due to changes in commodity prices and volumes marketed are largely offset by corresponding changes in marketing purchase expenses.

Revenues

• Revenues from our marketing activities decreased $254 million for the three months ended September 30, 2019, compared to the same period in 2018, primarily due to a 7% decrease in volumes marketed and a 24% decrease in the price received for volumes marketed.

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• For the nine months ended September 30, 2019, revenues from our marketing activities decreased $245 million compared to the same period in 2018, primarily due to a 32 Bcfe decrease in the volumes marketed and a 7% decrease in the price received for volumes marketed.

Operating Costs and Expenses

• Midstream operating costs and expenses for the third quarter of 2018 included $35 million related to our gathering operations in the Fayetteville Shale, which were sold in December 2018. Excluding this amount, operating costs and expenses decreased $1 million for the three months ended September 30, 2019, compared to the same period in 2018, primarily due to a $1 million decrease in depreciation, depletion and amortization expense.

• Midstream operating costs and expenses for the first three quarters of 2018 included $127 million related to our gathering operations in the Fayetteville Shale, which were sold in December 2018. Excluding this amount, operating costs and expenses remained flat for the nine months ended September 30, 2019, compared to the same period in 2018.

Impairments

• In the first three quarters of 2019, we recorded impairments of $2 million for non-core gathering assets.

• At September 30, 2018, we determined the carrying value of our gathering assets held for sale associated with the Fayetteville Shale sale exceeded the fair value less costs to sell. As a result, we recorded an impairment charge of $145 million in the third quarter of 2018. Additionally, in the second quarter of 2018, we recognized a $10 million impairment on unrelated non-core gathering assets.

Consolidated

Restructuring Charges

For the three months ended September 30, 2019, we recognized total restructuring charges of $4 million, of which $3 million primarily related to office consolidation associated with the Fayetteville Shale sale, and $1 million was related to cash severance, including payroll taxes withheld. For the nine months ended September 30, 2019, we recognized total restructuring charges of $9 million, of which $5 million primarily related to office consolidation associated with the Fayetteville Shale sale, and $4 million was related to cash severance, including payroll taxes withheld.

On June 27, 2018, we announced a workforce reduction plan, which resulted primarily from our previously announced study of structural, process and organizational changes to enhance shareholder value and continues with respect to other aspects of our business and activities. Affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, current value of a portion of equity awards to be forfeited. We recognized restructuring expense of $2 million and $20 million for the three and nine months ended September 30, 2018, of which $1 million and $18 million was related to cash severance, including payroll taxes, respectively.

Interest Expense

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended For the nine months ended

September 30, Increase/ September 30, Increase/ (in millions except percentages) 2019 2018 (Decrease) 2019 2018 (Decrease) Gross interest expense: Senior notes $ 39 $ 49 (20)% $ 117 $ 150 (22)% Credit arrangements 2 7 (71)% 7 30 (77)% Amortization of debt costs 3 2 50% 6 6 —% Total gross interest expense 44 58 (24)% 130 186 (30)% Less: capitalization (27) (29) (7)% (84) (86) (2)%

Net interest expense $ 17 $ 29 (41)% $ 46 $ 100 (54)%

• Interest expense related to our senior notes decreased for the three and nine months ended September 30, 2019, compared to the same periods of 2018, as we repurchased $900 million of our outstanding senior notes in December 2018 with a portion of the proceeds from the Fayetteville Shale sale. Additionally, S&P and Moody’s upgraded our public bond ratings in April and May 2018, respectively, which lowered the interest rates associated with our Senior Notes due 2020 and 2025 by 50 basis points, effective in July 2018.

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• Interest expense related to our credit arrangements decreased for the three and nine months ended September 30, 2019, as compared to the same periods of 2018, primarily due to the extinguishment of our 2016 term loan and entering into our revolving credit facility in April 2018, which decreased our outstanding borrowing amount, and the repayment of our revolving credit facility borrowings with a portion of the net proceeds from the Fayetteville Shale sale in December 2018.

• Capitalized interest decreased for the three and nine months ended September 30, 2019, compared to the same period in 2018, due to the evaluation of natural gas and oil properties over the past twelve months.

• Capitalized interest increased as a percentage of gross interest expense for the three and nine months ended September 30, 2019, compared to the same periods in 2018, primarily related to a smaller percentage decrease in our unevaluated natural gas and oil properties balance as compared to the larger percentage decrease in our gross interest expense over the same period, in addition to an increase in our average cost of debt over the past twelve months.

Gain (Loss) on Derivatives

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

Gain (loss) on unsettled derivatives $ 12 $ (59) $ 108 $ (113) Gain (loss) on settled derivatives 88 (6) 112 5

Gain (loss) on derivatives $ 100 $ (65) $ 220 $ (108)

We refer you to Note 9 to the consolidated financial statements included in this Quarterly Report for additional details about our gain (loss) on derivatives.

Gain/Loss on Early Extinguishment of Debt

For the three months ended September 30, 2019, we recorded a gain on early extinguishment of debt of $7 million as a result of our repurchase of $50 million in aggregate principal amount of our outstanding senior notes. See Note 12 to the consolidated financial statements of this Quarterly Report for more information on our long-term debt.

Concurrent with the closing of the 2018 credit agreement on April 26, 2018, we repaid our $1,191 million 2016 secured term loan balance and recognized a loss on early debt extinguishment of $8 million on the unaudited consolidated statements of operations in the second quarter of 2018 related to the unamortized debt issuance expense.

Income Taxes

For the three months ended For the nine months ended September 30, September 30,

(in millions except percentages) 2019 2018 2019 2018

Income tax (benefit) expense $ 10 $ — $ (401) $ — Effective tax rate 18 % 0 % (105)% 0 %

• As of the first quarter of 2019, we had sustained a three-year cumulative level of profitability. Based on this factor and other positive evidence including forecasted income, we concluded that it was more likely than not that the deferred tax assets would be realized and determined $522 million of the valuation allowance will be released. For the nine months ended September 30, 2019, we recorded

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document a discrete tax benefit of $399 million, with the remainder being recognized through current period activity. We expect to retain a valuation allowance of $87 million related to net operating losses in jurisdictions in which we no longer operate.

• Our low effective tax rate in 2018 was the result of our recognition of a valuation allowance that reduced the deferred tax asset primarily related to our current net operating loss carryforward. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized.

New Accounting Standards Implemented in this Report

Refer to Note 18 to the consolidated financial statements of this Quarterly Report for a discussion of new accounting standards which have been implemented.

New Accounting Standards Not Yet Implemented in this Report

Refer to Note 18 to the consolidated financial statements of this Quarterly Report for a discussion of new accounting standards which have not yet been implemented.

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LIQUIDITY AND CAPITAL RESOURCES

We depend on funds generated from our operations, our cash and cash equivalents balance, our revolving credit facility and capital markets as our primary sources of liquidity. Although we have financial flexibility with our cash balance and the ability to draw on our $2.0 billion revolving credit facility (less outstanding letters of credit, which were approximately $172 million as of September 30, 2019), we continue to be committed to our capital discipline strategy of investing within our cash flow from operations net of changes in working capital, supplemented by a portion of the net proceeds from the Fayetteville Shale sale realized in December 2018. We expect to apply the same principles in 2020.

Our cash flow from operating activities is highly dependent upon the sales prices that we receive for our natural gas and liquids production. Natural gas, oil and NGL prices are subject to wide fluctuations and are driven by market supply and demand, which is impacted by many factors. The sales price we receive for our production is also influenced by our commodity hedging activities. Our derivative contracts allow us to ensure a certain level of cash flow to fund our operations. In 2019, gains on derivatives have offset the majority of the impact of the recent decline in prices, and we currently have derivative positions in place for portions of our expected 2020 and 2021 production at prices above current market levels. There can be no assurance that we will be able to add derivative positions to cover the remainder of our expected production at favorable prices. See “Quantitative and Qualitative Disclosures about Market Risk” in Item 3 and Note 9, in the consolidated financial statements included in this Quarterly Report for further details.

Our commodity hedging activities are subject to the credit risk of our counterparties being financially unable to settle the transaction. We actively monitor the credit status of our counterparties, performing both quantitative and qualitative assessments based on their credit ratings and credit default swap rates where applicable, and to date have not had any credit defaults associated with our transactions. However, any future failures by one or more counterparties could negatively impact our cash flow from operating activities.

Our short-term cash flows are also dependent on the timely collection of receivables from our customers and joint interest owners. We actively manage this risk through credit management activities and, through the date of this filing, have not experienced any significant write-offs for non-collectable amounts. However, any sustained inaccessibility of credit by our customers and joint interest partners could adversely impact our cash flows.

Due to these above factors, we are unable to forecast with certainty our future level of cash flow from operations. Accordingly, we expect to adjust our discretionary uses of cash depending upon available cash flow. Further, we may from time to time seek to retire, rearrange or amend some or all of our outstanding debt or debt agreements through cash purchases, and/or exchanges, open market purchases, privately negotiated transactions, tender offers or otherwise. Such transactions, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

Credit Arrangements and Financing Activities

On April 26, 2018, we replaced our 2016 credit facility with a new revolving credit facility. The 2018 credit facility has an aggregate maximum revolving credit amount of $3.5 billion with a current aggregate commitment of $2.0 billion and a borrowing base (limit on availability) that is redetermined each April and October. The 2018 credit facility is secured by substantially all of our assets, including most of our subsidiaries. The permitted lien provisions in the senior note indentures currently limit liens securing indebtedness to the greater of $2.0 billion and 25% of adjusted consolidated net tangible assets. On October 8, 2019, we entered into an amendment to the 2018 credit facility that, among other things, established the October 2019 borrowing base at $2.1 billion and extended the maturity date to April 2024. The borrowing base is subject to change based primarily on drilling results, commodity prices, our future derivative position, the level of capital investing and operating costs. As of September 30, 2019, we had no borrowings outstanding on our 2018 credit facility and $172 million in outstanding letters of credit.

As of September 30, 2019, we were in compliance with all of the covenants of our revolving credit facility in all material respects. We refer you to Note 12 of the consolidated financial statements included in this Quarterly Report for additional discussion of the covenant requirements of our 2018 credit facility. Although we do not anticipate any violations of the financial covenants, our ability

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document to comply with these covenants is dependent upon the success of our exploration and development program and upon factors beyond our control, such as the market prices for natural gas and liquids.

The credit status of the financial institutions participating in our revolving credit facility could adversely impact our ability to borrow funds under the revolving credit facility. Although we believe all of the lenders under the facility have the ability to provide funds, we cannot predict whether each will be able to meet their obligation to us. We refer you to Note 12 to the consolidated financial statements included in this Quarterly Report for additional discussion of our revolving credit facility.

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Because of the focused work on refinancing and repayment of our debt during 2017 and 2018, only $265 million, or 11%, of our outstanding debt balance as of September 30, 2019 will come due prior to 2025, with $52 million of that coming due in the next year.

At September 30, 2019, we had a long-term issuer credit rating of Ba2 by Moody’s, a long-term debt rating of BB by S&P and a long-term issuer default rating of BB by Fitch Ratings. Any upgrades or downgrades in our public debt ratings by Moody’s or S&P could decrease or increase our cost of funds, respectively.

Cash Flows

For the nine months ended September 30,

(in millions) 2019 2018

Net cash provided by operating activities $ 739 $ 971 Net cash used in investing activities (835) (995) Net cash used in financing activities (76) (883)

Cash Flow from Operating Activities

For the nine months ended September 30,

(in millions) 2019 2018

Net cash provided by operating activities $ 739 $ 971 Less: Changes in working capital (88) 2

Net cash provided by operating activities, net of changes in working capital $ 651 $ 973

• Net cash provided by operating activities decreased 24%, or $232 million, for the nine months ended September 30, 2019, compared to the same period in 2018, primarily due to a $290 million decrease as a result of the December 2018 Fayetteville Shale sale and a $277 million decrease resulting from lower commodity prices. These decreases were partially offset by a $182 million increase associated with increased production, a $54 million increase as a result of reduced interest costs and a $90 million increase in working capital.

• Net cash generated from operating activities, net of changes in working capital, provided 70% of our cash requirements for capital investments for the nine months ended September 30, 2019, compared to providing 93% of our cash requirements for capital investments for the same period in 2018. While we front-load our capital programs into the earlier quarters in the year, we remain committed to our capital discipline strategy of investing within our cash flow from operations, net of changes in working capital, supplemented by a portion of the net proceeds from the Fayetteville Shale sale.

Cash Flow from Investing Activities

• Total E&P capital investing decreased $56 million for the three months ended September 30, 2019, compared to the same period in 2018, due to a $49 million decrease in direct E&P capital investing and a $7 million decrease in capitalized interest and internal costs, as compared to the same period in 2018.

• Total E&P capital investing decreased $94 million for the nine months ended September 30, 2019, compared to the same period in 2018, due to a $76 million decrease in direct E&P capital investing and a $18 million decrease in capitalized interest and internal costs, as compared to the same period in 2018.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the nine months ended September 30,

(in millions) 2019 2018

Additions to properties and equipment $ 877 $ 1,008 Adjustments for capital investments Changes in capital accruals 52 21 Other 4 10

Total capital investing $ 933 $ 1,039

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Capital Investing

For the three months ended For the nine months ended

September 30, Increase/ September 30, Increase/ (in millions except percentages) 2019 2018 (Decrease) 2019 2018 (Decrease) E&P capital investing $ 239 $ 295 (19)% $ 931 $ 1,025 (9)% (1) Midstream capital investing — — —% — 9 (100)% Other capital investing 1 3 (67)% 2 5 (60)%

Total capital investing $ 240 $ 298 (19)% $ 933 $ 1,039 (10)%

(1) Our Midstream gathering business in the Fayetteville Shale was sold in December 2018.

For the three months ended For the nine months ended September 30, September 30,

(in millions) 2019 2018 2019 2018

E&P Capital Investments by Type: Exploratory and development drilling, including workovers $ 176 $ 200 $ 711 $ 766 Acquisitions of properties 9 10 32 46 Seismic expenditures — 1 2 3 Water infrastructure project 6 26 32 39 Drilling rigs and other 3 6 14 13 Capitalized interest and expenses 45 52 140 158

Total E&P capital investments $ 239 $ 295 $ 931 $ 1,025

E&P Capital Investments by Area: Northeast Appalachia $ 74 $ 100 $ 306 $ 360 Southwest Appalachia 154 156 575 578 Fayetteville Shale — 5 — 30 (1) New Ventures & other 11 34 50 57

Total E&P capital investments $ 239 $ 295 $ 931 $ 1,025

(1) Includes $6 million and $32 million for the three and nine months ended September 30, 2019, respectively, and $26 million and $39 million for the three and nine months ended September 30, 2018 related to our water infrastructure project.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended For the nine months ended September 30, September 30,

2019 2018 2019 2018

Gross Operated Well Count Summary: Drilled 24 22 95 91 Completed 30 23 101 108 Wells to sales 34 35 89 113

Actual capital expenditure levels may vary significantly from period to period due to many factors, including drilling results, natural gas, oil and NGL prices, industry conditions, the prices and availability of goods and services, and the extent to which properties are acquired or non-strategic assets are sold.

Cash Flow from Financing Activities

(in millions except percentages) September 30, 2019 December 31, 2018 Increase/(Decrease) (1) Debt $ 2,271 $ 2,318 $ (47) Equity 3,135 2,362 773 Total debt to capitalization ratio 42 % 50 %

(1) Debt $ 2,271 $ 2,318 $ (47) Less: Cash and cash equivalents 29 201 (172)

(2) Debt, net of cash and cash equivalents $ 2,242 $ 2,117 $ 125

(1) The decrease in total debt as of September 30, 2019, as compared to December 31, 2018, primarily relates to the repurchase of $50 million of our outstanding senior notes during the third quarter of 2019.

(2) Debt, net of cash and cash equivalents is a non-GAAP financial measure of a company’s ability to repay its debt if it was all due today.

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We refer you to Note 12 of the consolidated financial statements included in this Quarterly Report for additional discussion of our outstanding debt and credit facilities.

Working Capital

• We had negative working capital of $247 million at September 30, 2019, a $357 million decrease from December 31, 2018, as a decrease of $258 million in accounts receivable, as compared to December 2018, related to the sale of the Fayetteville Shale production in December 2018 and lower commodity prices, a decrease of $172 million in cash and cash equivalents, a current liability of $35 million recorded in 2019 related to the implementation of the new lease accounting standard (Topic 842) and $52 million of our long-term debt, which matures in less than a year, being reclassified as a current liability in 2019 were only partially offset by positive changes in the current mark-to-market value of our derivative position and a $70 million decrease in accounts payable, as compared to December 31, 2018.

• At December 31, 2018, we had positive working capital of $110 million primarily due to $201 million of cash and cash equivalents resulting from the net proceeds from the Fayetteville Shale sale and an increase in accounts receivable primarily related to the increase in commodity pricing in December 2018, as compared to December 2017.

Off-Balance Sheet Arrangements

We may enter into off-balance sheet arrangements and transactions that can give rise to material off-balance sheet obligations. As of September 30, 2019, our material off-balance sheet arrangements and transactions include operating service arrangements and $172 million in letters of credit outstanding against our 2018 credit facility. There are no other transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect our liquidity or availability of our capital resources. For more information regarding off-balance sheet arrangements, we refer you to “Contractual Obligations and Contingent Liabilities and Commitments” in our 2018 Annual Report.

Contractual Obligations and Contingent Liabilities and Commitments

We have various contractual obligations in the normal course of our operations and financing activities. Other than the firm transportation and gathering agreements discussed below, there have been no material changes to our contractual obligations from those disclosed in our 2018 Annual Report.

Contingent Liabilities and Commitments

As of September 30, 2019, our contractual obligations for demand and similar charges under firm transportation and gathering agreements to guarantee access capacity on natural gas and liquids pipelines and gathering systems totaled approximately $8.2 billion, $752 million of which related to access capacity on future pipeline and gathering infrastructure projects that still require the granting of regulatory approvals and/or additional construction efforts. This amount also included guarantee obligations of up to $323 million. As of September 30, 2019, future payments under non-cancelable firm transportation and gathering agreements are as follows:

Payments Due by Period

Less than 1 More than 8 (in millions) Total Year 1 to 3 Years 3 to 5 Years 5 to 8 years Years

Infrastructure currently in service $ 7,442 $ 681 $ 1,272 $ 1,075 $ 1,528 $ 2,886 (1) Pending regulatory approval and/or construction 752 19 73 75 139 446

Total transportation charges $ 8,194 $ 700 $ 1,345 $ 1,150 $ 1,667 $ 3,332

(1) Based on the estimated in-service dates as of September 30, 2019.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Included in the transportation charges above are $108 million (potentially due in less than one year) and $27 million (potentially due in one to two years) related to certain agreements that remain in the name of our marketing affiliate but are expected to be paid in full by Flywheel Energy Operating, LLC, the purchaser of the Fayetteville Shale assets. Of these amounts, we may be obligated to reimburse Flywheel Energy Operating, LLC for a portion of volumetric shortfalls during 2019 and 2020 (up to $70 million) under these transportation agreements and have currently recorded a $57 million liability as of September 30, 2019, down from $88 million recorded at December 31, 2018.

In the first quarter of 2019, we agreed to purchase firm transportation with pipelines in the Appalachian Basin starting in 2021 and running through 2032 totaling $357 million in total contractual commitments of which the seller has agreed to reimburse $133 million of these commitments.

During the second quarter of 2019, we executed an agreement to convey our purchase option in our headquarters office building to a third-party, which closed on the purchase of the building in July 2019. Concurrent with the closing of the building

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sale, we terminated our existing lease agreement and entered into a new 10-year lease agreement for a smaller portion of the headquarters office building in July 2019, resulting in an estimated annual savings of $7 million to $8 million.

Substantially all of our employees are covered by defined benefit and postretirement benefit plans. For the nine months ended September 30, 2019, we have contributed $12 million to the pension and postretirement benefit plans, and we do not expect to further contribute to our pension plan during the remainder of 2019. We recognized liabilities of $39 million and $47 million as of September 30, 2019 and December 31, 2018, respectively, as a result of the underfunded status of our pension and other postretirement benefit plans. See Note 15 to the consolidated financial statements included in this Quarterly Report for additional discussion about our pension and other postretirement benefits.

We are subject to various litigation, claims and proceedings that arise in the ordinary course of business, such as for alleged breaches of contract, miscalculation of royalties, employment matters, traffic incidents, pollution, contamination, encroachment on others’ property or nuisance. We accrue for such items when a liability is both probable and the amount can be reasonably estimated. Management believes that current litigation, claims and proceedings, individually or in aggregate and after taking into account insurance, are not likely to have a material adverse impact on our financial position, results of operations or cash flows, although it is possible that adverse outcomes could have a material adverse effect on our results of operations or cash flows for the period in which the effect of that outcome becomes reasonably estimable. Many of these matters are in early stages, so the allegations and the damage theories have not been fully developed, and are all subject to inherent uncertainties; therefore, management’s view may change in the future.

We are also subject to laws and regulations relating to the protection of the environment. Environmental and cleanup related costs of a non-capital nature are accrued when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. Management believes any future remediation or other compliance related costs will not have a material effect on our financial position, results of operations or cash flows.

For further information, we refer you to “Litigation” and “Environmental Risk” in Note 13 to the consolidated financial statements included in Item I of Part I of this Quarterly Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market risks relating to our operations result primarily from the volatility in commodity prices, basis differentials and interest rates, as well as service costs and credit risk concentrations. We use fixed price swap agreements, options, basis swaps and interest rate swaps to reduce the volatility of earnings and cash flow due to fluctuations in the prices of natural gas, oil and certain NGLs along with interest rates. Our Board of Directors has approved risk management policies and procedures to utilize financial products for the reduction of defined commodity price risk. Utilization of financial products for the reduction of interest rate risks is also overseen by our Board of Directors. These policies prohibit speculation with derivatives and limit swap agreements to counterparties with appropriate credit standings.

Credit Risk

Our exposure to concentrations of credit risk consists primarily of trade receivables and derivative contracts associated with commodities trading. Concentrations of credit risk with respect to receivables are limited due to the large number of our purchasers and their dispersion across geographic areas. No single purchaser accounted for greater than 10% of revenues as of September 30, 2019. At December 31, 2018, two subsidiaries of Royal Dutch Shell Plc in aggregate accounted for approximately 10.4% of the quarter’s total natural gas, oil and NGL sales. We believe that the loss of any one customer would not have an adverse effect on our ability to sell our natural gas, oil and NGL production. See “Commodities Risk” below for discussion of credit risk associated with commodities trading.

Interest Rate Risk

As of September 30, 2019, we had approximately $2.3 billion of outstanding senior notes with a weighted average interest rate of 6.68%, and no borrowings under our revolving credit facility. We currently have an interest rate swap in effect to mitigate a portion of

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document our exposure to volatility in interest rates. At September 30, 2019, we had a long-term issuer credit rating of Ba2 by Moody’s, a long- term debt rating of BB by S&P and a long-term issuer default rating of BB by Fitch Ratings. Any upgrades or downgrades in our public debt ratings by Moody’s or S&P could decrease or increase our cost of funds, respectively.

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Expected Maturity Date

($ in millions) 2019 2020 2021 2022 2023 Thereafter Total (1) Fixed rate payments $ — $ 52 $ — $ 213 $ — $ 2,027 $ 2,292 Weighted average interest rate — % 5.30 % — % 4.10 % — % 6.99 % 6.68 %

(1) (1) (1) Variable rate payments $ — $ — $ — $ — $ — $ — $ — (2) (2) Weighted average interest rate — % — % — % — % 3.42 % — % 3.42 %

(1) Excludes unamortized debt issuance costs and debt discounts.

(2) On October 8, 2019, we entered into an amendment to the 2018 credit facility, which extended the maturity date of the credit facility to April 2024.

Commodities Risk

We use over-the-counter fixed price swap agreements and options to protect sales of our production against the inherent risks of adverse price fluctuations or locational pricing differences between a published index and the NYMEX futures market. These swaps and options include transactions in which one party will pay a fixed price (or variable price) for a notional quantity in exchange for receiving a variable price (or fixed price) based on a published index (referred to as price swaps) and transactions in which parties agree to pay a price based on two different indices (referred to as basis swaps).

The primary market risks relating to our derivative contracts are the volatility in market prices and basis differentials for our production. However, the market price risk is offset by the gain or loss recognized upon the related sale or purchase of the production that is financially protected. Credit risk relates to the risk of loss as a result of non-performance by our counterparties. The counterparties are primarily major banks and integrated energy companies that management believes present minimal credit risks. The credit quality of each counterparty and the level of financial exposure we have to each counterparty are closely monitored to limit our credit risk exposure. Additionally, we perform both quantitative and qualitative assessments of these counterparties based on their credit ratings and credit default swap rates where applicable. We have not incurred any counterparty losses related to non-performance and do not anticipate any losses given the information we have currently. However, we cannot be certain that we will not experience such losses in the future. We refer you to Note 9 of the consolidated financial statements included in this Quarterly Report for additional details about our derivative instruments.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

We have performed an evaluation under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act. Our disclosure controls and procedures are the controls and other procedures that we have designed to ensure that we record, process, accumulate and communicate information to our management, including our Chief Executive Officer and Chief Financial Officer, to allow timely decisions regarding required disclosures and submission within the time periods specified in the SEC’s rules and forms. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those determined to be effective can provide only a level of reasonable assurance with respect to financial statement preparation and presentation. Based on the evaluation, our management, including our Chief Executive Officer and Chief Financial Officer, concluded that our disclosure controls and procedures were effective as of September 30, 2019 at a reasonable assurance level.

Changes in Internal Control over Financial Reporting

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document There were no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the quarter ended September 30, 2019 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Refer to “Litigation” and “Environmental Risk” in Note 13 to the consolidated financial statements included in Item 1 of Part I of this Quarterly Report for a discussion of the Company’s legal proceedings.

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ITEM 1A. RISK FACTORS

There were no additions or material changes to our risk factors as disclosed in Item 1A of Part I in the Company’s 2018 Annual Report.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Not applicable.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Our sand mine location, which supported our former Fayetteville Shale business, is subject to regulation by the Federal Mine Safety and Health Administration under the Federal Mine Safety and Health Act of 1977. Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.106) is included in Exhibit 95.1 to this Quarterly Report.

ITEM 5. OTHER INFORMATION

Not applicable.

ITEM 6. EXHIBITS

(31.1)* Certification of CEO filed pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (31.2)* Certification of CFO filed pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (32.1)* Certification of CEO furnished pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (32.2)* Certification of CFO furnished pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (95.1)* Mine Safety Disclosure (101.INS) Interactive Data File Instance Document (101.SCH) Interactive Data File Schema Document (101.CAL) Interactive Data File Calculation Linkbase Document (101.LAB) Interactive Data File Label Linkbase Document (101.PRE) Interactive Data File Presentation Linkbase Document (101.DEF) Interactive Data File Definition Linkbase Document

*Filed herewith

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.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document SOUTHWESTERN ENERGY COMPANY

Registrant

Dated: October 24, 2019 /s/ JULIAN M. BOTT Julian M. Bott Executive Vice President and Chief Financial Officer

?

59

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Exhibit 31.1 CERTIFICATION

I, William J. Way, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Southwestern Energy Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Date: October 24, 2019 /s/ WILLIAM J. WAY William J. Way Director, President and Chief Executive Officer

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Exhibit 31.2 CERTIFICATION

I, Julian M. Bott, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Southwestern Energy Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Date: October 24, 2019 /s/ JULIAN M. BOTT Julian M. Bott Executive Vice President and Chief Financial Officer

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Exhibit 32.1

CERTIFICATION Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

In connection with the Quarterly Report of Southwestern Energy Company, a corporation (the “Corporation”) on Form 10-Q for the quarter ended September 30, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William J. Way, Director, President and Chief Executive Officer of the Corporation, certify to my knowledge, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

Dated: October 24, 2019 /s/ WILLIAM J. WAY William J. Way Director, President and Chief Executive Officer

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Exhibit 32.2

CERTIFICATION Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

In connection with the Quarterly Report of Southwestern Energy Company, a Delaware corporation (the “Corporation”) on Form 10-Q for the quarter ended September 30, 2019 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Julian M. Bott, Executive Vice President and Chief Financial Officer of the Corporation, certify to my knowledge, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

Dated: October 24, 2019 /s/ JULIAN M. BOTT Julian M. Bott Executive Vice President and Chief Financial Officer

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document EXHIBIT 95.1 Mine Safety Disclosure

The following disclosure is provided pursuant to Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act, which requires certain disclosures by companies required to file periodic reports under the Securities Exchange Act of 1934, as amended, that operate mines regulated under the Federal Mine Safety and Health Act of 1977.

The table that follows reflects citations, orders, violations and proposed assessments issued by the Mine Safety and Health Administration (the “MSHA”) to SWN Production (Arkansas), LLC, an indirect wholly owned subsidiary of Southwestern Energy Company. The disclosure is with respect to the three months ended September 30, 2019. Due to timing and other factors, the data may not agree with the mine data retrieval system maintained by the MSHA at www.MSHA.gov.

Southwestern Energy Company Mine Safety Disclosure Three Months Ended September 30, 2019 (Unaudited)

Received Received Notice of Notice of Legal Total Dollar Pattern Potential Actions Section Value of Total of to Have Pending Legal Legal Section 104(d) Proposed Number Violations Pattern as of the Actions Actions 104 Section Citations Section Section Section MSHA of Mining Under Under Last Initiated Resolved S&S 104(b) and 110(b)(2) 107(a) 107(a) Assessments Related Section Section Day of During During (1) (2) Operation Citations Orders Orders Violations Orders Orders Fatalities 104(e) 104(e) Period Period Period

A. W. Realty Company, LLC — — — — — — $— — — — —

Total $— No No

(1) The definition of mine under section 3 of the Mine Act includes the mine, as well as other items used in, or to be used in, or resulting from, the work of extracting minerals, such as land, structures, facilities, equipment, machines, tools, and preparation facilities. Unless otherwise indicated, any of these other items associated with a single mine have been aggregated in the totals for that mine.

(2) The whole-dollar amounts included are the total dollar value of all proposed or outstanding assessments, regardless of classification, received from MSHA on or before September 30, 2019 regardless of whether the assessment has been challenged or appealed, for alleged violations occurring during the three month period ended September 30, 2019. Citations and orders can be contested and appealed, and as part of that process, are sometimes reduced in severity and amount, and are sometimes dismissed. The number of citations, orders, and proposed assessments vary by inspector and also vary depending on the size and type of the operation.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Cash and Cash Equivalents Sep. 30, 2019 Cash and Cash Equivalents [Abstract] Cash and Cash Equivalents CASH AND CASH EQUIVALENTS

The following table presents a summary of cash and cash equivalents as of September 30, 2019 and December 31, 2018:

(in millions) September 30, 2019 December 31, 2018

Cash $ 9 $ 32 (1) Marketable securities 20 169

Total $ 29 $ 201

(1) Consists of government stable value money market funds.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Divestitures Sep. 30, 2019 Discontinued Operations and Disposal Groups [Abstract] Divestitures DIVESTITURES

On August 30, 2018, the Company entered into an agreement with Flywheel Energy Operating, LLC to sell 100% of the equity in the Company’s subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets for $1,865 million in cash, subject to customary closing adjustments, with an economic effective date of July 1, 2018. On December 3, 2018, the Company closed on the Fayetteville Shale sale and received approximately $1,650 million, which included purchase price adjustments of approximately $215 million primarily related to the net cash flows from the economic effective date to the closing date.

The Company retained certain contractual commitments related to firm transportation, with the buyer obligated to pay the transportation provider directly for these charges. As of September 30, 2019, approximately $135 million of these contractual commitments remain of which the Company will reimburse the buyer for certain of these potential obligations up to approximately $70 million through 2020 depending on the buyer’s actual use. At September 30, 2019, the Company has recorded a $57 million liability for the estimated future payments.

In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool included in the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, the Company determined the carrying value of certain non-full cost pool assets exceeded the fair value less costs to sell. As a result, an impairment charge of $161 million was recorded during the three and nine months ended September 30, 2018, of which $145 million related to midstream gathering assets held for sale and $15 million related to E&P assets held for sale. Additionally, the Company recorded a $1 million impairment related to other non-core assets that were not included in the sale.

From the proceeds received, $914 million was used to repurchase $900 million of the Company’s outstanding senior notes, including premiums and $9 million in accrued interest paid in December 2018. In addition, $201 million, including approximately $1 million in commissions, was used to repurchase approximately 44 million shares of the Company’s outstanding common stock, including $21 million during the first quarter of 2019. The Company earmarked the remaining net proceeds from the sale to supplement Appalachian Basin development and for general corporate purposes.

In June 2019, the Company sold non-core acreage for $25 million. There was no production or proved reserves associated with this acreage. In addition, during July 2019, the Company sold the land associated with its headquarters office building for $16 million, and recognized a $2 million gain on the sale. The Company also from time to time sells leases and other properties whose value, individually, is not material but is reflected in the Company’s financial statements.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Reclassifications from 9 Months Ended Accumulated Other Comprehensive Income Sep. 30, 2019 (Loss) Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] Reclassifications from RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) Accumulated Other Comprehensive Income (Loss) In the first half of 2019, changes in accumulated other comprehensive income primarily related to settlements in the Company’s pension and other postretirement benefits. The following tables detail the components of accumulated other comprehensive income and the related tax effects for the nine months ended September 30, 2019:

Pension and Other (in millions) Postretirement Foreign Currency Total

Beginning balance December 31, 2018 $ (22) $ (14) $ (36) Other comprehensive income before reclassifications — — — (1) Amounts reclassified from other comprehensive income 5 — 5

Net current-period other comprehensive income 5 — 5

Ending balance September 30, 2019 $ (17) $ (14) $ (31)

(1) See separate table below for details about these reclassifications.

Details about Accumulated Other Affected Line Item in the Amount Reclassified from Accumulated Other Comprehensive Income Consolidated Statement of Operations Comprehensive Income

For the nine months ended September 30, 2019

(in millions) Pension and other postretirement: (1) Amortization of prior service cost and net loss Other Income, Net $ 7 Provision for income taxes 2

Net income $ 5

Total reclassifications for the period Net income $ 5

?

(1) See Note 15 for additional details regarding the Company’s pension and other postretirement benefit plans.

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Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Earnings Per Share (Tables) Sep. 30, 2019 Earnings Per Share [Abstract] Schedule of Earnings Per Share The following table presents the computation of earnings per share for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions, except share/per share amounts) 2019 2018 2019 2018

Net income (loss) $ 49 $ (29) $ 781 $ 230 Participating securities – mandatory convertible preferred stock — — — 1

Net income (loss) attributable to common stock $ 49 $ (29) $ 781 $ 229

Number of common shares: Weighted average outstanding 539,221,101 581,171,753 539,315,170 577,912,421 Issued upon assumed exercise of outstanding stock options — — — — Effect of issuance of non-vested restricted common stock 187,706 — 400,120 640,365 Effect of issuance of non-vested performance units 629,380 — 727,359 1,276,072

Weighted average and potential dilutive outstanding 540,038,187 581,171,753 540,442,649 579,828,858

Earnings per common share Basic $ 0.09 $ (0.05) $ 1.45 $ 0.40

Diluted $ 0.09 $ (0.05) $ 1.44 $ 0.39

Schedule of Antidilutive Securities Excluded from The following table presents the common stock shares equivalent excluded from the calculation of diluted earnings per share for the three and nine months ended Computation of Earnings Per September 30, 2019 and 2018, as they would have had an antidilutive effect: Share

For the three months ended September For the nine months ended September 30, 30,

2019 2018 2019 2018

Unexercised stock options 5,102,882 717 5,115,334 — Unvested share-based payment 2,136,453 3,463,802 1,797,963 4,246,492 Performance units 240,450 2,000,553 247,443 856,703 Mandatory convertible preferred stock — — — 3,296,642

Total 7,479,785 5,465,072 7,160,740 8,399,837

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Debt (Tables) Sep. 30, 2019 Debt Disclosure [Abstract] Components of Debt The components of debt as of September 30, 2019 and December 31, 2018 consisted of the following:

September 30, 2019

Unamortized Issuance Unamortized Debt (in millions) Debt Instrument Expense Discount Total Current portion of long-term debt: (1) 4.05% Senior Notes due January 2020 $ 52 $ — $ — $ 52

Total current portion of long-term debt $ 52 $ — $ — $ 52

Long-term debt: (2) Variable rate (3.420% at September 30, 2019) 2018 revolving credit $ — $ — $ — $ — facility, due April 2023 4.10% Senior Notes due March 2022 213 (1) — 212 (1)(3) 4.95% Senior Notes due January 2025 896 (7) (1) 888 (3) 7.50% Senior Notes due April 2026 639 (7) — 632 (3) 7.75% Senior Notes due October 2027 492 (5) — 487

Total long-term debt $ 2,240 $ (20) $ (1) $ 2,219

Total debt $ 2,292 $ (20) $ (1) $ 2,271

December 31, 2018

Unamortized Issuance Unamortized Debt (in millions) Debt Instrument Expense Discount Total Long-term debt: (2) Variable rate (3.920% at December 31, 2018) 2018 term loan facility, due $ — $ — $ — $ — April 2023 (1) 4.05% Senior Notes due January 2020 52 — — 52 4.10% Senior Notes due March 2022 213 (1) — 212 (1) 4.95% Senior Notes due January 2025 927 (7) (1) 919 7.50% Senior Notes due April 2026 650 (8) — 642 7.75% Senior Notes due October 2027 500 (7) — 493

Total long-term debt $ 2,342 $ (23) $ (1) $ 2,318

(1) In February and June 2016, Moody’s and S&P downgraded certain senior notes, increasing the interest rates by 175 basis points effective July 2016. As a result of the downgrades, interest rates increased to 5.80% for the 2020 Notes and 6.70% for the 2025 Notes. S&P and Moody’s upgraded certain senior notes in April and May 2018, respectively. As a result of these upgrades, interest rates decreased to 5.30% for the 2020 Notes and 6.20% for the 2025 Notes effective July 2018. The first coupon payment to the bondholders at the lower interest rate was paid in January 2019.

(2) At September 30, 2019 and December 31, 2018, unamortized issuance expense of $9 million and $12 million, respectively, associated with the 2018 revolving credit facility is classified as other long-term assets on the consolidated balance sheets.

(3) During the third quarter of 2019, the Company purchased $31 million in 2025 Notes, $11 million in 2026 Notes and $8 million in 2027 Notes for $43 million in cash, reducing the Company’s outstanding debt by $50 million. This resulted in a gain on early extinguishment of debt of $7 million for the three and nine months ended September 30, 2019.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Cash and Cash Equivalents (Summary of Cash and Cash Equivalents) (Details) - USD Sep. 30, 2019Dec. 31, 2018 ($) $ in Millions Cash and Cash Equivalents [Abstract] Cash $ 9 $ 32 Marketable securities 20 169 Total $ 29 $ 201

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Revenue Recognition 1 Months Ended9 Months Ended (Narrative) (Details) - USD Dec. 31, 2018 Sep. 30, 2019 ($) Disaggregation of Revenue [Line Items] Contract asset associated with revenues from contracts with customers $ 0 Contract liability associated with revenues from contracts with customers $ 0 Minimum | NGL sales Disaggregation of Revenue [Line Items] Payment terms 30 days Minimum | Marketing Disaggregation of Revenue [Line Items] Payment terms 30 days Minimum | Gas gathering Disaggregation of Revenue [Line Items] Payment terms 30 days Maximum | NGL sales Disaggregation of Revenue [Line Items] Payment terms 60 days Maximum | Marketing Disaggregation of Revenue [Line Items] Payment terms 60 days Maximum | Gas gathering Disaggregation of Revenue [Line Items] Payment terms 60 days Fayetteville Shale Disaggregation of Revenue [Line Items] Percentage of assets sold 100.00%

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 3 Months Ended 9 Months Ended (Schedule of Stock-Based Compensation Costs) Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 (Details) - USD ($) $ in Millions Share-based Compensation [Abstract] Stock-based compensation cost – expensed $ 1 $ 7 $ 12 $ 20 Stock-based compensation cost – capitalized $ 1 $ 3 $ 7 $ 10

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document New Accounting Pronouncements - Narrative Sep. 30, Jan. 01, (Details) - USD ($) 2019 2019 $ in Millions New Accounting Pronouncements or Change in Accounting Principle [Line Items] Right-of-use asset $ 164 Lease liability balance $ 159 ASU 2016-02 New Accounting Pronouncements or Change in Accounting Principle [Line Items] Right-of-use asset $ 105 Lease liability balance $ 105

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 12 Months 1 Months Ended 3 Months Ended 9 Months Ended Ended Debt (Components of Debt) Jun. Feb. Sep. Jul. Jul. Jan. (Details) - USD ($) Sep. 30, 2019 Dec. 31, 2018 30, 29, Sep. 30, 2019 30, Sep. 30, 2019 Sep. 30, 2018 Dec. 31, 2018 31, 31, 31, 2016 2016 2018 2018 2016 2015 Debt Instrument [Line Items] Debt Instrument, long-term $ $ $ debt 2,240,000,000 2,240,000,000 2,240,000,000 Debt Instrument $ $ 2,292,000,000 2,292,000,000 2,292,000,000 2,342,000,000 2,342,000,000 Unamortized Issuance (20,000,000) (23,000,000) (20,000,000) (20,000,000) (23,000,000) Expense Unamortized Debt Discount (1,000,000) (1,000,000) (1,000,000) (1,000,000) (1,000,000) Total, current portion of long- 52,000,000 0 52,000,000 52,000,000 0 term debt Total, long-term debt 2,219,000,0002,318,000,000 2,219,000,000 2,219,000,000 2,318,000,000 Total debt 2,271,000,0002,318,000,000 2,271,000,000 2,271,000,000 2,318,000,000 Unamortized issuance expense 20,000,000 23,000,000 20,000,000 20,000,000 23,000,000 Repayments of long-term debt $ 43,000,000 1,191,000,000 Decrease in outstanding debt 50,000,000 Gain on extinguishment of 7,000,000 $ 0 7,000,000 $ (8,000,000) debt Line of Credit | 2018 revolving credit facility, due April 2023 Debt Instrument [Line Items] Debt Instrument, long-term 0 0 0 debt Unamortized Issuance 0 0 0 Expense Unamortized Debt Discount 0 0 0 Total, long-term debt 0 0 $ 0 Variable interest rate 3.42% Unamortized issuance expense 0 0 $ 0 Line of Credit | 2018 term loan facility, due April 2023 Debt Instrument [Line Items] Debt Instrument 0 0 Unamortized Issuance 0 0 Expense Unamortized Debt Discount 0 0 Total debt 0 $ 0 Variable interest rate 3.92% Unamortized issuance expense 0 $ 0 Senior Notes Debt Instrument [Line Items] Debt Instrument, current 52,000,000 52,000,000 52,000,000 portion of long-term debt Unamortized Issuance 0 0 0 Expense Unamortized Debt Discount 0 0 0 Total, current portion of long- 52,000,000 52,000,000 52,000,000 term debt Unamortized issuance expense 0 0 0 Repayments of long-term debt 900,000,000 43,000,000 Gain on extinguishment of 7,000,000 debt Senior Notes | 4.05% Senior Notes due January 2020

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Debt Instrument [Line Items] Debt Instrument, current 52,000,000 52,000,000 52,000,000 portion of long-term debt Debt Instrument 52,000,000 52,000,000 Unamortized Issuance 0 0 0 0 0 Expense Unamortized Debt Discount 0 0 0 0 0 Total, current portion of long- $ 52,000,000 $ 52,000,000 $ 52,000,000 term debt Total debt $ 52,000,000 $ 52,000,000 Stated interest rate 4.05% 4.05% 4.05% 4.05% 4.05% Unamortized issuance expense $ 0 $ 0 $ 0 $ 0 $ 0 Senior Notes | 4.10% Senior Notes due March 2022 Debt Instrument [Line Items] Debt Instrument, long-term 213,000,000 213,000,000 213,000,000 debt Debt Instrument 213,000,000 213,000,000 Unamortized Issuance (1,000,000) (1,000,000) (1,000,000) (1,000,000) (1,000,000) Expense Unamortized Debt Discount 0 0 0 0 0 Total, long-term debt $ 212,000,000 $ 212,000,000 $ 212,000,000 Total debt $ 212,000,000 $ 212,000,000 Stated interest rate 4.10% 4.10% 4.10% 4.10% 4.10% Unamortized issuance expense $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 $ 1,000,000 Senior Notes | 4.95% Senior Notes due January 2025 Debt Instrument [Line Items] Debt Instrument, long-term 896,000,000 896,000,000 896,000,000 debt Debt Instrument 927,000,000 927,000,000 Unamortized Issuance (7,000,000) (7,000,000) (7,000,000) (7,000,000) (7,000,000) Expense Unamortized Debt Discount (1,000,000) (1,000,000) (1,000,000) (1,000,000) (1,000,000) Total, long-term debt $ 888,000,000 $ 888,000,000 $ 888,000,000 Total debt $ 919,000,000 $ 919,000,000 Stated interest rate 4.95% 4.95% 4.95% 4.95% 4.95% Unamortized issuance expense $ 7,000,000 $ 7,000,000 $ 7,000,000 $ 7,000,000 $ 7,000,000 Repurchased amount 31,000,000 31,000,000 31,000,000 Senior Notes | 7.50% Senior Notes due April 2026 Debt Instrument [Line Items] Debt Instrument, long-term 639,000,000 639,000,000 639,000,000 debt Debt Instrument 650,000,000 650,000,000 Unamortized Issuance (7,000,000) (8,000,000) (7,000,000) (7,000,000) (8,000,000) Expense Unamortized Debt Discount 0 0 0 0 0 Total, long-term debt $ 632,000,000 $ 632,000,000 $ 632,000,000 Total debt $ 642,000,000 $ 642,000,000 Stated interest rate 7.50% 7.50% 7.50% 7.50% 7.50% Unamortized issuance expense $ 7,000,000 $ 8,000,000 $ 7,000,000 $ 7,000,000 $ 8,000,000 Repurchased amount 11,000,000 11,000,000 11,000,000 Senior Notes | 7.75% Senior Notes due October 2027 Debt Instrument [Line Items] Debt Instrument, long-term 492,000,000 492,000,000 492,000,000 debt Debt Instrument 500,000,000 500,000,000

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Unamortized Issuance (5,000,000) (7,000,000) (5,000,000) (5,000,000) (7,000,000) Expense Unamortized Debt Discount 0 0 0 0 0 Total, long-term debt $ 487,000,000 $ 487,000,000 $ 487,000,000 Total debt $ 493,000,000 $ 493,000,000 Stated interest rate 7.75% 7.75% 7.75% 7.75% 7.75% Unamortized issuance expense $ 5,000,000 $ 7,000,000 $ 5,000,000 $ 5,000,000 $ 7,000,000 Repurchased amount $ 8,000,000 $ 8,000,000 $ 8,000,000 Long-term debt | 4.05% Senior Notes due January 2020 Debt Instrument [Line Items] Stated interest rate 6.05% 6.05% 6.05% 5.30%5.80%4.05% Long-term debt | 4.95% Senior Notes due January 2025 Debt Instrument [Line Items] Stated interest rate 6.95% 6.95% 6.95% 6.20%6.70%4.95% LIBOR | Senior Notes Debt Instrument [Line Items] Increase in basis spread 1.75%1.75% Other long-term assets | Line of Credit | 2018 revolving credit facility, due April 2023 Debt Instrument [Line Items] Unamortized Issuance $ (9,000,000) (12,000,000) $ (9,000,000) $ (9,000,000) (12,000,000) Expense Unamortized issuance expense $ 9,000,000 $ 12,000,000 $ 9,000,000 $ 9,000,000 $ 12,000,000

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 3 Months Ended 9 Months Ended (Schedule of Equity- Classified Stock-Based Compensation Costs) Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 (Details) - USD ($) $ in Millions Share-based Compensation [Abstract] Equity-classified awards – expensed $ 2 $ 3 $ 6 $ 12 Equity-classified awards – capitalized $ 1 $ 2 $ 3 $ 6

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 3 Months Ended 9 Months Ended (Schedule of Liability- Classified Stock-Based Sep. 30, Sep. 30, Sep. 30, Sep. 30, Compensation Costs) 2019 2018 2019 2018 (Details) - USD ($) $ in Millions Share-based Compensation [Abstract] Liability-classified stock-based compensation cost – $ (1) $ 4 $ 6 $ 8 expensed Liability-classified stock-based compensation cost – $ 0 $ 1 $ 4 $ 4 capitalized

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Commitments and Contingencies (Schedule of Future Obligation under Sep. 30, 2019 Transportation Agreements) USD ($) (Details) $ in Millions Other Commitments [Line Items] Total $ 8,194 Less than 1 year 700 1 to 3 years 1,345 3 to 5 years 1,150 5 to 8 years 1,667 More than 8 years 3,332 Infrastructure currently in service Other Commitments [Line Items] Total 7,442 Less than 1 year 681 1 to 3 years 1,272 3 to 5 years 1,075 5 to 8 years 1,528 More than 8 years 2,886 Pending regulatory approval and/or construction Other Commitments [Line Items] Total 752 Less than 1 year 19 1 to 3 years 73 3 to 5 years 75 5 to 8 years 139 More than 8 years $ 446

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Basis of Presentation Sep. 30, 2019 (Narrative) (Details) segment Organization, Consolidation and Presentation of Financial Statements [Abstract] Number of segments 2

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 1 Months 3 Months Leases (New Accounting) Ended Ended (Details) - USD ($) Jan. 01, $ in Millions Jul. 31, 2019 Sep. 30, 2019 2019 New Accounting Pronouncements or Change in Accounting Principle [Line Items] Right-of-use asset $ 164 Lease liability balance 159 Term of contract 10 years Payment to previous lessor $ 6 Increase in ROU assets $ 56 ASU 2016-02 New Accounting Pronouncements or Change in Accounting Principle [Line Items] Right-of-use asset $ 105 Lease liability balance $ 105

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk 3 Months Ended 9 Months Ended Management (Summary of Before Tax Effect of Fair Value Hedges not Designated Sep. 30, Sep. 30, Sep. 30, Sep. 30, for Hedge Accounting) 2019 2018 2019 2018 (Details) - USD ($) $ in Millions Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in $ 12 $ (59) $ 108 $ (113) Earnings Settled Gain (Loss) on Derivatives Recognized in 88 (6) 112 5 Earnings Total gain (loss) on derivatives 100 (65) 220 (108) Purchased fixed price swaps | Oil Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 0 0 5 0 Earnings Settled Gain (Loss) on Derivatives Recognized in 0 0 (2) 0 Earnings Fixed price swaps | Oil Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 8 0 0 0 Earnings Settled Gain (Loss) on Derivatives Recognized in 3 0 7 0 Earnings Fixed price swaps | Natural Gas Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in (19) (17) 36 (46) Earnings Settled Gain (Loss) on Derivatives Recognized in 45 5 53 18 Earnings Fixed price swaps | Propane Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 10 (10) 19 (19) Earnings Settled Gain (Loss) on Derivatives Recognized in 11 (5) 20 (6) Earnings Fixed price swaps | Ethane Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 1 (27) 8 (29) Earnings Settled Gain (Loss) on Derivatives Recognized in 6 (6) 12 (6) Earnings Two-way costless collars | Oil Derivative Instruments, Gain (Loss) [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Unsettled Gain (Loss) on Derivatives Recognized in 0 0 (3) 0 Earnings Settled Gain (Loss) on Derivatives Recognized in 2 0 4 0 Earnings Two-way costless collars | Natural Gas Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in (11) 2 (2) 4 Earnings Settled Gain (Loss) on Derivatives Recognized in 10 0 12 4 Earnings Two-way costless collars | Propane Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 1 0 3 0 Earnings Settled Gain (Loss) on Derivatives Recognized in 1 0 1 0 Earnings Three-way costless collars | Oil Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 3 0 4 0 Earnings Three-way costless collars | Natural Gas Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 3 (7) 27 (36) Earnings Settled Gain (Loss) on Derivatives Recognized in 15 5 19 24 Earnings Basis swaps | Natural Gas Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 12 (5) 6 11 Earnings Settled Gain (Loss) on Derivatives Recognized in (3) (4) (11) (28) Earnings Purchased call options | Natural Gas Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in (1) (2) (3) 2 Earnings Settled Gain (Loss) on Derivatives Recognized in (1) 0 (1) 2 Earnings Amortization of premium paid 1 1 1 Sold call options | Oil Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 0 1 0 (5) Earnings Settled Gain (Loss) on Derivatives Recognized in 0 (1) 0 (2) Earnings Sold call options | Natural Gas

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 2 5 8 2 Earnings Settled Gain (Loss) on Derivatives Recognized in 0 0 (1) (1) Earnings Storage - fixed price swap Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in 2 0 1 0 Earnings Settled Gain (Loss) on Derivatives Recognized in (1) 0 (1) 0 Earnings Interest rate swaps Derivative Instruments, Gain (Loss) [Line Items] Unsettled Gain (Loss) on Derivatives Recognized in $ 1 $ 1 $ (1) $ 3 Earnings

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Consolidating 3 Months Ended 9 Months Ended Financial Information (Condensed Consolidating Sep. 30, Jun. 30, Mar. 31, Sep. 30, Jun. 30, Mar. 31, Sep. 30, Sep. 30, Statement of Operations) 2019 2019 2019 2018 2018 2018 2019 2018 (Details) - USD ($) $ in Millions Condensed Income Statements, Captions [Line Items] Total operating revenues $ $ 636 $ 951 $ 2,293 2,687 Operating expenses 189 206 523 588 General and administrative expenses 42 51 119 165 Loss on sale of operating assets 0 0 3 0 Restructuring charges 4 2 9 20 Depreciation, depletion and 125 151 352 426 amortization Impairments 2 161 8 171 Taxes, other than income taxes 15 26 51 64 Total operating costs and expense 665 885 2,087 2,242 Operating Income (Loss) (29) 66 206 445 Interest Expense, Net 17 29 46 100 Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on Early Extinguishment 7 0 7 (8) of Debt Other Income (Loss), Net (2) (1) (7) 1 Equity in Earnings of Subsidiaries 0 0 0 0 Income (Loss) Before Income Taxes 59 (29) 380 230 Provision (benefit) for income taxes 10 0 (401) 0 Net Income (Loss) 49 $ 138 $ 594 (29) [1] $ 51 $ 208 781 230 [1] Participating securities – mandatory 0 0 0 1 convertible preferred stock Net Income (Loss) Attributable to 49 (29) 781 229 Common Stock Other comprehensive income 1 4 4 5 4 Comprehensive income (loss) 50 $ 142 $ 594 (25) [1] $ 51 $ 208 786 234 [1] Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Operating expenses 0 0 0 0 General and administrative expenses 0 0 0 0 Loss on sale of operating assets 0 Restructuring charges 0 0 0 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Depreciation, depletion and 0 0 0 0 amortization Impairments 0 0 0 0 Taxes, other than income taxes 0 0 0 0 Total operating costs and expense 0 0 0 0 Operating Income (Loss) 0 0 0 0 Interest Expense, Net 0 0 0 0 Gain (Loss) on Derivatives 0 0 0 0 Gain (Loss) on Early Extinguishment 0 0 0 of Debt Other Income (Loss), Net 0 0 0 0 Equity in Earnings of Subsidiaries (58) 0 (819) (338) Income (Loss) Before Income Taxes (58) 0 (819) (338) Provision (benefit) for income taxes 0 0 0 0 Net Income (Loss) (58) 0 (819) (338) Participating securities – mandatory 0 convertible preferred stock Net Income (Loss) Attributable to (338) Common Stock Other comprehensive income 0 0 0 0 Comprehensive income (loss) (58) 0 (819) (338) Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Operating expenses 0 0 0 0 General and administrative expenses 0 0 0 0 Loss on sale of operating assets 0 Restructuring charges 0 0 0 0 Depreciation, depletion and 0 0 0 0 amortization Impairments 0 0 0 0 Taxes, other than income taxes 0 0 0 0 Total operating costs and expense 0 0 0 0 Operating Income (Loss) 0 0 0 0 Interest Expense, Net 17 29 46 100 Gain (Loss) on Derivatives 0 0 0 0 Gain (Loss) on Early Extinguishment 7 7 (8) of Debt Other Income (Loss), Net 0 0 0 0 Equity in Earnings of Subsidiaries 59 0 820 338 Income (Loss) Before Income Taxes 49 (29) 781 230 Provision (benefit) for income taxes 0 0 0 0 Net Income (Loss) 49 (29) 781 230

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Participating securities – mandatory 1 convertible preferred stock Net Income (Loss) Attributable to 229 Common Stock Other comprehensive income 1 4 5 4 Comprehensive income (loss) 50 (25) 786 234 Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 636 951 2,293 2,687 Operating expenses 189 206 523 588 General and administrative expenses 42 51 119 165 Loss on sale of operating assets 3 Restructuring charges 4 2 9 20 Depreciation, depletion and 124 151 351 426 amortization Impairments 2 161 8 171 Taxes, other than income taxes 15 26 51 64 Total operating costs and expense 664 885 2,086 2,242 Operating Income (Loss) (28) 66 207 445 Interest Expense, Net 0 0 0 0 Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on Early Extinguishment 0 0 0 of Debt Other Income (Loss), Net (2) (1) (7) 1 Equity in Earnings of Subsidiaries (1) 0 (1) 0 Income (Loss) Before Income Taxes 69 0 419 338 Provision (benefit) for income taxes 10 0 (401) 0 Net Income (Loss) 59 0 820 338 Participating securities – mandatory 0 convertible preferred stock Net Income (Loss) Attributable to 338 Common Stock Other comprehensive income 0 0 0 0 Comprehensive income (loss) 59 0 820 338 Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Operating expenses 0 0 0 0 General and administrative expenses 0 0 0 0 Loss on sale of operating assets 0 Restructuring charges 0 0 0 0 Depreciation, depletion and 1 0 1 0 amortization

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Impairments 0 0 0 0 Taxes, other than income taxes 0 0 0 0 Total operating costs and expense 1 0 1 0 Operating Income (Loss) (1) 0 (1) 0 Interest Expense, Net 0 0 0 0 Gain (Loss) on Derivatives 0 0 0 0 Gain (Loss) on Early Extinguishment 0 0 0 of Debt Other Income (Loss), Net 0 0 0 0 Equity in Earnings of Subsidiaries 0 0 0 0 Income (Loss) Before Income Taxes (1) 0 (1) 0 Provision (benefit) for income taxes 0 0 0 0 Net Income (Loss) (1) 0 (1) 0 Participating securities – mandatory 0 convertible preferred stock Net Income (Loss) Attributable to 0 Common Stock Other comprehensive income 0 0 0 0 Comprehensive income (loss) (1) 0 (1) 0 Gas sales Condensed Income Statements, Captions [Line Items] Total operating revenues 238 465 943 1,412 Gas sales | Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Gas sales | Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Gas sales | Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 238 465 943 1,412 Gas sales | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Oil sales Condensed Income Statements, Captions [Line Items] Total operating revenues 67 62 153 141 Oil sales | Eliminations

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Oil sales | Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Oil sales | Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 67 62 153 141 Oil sales | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 NGL sales Condensed Income Statements, Captions [Line Items] Total operating revenues 52 112 191 252 NGL sales | Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 NGL sales | Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 NGL sales | Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 52 112 191 252 NGL sales | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Marketing Condensed Income Statements, Captions [Line Items] Total operating revenues 279 287 1,004 805 Marketing | Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Marketing | Parent

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Marketing | Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 279 287 1,004 805 Marketing | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 0 0 Gas gathering Condensed Income Statements, Captions [Line Items] Total operating revenues 0 25 0 73 Gas gathering | Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Gas gathering | Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Gas gathering | Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 25 73 Gas gathering | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Other Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 2 4 Other | Eliminations Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Other | Parent Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Other | Guarantors

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Income Statements, Captions [Line Items] Total operating revenues 2 4 Other | Non-Guarantors Condensed Income Statements, Captions [Line Items] Total operating revenues 0 0 Marketing purchases Condensed Income Statements, Captions [Line Items] Marketing purchases 288 288 1,022 808 Marketing purchases | Eliminations Condensed Income Statements, Captions [Line Items] Marketing purchases 0 0 0 0 Marketing purchases | Parent Condensed Income Statements, Captions [Line Items] Marketing purchases 0 0 0 0 Marketing purchases | Guarantors Condensed Income Statements, Captions [Line Items] Marketing purchases 288 288 1,022 808 Marketing purchases | Non-Guarantors Condensed Income Statements, Captions [Line Items] Marketing purchases $ 0 $ 0 $ 0 $ 0 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Earnings Per Share 3 Months Ended 9 Months Ended (Schedule of Antidilutive Securities Excluded from Sep. 30, Sep. 30, Sep. 30, Sep. 30, Computation of Earnings 2019 2018 2019 2018 Per Share) (Details) - shares Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Antidilutive securities excluded from computation of earnings per 7,479,785 5,465,072 7,160,740 8,399,837 share (in shares) Unexercised stock options Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Antidilutive securities excluded from computation of earnings per 5,102,882 717 5,115,334 0 share (in shares) Unvested share-based payment Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Antidilutive securities excluded from computation of earnings per 2,136,453 3,463,802 1,797,963 4,246,492 share (in shares) Performance units Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Antidilutive securities excluded from computation of earnings per 240,450 2,000,553 247,443 856,703 share (in shares) Mandatory convertible preferred stock Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] Antidilutive securities excluded from computation of earnings per 0 0 0 3,296,642 share (in shares)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 3 Months 9 Months Fair Value Measurements Ended Ended (Narrative) (Details) - USD Sep. Sep. Sep. Sep. Jul. Jul. Jan. ($) 30, 30, 30, 30, 31, 31, 31, $ in Millions 2019 2018 2019 2018 2018 2016 2015 Debt Instrument [Line Items] Impairments $ 2 $ 161 $ 8 $ 171 Long-term debt | 4.05% Senior Notes due January 2020 Debt Instrument [Line Items] Stated interest rate 6.05% 6.05% 5.30% 5.80% 4.05% Long-term debt | 4.05% Senior Notes due January 2020 | Significant Other Observable Inputs (Level 2) Debt Instrument [Line Items] Stated interest rate 3.42% Fayetteville Shale Debt Instrument [Line Items] Impairments 161 161 Midstream Debt Instrument [Line Items] Impairments $ 2 145 $ 2 155 Midstream | Fayetteville Shale Debt Instrument [Line Items] Impairments 145 145 E&P Debt Instrument [Line Items] Impairments $ 0 15 $ 6 15 E&P | Fayetteville Shale Debt Instrument [Line Items] Impairments 15 15 Non-Core Assets Debt Instrument [Line Items] Impairments $ 1 $ 1

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED Accumulated STATEMENTS OF Additional Common Common Preferred Accumulated Other CHANGES IN EQUITY - Total Paid-In Stock in Stock Stock Deficit Comprehensive USD ($) Capital Treasury Income (Loss) $ in Millions Balance beginning at Dec. $ 1,979 $ 5 $ 4,698 $ (2,679) $ (44) $ (1) 31, 2017 Balance (in shares) at Dec. 512,134,311 1,725,000 31,269 31, 2017 Comprehensive income: Net income 208 208 Comprehensive income 208 (loss) Stock-based compensation 7 7 Conversion of preferred 74,998,614 (1,725,000) stock (in shares) Conversion of preferred $ 1 (1) stock Issuance of restricted stock 5,076 (in shares) Cancellation of restricted (160,168) stock (in shares) Performance units vested (in 214,866 shares) Tax withholding - stock (338,808) compensation (in shares) Tax withholding - stock (1) (1) compensation Balance (in shares) at Mar. 586,853,8910 31,269 31, 2018 Balance ending at Mar. 31, 2,193 $ 6 4,703 (2,471) (44) $ (1) 2018 Balance beginning at Dec. 1,979 $ 5 4,698 (2,679) (44) $ (1) 31, 2017 Balance (in shares) at Dec. 512,134,311 1,725,000 31,269 31, 2017 Comprehensive income: Net income [1] 230 Other comprehensive income 4 Comprehensive income [1] 234 (loss) Balance (in shares) at Sep. 586,195,1620 4,860,280 30, 2018 Balance ending at Sep. 30, 2,205 $ 6 4,714 (2,449) (40) $ (26) 2018 Balance beginning at Dec. 1,979 $ 5 4,698 (2,679) (44) $ (1) 31, 2017 Balance (in shares) at Dec. 512,134,311 1,725,000 31,269 31, 2017

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Balance (in shares) at Dec. 585,407,107 39,092,537 31, 2018 Balance ending at Dec. 31, 2,362 $ 6 4,715 (2,142) (36) $ (181) 2018 Balance beginning at Mar. 2,193 $ 6 4,703 (2,471) (44) $ (1) 31, 2018 Balance (in shares) at Mar. 586,853,8910 31,269 31, 2018 Comprehensive income: Net income 51 51 Comprehensive income 51 (loss) Stock-based compensation 6 6 Issuance of restricted stock 307,743 (in shares) Cancellation of restricted (722,465) stock (in shares) Tax withholding - stock (9,068) compensation (in shares) Balance (in shares) at Jun. 586,430,1010 31,269 30, 2018 Balance ending at Jun. 30, 2,250 $ 6 4,709 (2,420) (44) $ (1) 2018 Comprehensive income: Net income (29) [1] (29) Other comprehensive income 4 4 Comprehensive income [1] (25) (loss) Stock-based compensation 5 5 Issuance of restricted stock 30,924 (in shares) Cancellation of restricted (248,342) stock (in shares) Treasury stock (in shares) 4,829,011 Treasury stock (25) $ (25) Tax withholding - stock (17,521) compensation (in shares) Balance (in shares) at Sep. 586,195,1620 4,860,280 30, 2018 Balance ending at Sep. 30, 2,205 $ 6 4,714 (2,449) (40) $ (26) 2018 Balance beginning at Jun. $ 2,250 $ 6 4,709 (2,420) (44) $ (1) 30, 2018 Balance (in shares) at Jun. 586,430,1010 31,269 30, 2018 Comprehensive income: Treasury stock (in shares) 39,061,269 Treasury stock $ (180) Balance (in shares) at Dec. 585,407,107 39,092,537 31, 2018

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Balance ending at Dec. 31, 2,362 $ 6 4,715 (2,142) (36) $ (181) 2018 Comprehensive income: Net income 594 594 Comprehensive income 594 (loss) Stock-based compensation $ 3 3 Issuance of restricted stock 8,798 (in shares) Cancellation of restricted (128,324) stock (in shares) Treasury stock (in shares) 5,260,687 5,260,687 Treasury stock $ (21) $ (21) Performance units vested (in 535,802 shares) Tax withholding - stock (274,657) compensation (in shares) Tax withholding - stock (1) (1) compensation Balance (in shares) at Mar. 585,548,726 44,353,224 31, 2019 Balance ending at Mar. 31, 2,937 $ 6 4,717 (1,548) (36) $ (202) 2019 Balance beginning at Dec. 2,362 $ 6 4,715 (2,142) (36) $ (181) 31, 2018 Balance (in shares) at Dec. 585,407,107 39,092,537 31, 2018 Comprehensive income: Net income 781 Other comprehensive income 5 5 Comprehensive income 786 (loss) Balance (in shares) at Sep. 585,637,420 44,353,224 30, 2019 Balance ending at Sep. 30, 3,135 $ 6 4,723 (1,361) (31) $ (202) 2019 Balance beginning at Mar. 2,937 $ 6 4,717 (1,548) (36) $ (202) 31, 2019 Balance (in shares) at Mar. 585,548,726 44,353,224 31, 2019 Comprehensive income: Net income 138 138 Other comprehensive income 4 4 Comprehensive income 142 (loss) Stock-based compensation 3 3 Issuance of restricted stock 6,424 (in shares) Cancellation of restricted (72,555) stock (in shares)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Tax withholding - stock (4,250) compensation (in shares) Balance (in shares) at Jun. 585,478,345 44,353,224 30, 2019 Balance ending at Jun. 30, 3,082 $ 6 4,720 (1,410) (32) $ (202) 2019 Comprehensive income: Net income 49 49 Other comprehensive income 1 1 Comprehensive income 50 (loss) Stock-based compensation 3 3 Issuance of restricted stock 205,883 (in shares) Cancellation of restricted (33,851) stock (in shares) Tax withholding - stock (12,957) compensation (in shares) Balance (in shares) at Sep. 585,637,420 44,353,224 30, 2019 Balance ending at Sep. 30, $ 3,135 $ 6 $ 4,723 $ (1,361) $ (31) $ (202) 2019 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED 3 Months Ended 9 Months Ended STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 USD ($) $ in Millions Statement of Comprehensive Income [Abstract] Defined benefit plan, tax (less than) $ 1 $ 1 $ 2 $ 1

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document New Accounting 9 Months Ended Pronouncements Sep. 30, 2019 Accounting Policies [Abstract] New Accounting NEW ACCOUNTING PRONOUNCEMENTS Pronouncements New Accounting Standards Implemented

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. The codification was amended through additional ASUs. For public entities, Update 2016-02 became effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company adopted ASC 842 with an effective date of January 1, 2019 using the modified retrospective approach for all leases that existed at the date of initial application. The Company elected to apply the transition as of the beginning of the period of adoption. For leases that existed at the period of adoption on January 1, 2019, the incremental borrowing rate as of the application date was used to calculate the present value of remaining lease payments. Upon adoption of ASC 842, the Company recognized a discounted right-of-use asset and corresponding lease liability with opening balances of approximately $105 million as of January 1, 2019. The adoption of the standard did not materially change the Company’s consolidated statement of operations or its consolidated statement of cash flows. Please refer to Note 4 – “Leases” for full disclosure.

New Accounting Standards Not Yet Implemented

In June 2016, the FASB issued Accounting Standards Update No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“Update 2016-13”). Update 2016-13 replaces the incurred loss model with an expected loss model, which is referred to as the current expected credit loss (“CECL”) model. The CECL model is applicable to the measurement of credit losses on financial assets measured at amortized cost, including but not limited to trade receivables.

From evaluation of the Company’s current credit portfolio, which includes trade receivables from commodity sales, joint interest billings due from partners and other receivables, historical credit losses have been de minimis. The Company believes that its expected future credit losses will not be significant, and therefore Southwestern does not believe the adoption of the standard will have a material impact on its consolidated financial statements. The Company will continue to monitor changes in its credit portfolio as evaluation progresses. For public business entities, the new standard is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Income Taxes Sep. 30, 2019 Income Tax Expense (Benefit), Continuing Operations [Abstract] Income Taxes INCOME TAXES

The Company’s effective tax rate was approximately 18% and 0% for the three months ended September 30, 2019 and 2018, respectively, and (105)% and 0% for the nine months ended September 30, 2019 and 2018, respectively. The change in the effective tax rate for the three and nine months ended September 30, 2019 was primarily the effect of releasing the valuation allowances previously recorded against the Company’s deferred tax assets. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgment regarding future taxable income, and considers the tax consequences in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is required. Such evidence can include current financial position, results of operations, both actual and forecasted, the reversal of deferred tax liabilities and tax planning strategies as well as the current and forecasted business economics of the oil and gas industry.

For the year ended December 31, 2018, the Company maintained a full valuation allowance against its deferred tax assets based on its conclusion, considering all available evidence (both positive and negative), that it was more likely than not that the deferred tax assets would not be realized. A significant item of objective negative evidence considered was the cumulative pre-tax loss incurred over the three-year period ended December 31, 2018, primarily due to impairments of proved natural gas and oil properties recognized in 2015 and 2016. As of the first quarter of 2019, the Company had sustained a three-year cumulative level of profitability. Based on this factor and other positive evidence including forecasted income, the Company concluded that it was more likely than not that the deferred tax assets would be realized and determined $522 million of the valuation allowance will be released. For the nine months ended September 30, 2019, the Company recorded a discrete tax benefit of $399 million, with the remainder being recognized through current period activity. The Company expects to retain a valuation allowance of $87 million related to net operating losses in jurisdictions in which it no longer operates.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Consolidating 9 Months Ended Financial Information Sep. 30, 2019 (Tables) Condensed Financial Information Disclosure [Abstract] Condensed Consolidating Statements Of Operations CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 238 $ — $ — $ 238 Oil sales — 67 — — 67 NGL sales — 52 — — 52 Marketing — 279 — — 279

— 636 — — 636 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 189 — — 189 General and administrative expenses — 42 — — 42 Restructuring charges — 4 — — 4 Depreciation, depletion and amortization — 124 1 — 125 Impairments — 2 — — 2 Taxes, other than income taxes — 15 — — 15

— 664 1 — 665

Operating Loss — (28) (1) — (29)

Interest Expense, Net 17 — — — 17 Gain on Derivatives — 100 — — 100 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (2) — — (2) Equity in Earnings of Subsidiaries 59 (1) — (58) —

Income (Loss) Before Income Taxes 49 69 (1) (58) 59 Provision for Income Taxes — 10 — — 10

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49 Other Comprehensive Income 1 — — — 1

Comprehensive Income (Loss) $ 50 $ 59 $ (1) $ (58) $ 50

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 465 $ — $ — $ 465 Oil sales — 62 — — 62 NGL sales — 112 — — 112 Marketing — 287 — — 287 Gas gathering — 25 — — 25

— 951 — — 951 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 206 — — 206 General and administrative expenses — 51 — — 51 Restructuring charges — 2 — — 2 Depreciation, depletion and amortization — 151 — — 151 Impairments — 161 — — 161 Taxes, other than income taxes — 26 — — 26

— 885 — — 885

Operating Income — 66 — — 66

Interest Expense, Net 29 — — — 29 Loss on Derivatives — (65) — — (65) Other Loss, Net — (1) — — (1) Equity in Earnings of Subsidiaries — — — — —

Loss Before Income Taxes (29) — — — (29) Provision for Income Taxes — — — — —

Net Loss $ (29) $ — $ — $ — $ (29)

Net Loss $ (29) $ — $ — $ — $ (29) Other Comprehensive Income 4 — — — 4

Comprehensive Loss $ (25) $ — $ — $ — $ (25)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 943 $ — $ — $ 943 Oil sales — 153 — — 153 NGL sales — 191 — — 191 Marketing — 1,004 — — 1,004 Other — 2 — — 2 — 2,293 — — 2,293 Operating Costs and Expenses: Marketing purchases — 1,022 — — 1,022 Operating expenses — 523 — — 523 General and administrative expenses — 119 — — 119 Loss on sale of operating assets — 3 — — 3 Restructuring charges — 9 — — 9 Depreciation, depletion and amortization — 351 1 — 352 Impairments — 8 — — 8 Taxes, other than income taxes — 51 — — 51 — 2,086 1 — 2,087

Operating Income (Loss) — 207 (1) — 206 Interest Expense, Net 46 — — — 46 Gain on Derivatives — 220 — — 220 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (7) — — (7) Equity in Earnings of Subsidiaries 820 (1) — (819) —

Income (Loss) Before Income Taxes 781 419 (1) (819) 380 Benefit from Income Taxes — (401) — — (401) Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781

Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781 Other Comprehensive Income 5 — — — 5

Comprehensive Income (Loss) $ 786 $ 820 $ (1) $ (819) $ 786

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 1,412 $ — $ — $ 1,412 Oil sales — 141 — — 141 NGL sales — 252 — — 252 Marketing — 805 — — 805 Gas gathering — 73 — — 73 Other — 4 — — 4 — 2,687 — — 2,687 Operating Costs and Expenses: Marketing purchases — 808 — — 808 Operating expenses — 588 — — 588 General and administrative expenses — 165 — — 165 Restructuring charges — 20 — — 20 Depreciation, depletion and amortization — 426 — — 426 Impairments — 171 — — 171 Taxes, other than income taxes — 64 — — 64 — 2,242 — — 2,242

Operating Income — 445 — — 445 Interest Expense, Net 100 — — — 100 Loss on Derivatives — (108) — — (108) Loss on Early Extinguishment of Debt (8) — — — (8) Other Income, Net — 1 — — 1 Equity in Earnings of Subsidiaries 338 — — (338) —

Income (Loss) Before Income Taxes 230 338 — (338) 230 Provision for Income Taxes — — — — — Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230

Participating securities – mandatory convertible preferred stock 1 — — — 1

Net Income (Loss) Attributable to Common Stock $ 229 $ 338 $ — $ (338) $ 229

Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230 Other Comprehensive Income 4 — — — 4

Comprehensive Income (Loss) $ 234 $ 338 $ — $ (338) $ 234

Condensed Consolidating CONDENSED CONSOLIDATED BALANCE SHEETS Balance Sheets (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated September 30, 2019 ASSETS Cash and cash equivalents $ 29 $ — $ — $ — $ 29 Accounts receivable, net — 323 — — 323 Other current assets 6 275 — — 281 Total current assets 35 598 — — 633

Intercompany receivables 7,957 — — (7,957) —

Natural gas and oil properties, using the full cost method — 25,006 54 — 25,060 Other 179 314 29 — 522 Less: Accumulated depreciation, depletion and amortization (149) (20,176) (58) — (20,383) Total property and equipment, net 30 5,144 25 — 5,199

Investments in subsidiaries (equity method) — 23 — (23) — Other long-term assets 99 667 — — 766

TOTAL ASSETS $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

LIABILITIES AND EQUITY Current portion of long-term debt $ 52 $ — $ — $ — $ 52 Accounts payable 77 462 — — 539 Other current liabilities 130 159 — — 289 Total current liabilities 259 621 — — 880

Intercompany payables — 7,955 2 (7,957) —

Long-term debt 2,219 — — — 2,219 Pension and other postretirement liabilities 39 — — — 39 Other long-term liabilities 87 238 — — 325 Negative carrying amount of subsidiaries, net 2,382 — — (2,382) — Total long-term liabilities 4,727 238 — (2,382) 2,583 Commitments and contingencies Total equity (accumulated deficit) 3,135 (2,382) 23 2,359 3,135

TOTAL LIABILITIES AND EQUITY $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated December 31, 2018 ASSETS Cash and cash equivalents $ 201 $ — $ — $ — $ 201 Accounts receivable, net 4 577 — — 581 Other current assets 8 166 — — 174

Total current assets 213 743 — — 956

Intercompany receivables 7,932 — — (7,932) —

Natural gas and oil properties, using the full cost method — 24,128 52 — 24,180 Other 197 301 27 — 525 Less: Accumulated depreciation, depletion and amortization (154) (19,840) (55) — (20,049)

Total property and equipment, net 43 4,589 24 — 4,656

Investments in subsidiaries (equity method) — 24 — (24) — Other long-term assets 19 166 — — 185

TOTAL ASSETS $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

LIABILITIES AND EQUITY Accounts payable $ 113 $ 496 $ — $ — $ 609 Other current liabilities 115 122 — — 237

Total current liabilities 228 618 — — 846

Intercompany payables — 7,932 — (7,932) —

Long-term debt 2,318 — — — 2,318 Pension and other postretirement liabilities 46 — — — 46 Other long-term liabilities 54 171 — — 225 Negative carrying amount of subsidiaries, net 3,199 — — (3,199) —

Total long-term liabilities 5,617 171 — (3,199) 2,589 Commitments and contingencies Total equity (accumulated deficit) 2,362 (3,199) 24 3,175 2,362

TOTAL LIABILITIES AND EQUITY $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

Condensed Consolidating CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS Statements Of Cash Flows (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Net cash provided by (used in) operating activities $ 1,154 $ 404 $ — $ (819) $ 739 Investing activities: Capital investments — (875) (2) — (877) Proceeds from sale of property and equipment — 42 — — 42

Net cash used in investing activities — (833) (2) — (835) Financing activities: Intercompany activities (1,250) 429 2 819 — Payments on long-term debt (43) — — — (43) Change in bank drafts outstanding (11) — — — (11) Purchase of treasury stock (21) — — — (21) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (1,326) 429 2 819 (76)

Decrease in cash and cash equivalents (172) — — — (172) Cash and cash equivalents at beginning of year 201 — — — 201

Cash and cash equivalents at end of period $ 29 $ — $ — $ — $ 29

Nine months ended September 30, 2018 Net cash provided by (used in) operating activities $ 57 $ 1,396 $ — $ (482) $ 971 Investing activities: Capital investments (12) (996) — — (1,008) Proceeds from sale of property and equipment — 9 — 9 Other 4 — — — 4

Net cash used in investing activities (8) (987) — — (995) Financing activities: Intercompany activities (71) (411) — 482 — Payments on long-term debt (1,191) — — — (1,191) Payments on revolving credit facility (1,122) — — — (1,122) Borrowings under revolving credit facility 1,482 — — — 1,482 Change in bank drafts outstanding 10 — — — 10 Debt issuance costs (9) — — — (9) Purchase of treasury stock (25) — — — (25) Preferred stock dividend (27) — — — (27) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (954) (411) — 482 (883)

Decrease in cash and cash equivalents (905) (2) — — (907) Cash and cash equivalents at beginning of year 914 2 — — 916

Cash and cash equivalents at end of period $ 9 $ — $ — $ — $ 9

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Restructuring Charges 3 Months Ended 9 Months Ended (Restructuring Rollforward) (Details) - USD ($) Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 $ in Millions Restructuring Reserve [Roll Forward] Additions $ 4.0 $ 2.0 $ 9.0 $ 20.0 Workforce Reduction Restructuring Reserve [Roll Forward] Liability at December 31, 2018 5.0 Additions 4.0 $ 2.0 9.0 $ 20.0 Distributions (13.0) Liability at September 30, 2019 $ 1.0 $ 1.0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value Measurements 9 Months (Summary of Assets and Ended Liabilities Measured at Fair Value on Recurring Basis) Dec. 31, Sep. 30, 2019 (Details) - USD ($) 2018 $ in Millions Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Total $ 169 $ 52 Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Total 0 0 Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Total 169 52 Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Total 0 0 Purchased fixed price swaps | Oil Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities (1) (6) Purchased fixed price swaps | Oil | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities 0 0 Purchased fixed price swaps | Oil | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities (1) (6) Purchased fixed price swaps | Oil | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities 0 0 Fixed price swaps | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 73 38 Derivative liabilities (10) Premium paid 9 Fixed price swaps | Natural Gas | Quoted Prices in Active Markets (Level 1)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Fixed price swaps | Natural Gas | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 73 38 Derivative liabilities (10) Fixed price swaps | Natural Gas | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Fixed price swaps | Oil Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 19 19 Fixed price swaps | Oil | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Fixed price swaps | Oil | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 19 19 Fixed price swaps | Oil | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Fixed price swaps | Propane Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 30 11 Fixed price swaps | Propane | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Fixed price swaps | Propane | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 30 11 Fixed price swaps | Propane | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative assets 0 0 Fixed price swaps | Ethane Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 13 8 Derivative liabilities (3) Fixed price swaps | Ethane | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Fixed price swaps | Ethane | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 13 8 Derivative liabilities (3) Fixed price swaps | Ethane | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Two-way costless collars | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 2 11 Derivative liabilities (7) Two-way costless collars | Natural Gas | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Two-way costless collars | Natural Gas | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 2 11 Derivative liabilities (7) Two-way costless collars | Natural Gas | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Two-way costless collars | Oil Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative assets 7 11 Derivative liabilities (1) Two-way costless collars | Oil | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Two-way costless collars | Oil | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 7 11 Derivative liabilities (1) Two-way costless collars | Oil | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 Two-way costless collars | Propane Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 3 Two-way costless collars | Propane | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Two-way costless collars | Propane | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 3 Two-way costless collars | Propane | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Three-way costless collars | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 147 75 Derivative liabilities (113) (68) Three-way costless collars | Natural Gas | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 0 Three-way costless collars | Natural Gas | Significant Other Observable Inputs (Level 2)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 147 75 Derivative liabilities (113) (68) Three-way costless collars | Natural Gas | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 0 Three-way costless collars | Oil Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 13 Derivative liabilities (9) Three-way costless collars | Oil | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Derivative liabilities 0 Three-way costless collars | Oil | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 13 Derivative liabilities (9) Three-way costless collars | Oil | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Derivative liabilities 0 Basis swaps | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 24 11 Derivative liabilities (29) (22) Basis swaps | Natural Gas | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 0 Basis swaps | Natural Gas | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 24 11 Derivative liabilities (29) (22) Basis swaps | Natural Gas | Significant Unobservable Inputs (Level 3)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Derivative liabilities 0 0 Purchased call options | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 3 6 Purchased call options | Natural Gas | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Purchased call options | Natural Gas | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 3 6 Purchased call options | Natural Gas | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 0 Interest rate swaps Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 1 Interest rate swaps | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Interest rate swaps | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 1 Interest rate swaps | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Sold call options | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities (14) (22) Sold call options | Natural Gas | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities 0 0 Sold call options | Natural Gas | Significant Other Observable Inputs (Level 2)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities (14) (22) Sold call options | Natural Gas | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative liabilities 0 $ 0 Storage - fixed price swap Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 1 Storage - fixed price swap | Quoted Prices in Active Markets (Level 1) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 0 Storage - fixed price swap | Significant Other Observable Inputs (Level 2) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets 1 Storage - fixed price swap | Significant Unobservable Inputs (Level 3) Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative assets $ 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Reclassifications from 3 Months Ended 9 Months Ended Accumulated Other Comprehensive Income (Loss) (Components of Sep. 30, Jun. 30, Sep. 30, Sep. 30, Sep. 30, Accumulated Other 2019 2019 2018 2019 2018 Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions AOCI Attributable to Parent, Net of Tax [Roll Forward] Balance beginning $ 3,082 $ 2,937 $ 2,250 $ 2,362 $ 1,979 Net current-period other comprehensive income 1 4 4 5 4 Balance ending 3,135 3,082 2,205 3,135 2,205 Pension and Other Postretirement AOCI Attributable to Parent, Net of Tax [Roll Forward] Balance beginning (22) Other comprehensive income before 0 reclassifications Amounts reclassified from other comprehensive 5 income Net current-period other comprehensive income 5 Balance ending (17) (17) Foreign Currency AOCI Attributable to Parent, Net of Tax [Roll Forward] Balance beginning (14) Other comprehensive income before 0 reclassifications Amounts reclassified from other comprehensive 0 income Net current-period other comprehensive income 0 Balance ending (14) (14) Total AOCI Attributable to Parent, Net of Tax [Roll Forward] Balance beginning (32) (36) (44) (36) (44) Other comprehensive income before 0 reclassifications Amounts reclassified from other comprehensive 5 income Net current-period other comprehensive income 1 4 4 5 Balance ending $ (31) $ (32) $ (40) $ (31) $ (40)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Consolidating Financial Information (Condensed Consolidating Sep. 30, Jun. 30, Mar. 31, Dec. 31, Sep. 30, Jun. 30, Mar. 31, Dec. 31, Balance Sheets) (Details) - 2019 2019 2019 2018 2018 2018 2018 2017 USD ($) $ in Millions Current assets: Cash and cash equivalents $ 29 $ 201 Accounts receivable, net 323 581 Other current assets 281 174 Total current assets 633 956 Intercompany receivables 0 0 Natural gas and oil properties, using 25,060 24,180 the full cost method Other 522 525 Less: Accumulated depreciation, (20,383) (20,049) depletion and amortization Total property and equipment, net 5,199 4,656 Investments in subsidiaries (equity 0 0 method) Other long-term assets 766 185 TOTAL ASSETS 6,598 5,797 $ 7,058 Current liabilities: Current portion of long-term debt 52 0 Accounts payable 539 609 Other current liabilities 289 237 Total current liabilities 880 846 Intercompany payables 0 0 Long-term debt 2,219 2,318 Pension and other postretirement 39 46 liabilities Other long-term liabilities 325 225 Negative carrying amount of 0 0 subsidiaries, net Total long-term liabilities 2,583 2,589 Commitments and contingencies (Note 13) Total equity 3,135 $ 3,082 $ 2,937 2,362 $ 2,205 $ 2,250 $ 2,193 $ 1,979 TOTAL LIABILITIES AND 6,598 5,797 EQUITY Eliminations Current assets: Cash and cash equivalents 0 0 Accounts receivable, net 0 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Other current assets 0 0 Total current assets 0 0 Intercompany receivables (7,957) (7,932) Natural gas and oil properties, using 0 0 the full cost method Other 0 0 Less: Accumulated depreciation, 0 0 depletion and amortization Total property and equipment, net 0 0 Investments in subsidiaries (equity (23) (24) method) Other long-term assets 0 0 TOTAL ASSETS (7,980) (7,956) Current liabilities: Current portion of long-term debt 0 Accounts payable 0 0 Other current liabilities 0 0 Total current liabilities 0 0 Intercompany payables (7,957) (7,932) Long-term debt 0 0 Pension and other postretirement 0 0 liabilities Other long-term liabilities 0 0 Negative carrying amount of (2,382) (3,199) subsidiaries, net Total long-term liabilities (2,382) (3,199) Commitments and contingencies (Note 13) Total equity 2,359 3,175 TOTAL LIABILITIES AND (7,980) (7,956) EQUITY Parent Current assets: Cash and cash equivalents 29 201 Accounts receivable, net 0 4 Other current assets 6 8 Total current assets 35 213 Intercompany receivables 7,957 7,932 Natural gas and oil properties, using 0 0 the full cost method Other 179 197 Less: Accumulated depreciation, (149) (154) depletion and amortization Total property and equipment, net 30 43

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Investments in subsidiaries (equity 0 0 method) Other long-term assets 99 19 TOTAL ASSETS 8,121 8,207 Current liabilities: Current portion of long-term debt 52 Accounts payable 77 113 Other current liabilities 130 115 Total current liabilities 259 228 Intercompany payables 0 0 Long-term debt 2,219 2,318 Pension and other postretirement 39 46 liabilities Other long-term liabilities 87 54 Negative carrying amount of 2,382 3,199 subsidiaries, net Total long-term liabilities 4,727 5,617 Commitments and contingencies (Note 13) Total equity 3,135 2,362 TOTAL LIABILITIES AND 8,121 8,207 EQUITY Guarantors Current assets: Cash and cash equivalents 0 0 Accounts receivable, net 323 577 Other current assets 275 166 Total current assets 598 743 Intercompany receivables 0 0 Natural gas and oil properties, using 25,006 24,128 the full cost method Other 314 301 Less: Accumulated depreciation, (20,176) (19,840) depletion and amortization Total property and equipment, net 5,144 4,589 Investments in subsidiaries (equity 23 24 method) Other long-term assets 667 166 TOTAL ASSETS 6,432 5,522 Current liabilities: Current portion of long-term debt 0 Accounts payable 462 496 Other current liabilities 159 122 Total current liabilities 621 618 Intercompany payables 7,955 7,932

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Long-term debt 0 0 Pension and other postretirement 0 0 liabilities Other long-term liabilities 238 171 Negative carrying amount of 0 0 subsidiaries, net Total long-term liabilities 238 171 Commitments and contingencies (Note 13) Total equity (2,382) (3,199) TOTAL LIABILITIES AND 6,432 5,522 EQUITY Non-Guarantors Current assets: Cash and cash equivalents 0 0 Accounts receivable, net 0 0 Other current assets 0 0 Total current assets 0 0 Intercompany receivables 0 0 Natural gas and oil properties, using 54 52 the full cost method Other 29 27 Less: Accumulated depreciation, (58) (55) depletion and amortization Total property and equipment, net 25 24 Investments in subsidiaries (equity 0 0 method) Other long-term assets 0 0 TOTAL ASSETS 25 24 Current liabilities: Current portion of long-term debt 0 Accounts payable 0 0 Other current liabilities 0 0 Total current liabilities 0 0 Intercompany payables 2 0 Long-term debt 0 0 Pension and other postretirement 0 0 liabilities Other long-term liabilities 0 0 Negative carrying amount of 0 0 subsidiaries, net Total long-term liabilities 0 0 Commitments and contingencies (Note 13) Total equity 23 24

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document TOTAL LIABILITIES AND $ 25 $ 24 EQUITY

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk 9 Months Ended Management (Schedule of Derivative Instruments Sep. 30, 2019 Notional Amount, Weighted USD ($) Average Contract Prices and $ / bbl Fair Value) (Details) - Not $ / MMBTU Designated as Hedging MBbls Instrument Bcf MBbls in Thousands, $ in Millions, Bcf in Billions Sold Fixed Price Swaps - 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 61 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.89 Fair Value $ 28 Sold Fixed Price Swaps - 2019 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 632 Average price (in dollars per MMBtu, Bbl) | $ / bbl 60.65 Fair Value $ 4 Sold Fixed Price Swaps - 2019 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 978 Average price (in dollars per MMBtu, Bbl) | $ / bbl 30.18 Fair Value $ 11 Sold Fixed Price Swaps - 2019 | Ethane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 2,194 Average price (in dollars per MMBtu, Bbl) | $ / bbl 10.53 Fair Value $ 6 Two-way Costless-collars - 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 6 Fair Value $ 2 Two-way Costless-collars - 2019 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 382 Fair Value $ 3 Two-way Costless-collars - 2019 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 138 Fair Value $ 1 Two-way Costless-collars - 2019 Purchased Puts | Propane Derivative [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Floor price (in dollars per MMBtu, Bbl) | $ / bbl 25.62 Two-way Costless-collars - 2019 Sold Calls | Natural Gas Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.92 Two-way Costless-collars - 2019 Sold Calls | Oil Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 67.16 Two-way Costless-collars - 2019 Sold Calls | Propane Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 28.77 Three-way Costless-collars - 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 44 Fair Value $ 13 Three-way Costless-collars - 2019 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 138 Three-way Costless-collars - 2019 Sold Calls | Natural Gas Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.15 Three-way Costless-collars - 2019 Sold Calls | Oil Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 63.67 Financial protection on production - 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 111 Fair Value $ 43 Financial protection on production - 2019 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 1,152 Fair Value $ 7 Financial protection on production - 2019 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 1,116 Fair Value $ 12 Sold Fixed Price Swaps - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 151 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.58 Fair Value $ 45 Sold Fixed Price Swaps - 2020 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 1,556 Average price (in dollars per MMBtu, Bbl) | $ / bbl 60.18

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value $ 14 Sold Fixed Price Swaps - 2020 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 2,928 Average price (in dollars per MMBtu, Bbl) | $ / bbl 25.58 Fair Value $ 18 Sold Fixed Price Swaps - 2020 | Ethane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 3,843 Average price (in dollars per MMBtu, Bbl) | $ / bbl 9.80 Fair Value $ 7 Two-way Costless-collars - 2020 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 366 Fair Value $ 4 Two-way Costless-collars - 2020 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 366 Fair Value $ 2 Two-way Costless-collars - 2020 Sold Calls | Oil Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 69.80 Two-way Costless-collars - 2020 Sold Calls | Propane Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 29.40 Three-Way Costless Collars - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 209 Fair Value $ 22 Three-Way Costless Collars - 2020 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 915 Fair Value $ 3 Three-way Costless-collars - 2020 Sold Calls | Natural Gas Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.98 Three-way Costless-collars - 2020 Sold Calls | Oil Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 61.75 Financial protection on production - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 360 Fair Value $ 67 Financial protection on production - 2020 | Oil

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 2,837 Fair Value $ 21 Financial protection on production - 2020 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 3,294 Fair Value $ 20 Three-way Costless-collars - 2021 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 134 Fair Value $ (1) Three-way Costless-collars - 2021 | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 730 Fair Value $ 1 Three-Way Costless Collars - 2021 Sold Calls | Natural Gas Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.85 Three-Way Costless Collars - 2021 Sold Calls | Oil Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / bbl 59.50 Sold Fixed Price Swaps - 2021 | Propane Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 456 Average price (in dollars per MMBtu, Bbl) | $ / bbl 22.24 Fair Value $ 1 Three-Way Costless Collars-2022 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 23 Fair Value $ 0 Three-way Costless Collars 2022 - Sold Calls | Natural Gas Derivative [Line Items] Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.14 Sold Basis Swaps - 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 35 Basis differential per MMBtu | $ / MMBTU (0.40) Fair Value $ 9 Sold Basis Swaps - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 141 Basis differential per MMBtu | $ / MMBTU (0.31) Fair Value $ (13) Sold Basis Swaps - 2021 | Natural Gas

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 65 Basis differential per MMBtu | $ / MMBTU (0.48) Fair Value $ (1) Sold Basis Swaps 2022 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 45 Basis differential per MMBtu | $ / MMBTU (0.50) Fair Value $ 0 Sold Basis Swaps | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 286 Fair Value $ (5) Purchased fixed price swaps | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 69 Average price (in dollars per MMBtu, Bbl) | $ / bbl 69.10 Fair Value $ (1) Sold fixed price swaps | Oil Derivative [Line Items] Volume (Bcf, MBbls) | MBbls 701 Average price (in dollars per MMBtu, Bbl) | $ / bbl 61.48 Fair Value $ 5 Purchased Call Options 2019 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 5 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.50 Fair Value $ 0 Purchased Call Options - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 68 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.63 Fair Value $ 1 Purchased Call Options - 2021 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 57 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.52 Fair Value $ 2 Purchased call options | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 130 Fair Value $ 3 Sold Call Options - 2019 | Natural Gas Derivative [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Volume (Bcf, MBbls) | Bcf 13 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.50 Fair Value $ 0 Sold Call Options - 2020 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 137 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.39 Fair Value $ (5) Sold Call Options - 2021 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 114 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.33 Fair Value $ (6) Sold Call Options - 2023 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 6 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.00 Fair Value $ (1) Sold Call Options - 2024 | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 9 Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.00 Fair Value $ (2) Sold call options | Natural Gas Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 279 Fair Value $ (14) Purchased Fixed Price Swaps, Storage, 2019 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.90 Basis differential per MMBtu | $ / MMBTU 0 Fair Value $ 0 Purchased Basis Swaps Storage, 2019 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 0 Basis differential per MMBtu | $ / MMBTU (0.61) Fair Value $ 0 Storage 2019 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Fair Value $ 0 Purchased Fixed Price Swaps, Storage, 2020

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.37 Basis differential per MMBtu | $ / MMBTU 0 Fair Value $ 0 Purchased Basis Swaps, Storage, 2020 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 0 Basis differential per MMBtu | $ / MMBTU (0.32) Fair Value $ 0 Fixed Price Swap, Storage, 2020 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 2 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 3.06 Basis differential per MMBtu | $ / MMBTU 0 Fair Value $ 1 Sold Basis Swaps, Storage, 2020 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 0 Average price (in dollars per MMBtu, Bbl) | $ / MMBTU 0 Basis differential per MMBtu | $ / MMBTU (0.32) Fair Value $ 0 Storage 2020 Derivative [Line Items] Volume (Bcf, MBbls) | Bcf 2 Fair Value $ 1 Short Puts | Three-way Costless-collars - 2019 Sold Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.43 Short Puts | Three-way Costless-collars - 2019 Sold Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 45.00 Short Puts | Three-way Costless-collars - 2020 Sold Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.34 Short Puts | Three-way Costless-collars - 2020 Sold Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 45.00 Short Puts | Three-Way Costless Collars - 2021 Sold Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.27 Short Puts | Three-Way Costless Collars - 2021 Sold Puts | Oil Derivative [Line Items]

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Floor price (in dollars per MMBtu, Bbl) | $ / bbl 45.00 Short Puts | Three-Way Costless Collars 2022 - Sold Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.30 Purchased Puts | Two-way Costless-collars - 2019 Purchased Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.78 Purchased Puts | Two-way Costless-collars - 2019 Purchased Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 61.45 Purchased Puts | Three-way Costless-collars - 2019 Purchased Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.82 Purchased Puts | Three-way Costless-collars - 2019 Purchased Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 55.00 Purchased Puts | Two-way Costless-collars - 2020 Purchased Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 60.00 Purchased Puts | Two-way Costless-collars - 2020 Purchased Puts | Propane Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 25.20 Purchased Puts | Three-way Costless-collars - 2020 Purchased Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.67 Purchased Puts | Three-way Costless-collars - 2020 Purchased Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 55.00 Purchased Puts | Three-Way Costless Collars - 2021 Purchased Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.55 Purchased Puts | Three-Way Costless Collars - 2021 Purchased Puts | Oil Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / bbl 53.00 Purchased Puts | Three Way Costless Collars 2022 - Purchased Puts | Natural Gas Derivative [Line Items] Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU 2.70

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED BALANCE SHEETS - USD Sep. 30, Dec. 31, ($) 2019 2018 $ in Millions Current assets: Cash and cash equivalents $ 29 $ 201 Accounts receivable, net 323 581 Derivative assets 239 130 Other current assets 42 44 Total current assets 633 956 Natural gas and oil properties, using the full cost method, including, $1,518 million as of 25,060 24,180 September 30, 2019 and $1,755 million as of December 31, 2018 excluded from amortization Other 522 525 Less: Accumulated depreciation, depletion and amortization (20,383)(20,049) Total property and equipment, net 5,199 4,656 Deferred tax assets 398 0 Other long-term assets 368 185 TOTAL ASSETS 6,598 5,797 Current liabilities: Current portion of long-term debt 52 0 Accounts payable 539 609 Taxes payable 55 58 Interest payable 57 52 Derivative liabilities 85 79 Other current liabilities 92 48 Total current liabilities 880 846 Long-term debt 2,219 2,318 Pension and other postretirement liabilities 39 46 Other long-term liabilities 325 225 Total long-term liabilities 2,583 2,589 Commitments and contingencies (Note 13) Equity: Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 585,637,420 shares 6 6 as of September 30, 2019 and 585,407,107 as of December 31, 2018 Additional paid-in capital 4,723 4,715 Accumulated deficit (1,361) (2,142) Accumulated other comprehensive loss (31) (36) Common stock in treasury, 44,353,224 shares as of September 30, 2019 and 39,092,537 shares (202) (181) as of December 31, 2018 Total equity 3,135 2,362 TOTAL LIABILITIES AND EQUITY $ 6,598 $ 5,797

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Cover Page - shares Sep. 30, 2019 Oct. 22, 2019 Cover page. Document Type 10-Q Document Quarterly Report true Document Period End Date Sep. 30, 2019 Document Transition Report false Entity File Number 001-08246 Document Fiscal Year Focus 2019 Document Fiscal Period Focus Q3 Entity Registrant Name SOUTHWESTERN ENERGY CO Entity Incorporation, State or Country Code DE Entity Tax Identification Number 71-0205415 Entity Address, Address Line One 10000 Energy Drive Entity Address, City or Town Spring, Entity Address, State or Province TX Entity Address, Postal Zip Code 77389 City Area Code 832 Local Phone Number 796-1000 Entity Current Reporting Status Yes Entity Interactive Data Current Yes Entity Central Index Key 0000007332 Current Fiscal Year End Date --12-31 Entity Filer Category Large Accelerated Filer Entity Small Business false Entity Emerging Growth Company false Entity Shell Company false Title of 12(b) Security Common Stock, Par Value $0.01 Trading Symbol SWN Entity Common Stock, Shares Outstanding 541,296,926 Amendment Flag false Security Exchange Name NYSE

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Basis of Presentation Sep. 30, 2019 Organization, Consolidation and Presentation of Financial Statements [Abstract] Basis of Presentation BASIS OF PRESENTATION

Southwestern Energy Company (including its subsidiaries, collectively “Southwestern” or the “Company”) is an independent energy company engaged in natural gas, oil and natural gas liquid (“NGL”) exploration, development and production (“E&P”). The Company is also focused on creating and capturing additional value through its marketing business (“Midstream”). Southwestern conducts most of its business through subsidiaries and operates principally in two segments: E&P and Midstream. The Company’s historical financial and operating results include its Fayetteville Shale E&P and related midstream gathering businesses, which were sold in early December 2018 (the “Fayetteville Shale sale”). The sale is discussed in further detail in Note 2.

E&P. Southwestern’s primary business is the exploration for and production of natural gas, oil and NGLs, with ongoing operations focused on the development of unconventional natural gas and oil reservoirs located in Pennsylvania and West Virginia. The Company’s operations in northeast Pennsylvania, herein referred to as “Northeast Appalachia,” are primarily focused on the unconventional natural gas reservoir known as the Marcellus Shale. Operations in West Virginia and southwest Pennsylvania, herein referred to as “Southwest Appalachia,” are focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and oil reservoirs. Collectively, Southwestern refers to its properties located in Pennsylvania and West Virginia as the “Appalachian Basin.” The Company also operates drilling rigs located in Pennsylvania and West Virginia, and provides certain oilfield products and services, principally serving the Company’s E&P operations through vertical integration.

Midstream. Southwestern’s marketing activities capture opportunities that arise through the marketing and transportation of natural gas, oil and NGLs primarily produced in its E&P operations.

The accompanying consolidated financial statements were prepared using accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission. Certain information relating to the Company’s organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been appropriately condensed or omitted in this Quarterly Report. The Company believes the disclosures made are adequate to make the information presented not misleading.

The consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair statement of the financial position, results of operations and cash flows for the interim periods presented herein. It is recommended that these consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018 (“2018 Annual Report”).

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The Company’s significant accounting policies, which have been reviewed and approved by the Audit Committee of the Company’s Board of Directors, are summarized in Note 1 in the Notes to the Consolidated Financial Statements included in the Company’s 2018 Annual Report.

Certain reclassifications have been made to the prior year financial statements to conform to the 2019 presentation. The effects of the reclassifications were not material to the Company’s consolidated financial statements.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Consolidating 9 Months Ended Financial Information Sep. 30, 2019 Condensed Financial Information Disclosure [Abstract] Condensed Consolidating CONDENSED CONSOLIDATING FINANCIAL INFORMATION Financial Information In April, 2018, the Company entered into the 2018 credit facility. Pursuant to requirements under the indentures governing the Company’s senior notes, each 100% owned subsidiary that became a guarantor of the 2018 credit facility also became a guarantor of each of the Company’s senior notes (the “Guarantor Subsidiaries”). The Guarantor Subsidiaries also granted liens and security interests to support their guarantees under the 2018 credit facility but not of the senior notes. These guarantees are full and unconditional and joint and several among the Guarantor Subsidiaries. Certain of the Company’s operating units which are accounted for on a consolidated basis do not guarantee the 2018 credit facility and senior notes (“Non-Guarantor Subsidiaries”). See Note 12 – Debt for additional information on the Company’s 2018 credit facility and senior notes. At the closing of the Fayetteville Shale sale in December 2018, its subsidiaries being sold were released from these guarantees. See Note 2 for additional information on the divestiture of the Company’s Fayetteville Shale-related subsidiaries.

The following financial information reflects consolidating financial information of Southwestern Energy Company (the parent and issuer company), its Guarantor Subsidiaries on a combined basis and the Non-Guarantor Subsidiaries on a combined basis, prepared on the equity basis of accounting. The information is presented in accordance with the requirements of Rule 3-10 under the SEC’s Regulation S-X. The financial information may not necessarily be indicative of results of operations, cash flows or financial position had the Guarantor Subsidiaries operated as independent entities.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 238 $ — $ — $ 238 Oil sales — 67 — — 67 NGL sales — 52 — — 52 Marketing — 279 — — 279

— 636 — — 636 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 189 — — 189 General and administrative expenses — 42 — — 42 Restructuring charges — 4 — — 4 Depreciation, depletion and amortization — 124 1 — 125 Impairments — 2 — — 2 Taxes, other than income taxes — 15 — — 15

— 664 1 — 665

Operating Loss — (28) (1) — (29)

Interest Expense, Net 17 — — — 17 Gain on Derivatives — 100 — — 100 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (2) — — (2) Equity in Earnings of Subsidiaries 59 (1) — (58) —

Income (Loss) Before Income Taxes 49 69 (1) (58) 59 Provision for Income Taxes — 10 — — 10

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49

Net Income (Loss) $ 49 $ 59 $ (1) $ (58) $ 49 Other Comprehensive Income 1 — — — 1

Comprehensive Income (Loss) $ 50 $ 59 $ (1) $ (58) $ 50

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (Unaudited)

(in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Three months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 465 $ — $ — $ 465 Oil sales — 62 — — 62 NGL sales — 112 — — 112 Marketing — 287 — — 287 Gas gathering — 25 — — 25

— 951 — — 951 Operating Costs and Expenses: Marketing purchases — 288 — — 288 Operating expenses — 206 — — 206 General and administrative expenses — 51 — — 51 Restructuring charges — 2 — — 2 Depreciation, depletion and amortization — 151 — — 151 Impairments — 161 — — 161 Taxes, other than income taxes — 26 — — 26

— 885 — — 885

Operating Income — 66 — — 66

Interest Expense, Net 29 — — — 29 Loss on Derivatives — (65) — — (65) Other Loss, Net — (1) — — (1) Equity in Earnings of Subsidiaries — — — — —

Loss Before Income Taxes (29) — — — (29) Provision for Income Taxes — — — — —

Net Loss $ (29) $ — $ — $ — $ (29)

Net Loss $ (29) $ — $ — $ — $ (29) Other Comprehensive Income 4 — — — 4

Comprehensive Loss $ (25) $ — $ — $ — $ (25)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Operating Revenues: Gas sales $ — $ 943 $ — $ — $ 943 Oil sales — 153 — — 153 NGL sales — 191 — — 191 Marketing — 1,004 — — 1,004 Other — 2 — — 2 — 2,293 — — 2,293 Operating Costs and Expenses: Marketing purchases — 1,022 — — 1,022 Operating expenses — 523 — — 523 General and administrative expenses — 119 — — 119 Loss on sale of operating assets — 3 — — 3 Restructuring charges — 9 — — 9 Depreciation, depletion and amortization — 351 1 — 352 Impairments — 8 — — 8 Taxes, other than income taxes — 51 — — 51 — 2,086 1 — 2,087

Operating Income (Loss) — 207 (1) — 206 Interest Expense, Net 46 — — — 46 Gain on Derivatives — 220 — — 220 Gain on Early Extinguishment of Debt 7 — — — 7 Other Loss, Net — (7) — — (7) Equity in Earnings of Subsidiaries 820 (1) — (819) —

Income (Loss) Before Income Taxes 781 419 (1) (819) 380 Benefit from Income Taxes — (401) — — (401) Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781

Net Income (Loss) $ 781 $ 820 $ (1) $ (819) $ 781 Other Comprehensive Income 5 — — — 5

Comprehensive Income (Loss) $ 786 $ 820 $ (1) $ (819) $ 786

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2018 Operating Revenues: Gas sales $ — $ 1,412 $ — $ — $ 1,412 Oil sales — 141 — — 141 NGL sales — 252 — — 252 Marketing — 805 — — 805 Gas gathering — 73 — — 73 Other — 4 — — 4 — 2,687 — — 2,687 Operating Costs and Expenses: Marketing purchases — 808 — — 808 Operating expenses — 588 — — 588 General and administrative expenses — 165 — — 165 Restructuring charges — 20 — — 20 Depreciation, depletion and amortization — 426 — — 426 Impairments — 171 — — 171 Taxes, other than income taxes — 64 — — 64 — 2,242 — — 2,242

Operating Income — 445 — — 445 Interest Expense, Net 100 — — — 100 Loss on Derivatives — (108) — — (108) Loss on Early Extinguishment of Debt (8) — — — (8) Other Income, Net — 1 — — 1 Equity in Earnings of Subsidiaries 338 — — (338) —

Income (Loss) Before Income Taxes 230 338 — (338) 230 Provision for Income Taxes — — — — — Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230

Participating securities – mandatory convertible preferred stock 1 — — — 1

Net Income (Loss) Attributable to Common Stock $ 229 $ 338 $ — $ (338) $ 229

Net Income (Loss) $ 230 $ 338 $ — $ (338) $ 230 Other Comprehensive Income 4 — — — 4

Comprehensive Income (Loss) $ 234 $ 338 $ — $ (338) $ 234

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated September 30, 2019 ASSETS Cash and cash equivalents $ 29 $ — $ — $ — $ 29 Accounts receivable, net — 323 — — 323 Other current assets 6 275 — — 281 Total current assets 35 598 — — 633

Intercompany receivables 7,957 — — (7,957) —

Natural gas and oil properties, using the full cost method — 25,006 54 — 25,060 Other 179 314 29 — 522 Less: Accumulated depreciation, depletion and amortization (149) (20,176) (58) — (20,383) Total property and equipment, net 30 5,144 25 — 5,199

Investments in subsidiaries (equity method) — 23 — (23) — Other long-term assets 99 667 — — 766

TOTAL ASSETS $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

LIABILITIES AND EQUITY Current portion of long-term debt $ 52 $ — $ — $ — $ 52 Accounts payable 77 462 — — 539 Other current liabilities 130 159 — — 289 Total current liabilities 259 621 — — 880

Intercompany payables — 7,955 2 (7,957) —

Long-term debt 2,219 — — — 2,219 Pension and other postretirement liabilities 39 — — — 39 Other long-term liabilities 87 238 — — 325 Negative carrying amount of subsidiaries, net 2,382 — — (2,382) — Total long-term liabilities 4,727 238 — (2,382) 2,583 Commitments and contingencies Total equity (accumulated deficit) 3,135 (2,382) 23 2,359 3,135

TOTAL LIABILITIES AND EQUITY $ 8,121 $ 6,432 $ 25 $ (7,980) $ 6,598

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated December 31, 2018 ASSETS Cash and cash equivalents $ 201 $ — $ — $ — $ 201 Accounts receivable, net 4 577 — — 581 Other current assets 8 166 — — 174

Total current assets 213 743 — — 956

Intercompany receivables 7,932 — — (7,932) —

Natural gas and oil properties, using the full cost method — 24,128 52 — 24,180 Other 197 301 27 — 525 Less: Accumulated depreciation, depletion and amortization (154) (19,840) (55) — (20,049)

Total property and equipment, net 43 4,589 24 — 4,656

Investments in subsidiaries (equity method) — 24 — (24) — Other long-term assets 19 166 — — 185

TOTAL ASSETS $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

LIABILITIES AND EQUITY Accounts payable $ 113 $ 496 $ — $ — $ 609 Other current liabilities 115 122 — — 237

Total current liabilities 228 618 — — 846

Intercompany payables — 7,932 — (7,932) —

Long-term debt 2,318 — — — 2,318 Pension and other postretirement liabilities 46 — — — 46 Other long-term liabilities 54 171 — — 225 Negative carrying amount of subsidiaries, net 3,199 — — (3,199) —

Total long-term liabilities 5,617 171 — (3,199) 2,589 Commitments and contingencies Total equity (accumulated deficit) 2,362 (3,199) 24 3,175 2,362

TOTAL LIABILITIES AND EQUITY $ 8,207 $ 5,522 $ 24 $ (7,956) $ 5,797

CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) Parent Guarantors Non-Guarantors Eliminations Consolidated Nine months ended September 30, 2019 Net cash provided by (used in) operating activities $ 1,154 $ 404 $ — $ (819) $ 739 Investing activities: Capital investments — (875) (2) — (877) Proceeds from sale of property and equipment — 42 — — 42

Net cash used in investing activities — (833) (2) — (835) Financing activities: Intercompany activities (1,250) 429 2 819 — Payments on long-term debt (43) — — — (43) Change in bank drafts outstanding (11) — — — (11) Purchase of treasury stock (21) — — — (21) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (1,326) 429 2 819 (76)

Decrease in cash and cash equivalents (172) — — — (172) Cash and cash equivalents at beginning of year 201 — — — 201

Cash and cash equivalents at end of period $ 29 $ — $ — $ — $ 29

Nine months ended September 30, 2018 Net cash provided by (used in) operating activities $ 57 $ 1,396 $ — $ (482) $ 971 Investing activities: Capital investments (12) (996) — — (1,008) Proceeds from sale of property and equipment — 9 — 9 Other 4 — — — 4

Net cash used in investing activities (8) (987) — — (995) Financing activities: Intercompany activities (71) (411) — 482 — Payments on long-term debt (1,191) — — — (1,191) Payments on revolving credit facility (1,122) — — — (1,122) Borrowings under revolving credit facility 1,482 — — — 1,482 Change in bank drafts outstanding 10 — — — 10 Debt issuance costs (9) — — — (9) Purchase of treasury stock (25) — — — (25) Preferred stock dividend (27) — — — (27) Cash paid for tax withholding (1) — — — (1)

Net cash provided by (used in) financing activities (954) (411) — 482 (883)

Decrease in cash and cash equivalents (905) (2) — — (907) Cash and cash equivalents at beginning of year 914 2 — — 916

Cash and cash equivalents at end of period $ 9 $ — $ — $ — $ 9

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Pension Plan and Other 9 Months Ended Postretirement Benefits Sep. 30, 2019 Retirement Benefits [Abstract] Pension Plan and Other PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS Postretirement Benefits The Company maintains defined pension and other postretirement benefit plans, which cover substantially all of the Company’s employees. Net periodic pension costs include the following components for the three and nine months ended September 30, 2019 and 2018:

Consolidated Statements of For the three months ended September For the nine months ended September Operations Classification of 30, 30, (in millions) Net Periodic Benefit Cost 2019 2018 2019 2018 Service cost General and administrative expenses $ 1 $ 2 $ 5 $ 8 Interest cost Other Income (Loss), Net 2 1 4 4 Expected return on plan assets Other Income (Loss), Net (1) (2) (4) (6) Amortization of prior service cost Other Income (Loss), Net — — — — Amortization of net loss Other Income (Loss), Net — 1 1 1 Settlement loss Other Income (Loss), Net 1 — 5 —

Net periodic benefit cost $ 3 $ 2 $ 11 $ 7

The Company recognized a $5 million non-cash settlement loss related to $19 million of lump sum payments from the pension plan for the nine months ended September 30, 2019 for employees who were terminated primarily as a result of the Fayetteville Shale sale.

The Company’s other postretirement benefit plan had a net periodic benefit cost of less than $1 million for the three months ended September 30, 2019 and 2018 and a net periodic benefit cost of $1 million and $2 million for the nine months ended September 30, 2019 and 2018, respectively.

As of September 30, 2019, the Company has contributed $12 million to the pension and other postretirement benefit plans and does not expect to further contribute to its pension plan during the remainder of 2019. The Company recognized liabilities of $26 million and $13 million related to its pension and other postretirement benefits, respectively, as of September 30, 2019, compared to liabilities of $34 million and $13 million as of December 31, 2018, respectively.

The Company maintains a non-qualified deferred compensation supplemental retirement savings plan (“Non-Qualified Plan”) for certain key employees who may elect to defer and contribute a portion of their compensation, as permitted by the Non-Qualified Plan. Shares of the Company’s common stock purchased under the terms of the Non-Qualified Plan are included in treasury stock and totaled 5,115 shares and 10,653 shares at September 30, 2019 and December 31, 2018, respectively.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Fair Value Measurements Sep. 30, 2019 Fair Value Disclosures [Abstract] Fair Value Measurements FAIR VALUE MEASUREMENTS

Assets and liabilities measured at fair value on a recurring basis

The carrying amounts and estimated fair values of the Company’s financial instruments as of September 30, 2019 and December 31, 2018 were as follows:

September 30, 2019 December 31, 2018

Carrying Fair Carrying Fair (in millions) Amount Value Amount Value

Cash and cash equivalents $ 29 $ 29 $ 201 $ 201 2018 revolving credit facility due April 2023 — — — — (1) Senior notes 2,292 2,109 2,342 2,190 (2) (2) Derivative instruments, net 169 169 52 52

(1) Excludes unamortized debt issuance costs and debt discounts.

(2) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet.

The fair value hierarchy prioritizes the inputs to valuation techniques used to measure fair value. As presented in the tables below, this hierarchy consists of three broad levels:

Level 1 valuations - Consist of unadjusted quoted prices in active markets for identical assets and liabilities and have the highest priority.

Level 2 valuations - Consist of quoted market information for the calculation of fair market value.

Level 3 valuations - Consist of internal estimates and have the lowest priority.

The carrying values of cash and cash equivalents, including marketable securities, accounts receivable, other current assets, accounts payable and other current liabilities on the consolidated balance sheets approximate fair value because of their short-term nature. For debt and derivative instruments, the following methods and assumptions were used to estimate fair value:

Debt: The fair values of the Company’s senior notes were based on the market value of the Company’s publicly traded debt as determined based on the market prices of the Company’s senior notes. These instruments were previously classified as a Level 2 measurement but substantially all senior notes were updated to a Level 1 measurement in the second quarter of 2018

as the market activity of the Company’s debt has resulted in timely quoted prices. The 3.42% Senior Notes due January 2020 remain a Level 2 measurement due to relative market inactivity.

The carrying values of the borrowings under the Company’s revolving credit facility (to the extent utilized) approximates fair value because the interest rate is variable and reflective of market rates. The Company considers the fair value of its revolving credit facility to be a Level 1 measurement on the fair value hierarchy.

Derivative Instruments: The fair value of all derivative instruments is the amount at which the instrument could be exchanged currently between willing parties. The amounts are based on quoted market prices, best estimates obtained from counterparties and an option pricing model, when necessary, for price option contracts.

The Company has classified its derivatives into these levels depending upon the data utilized to determine their fair values. The Company’s fixed price swaps (Level 2) are estimated using third-party discounted cash flow calculations using the New York Mercantile Exchange (“NYMEX”) futures index for natural gas and oil derivatives and Oil Price Information Service (“OPIS”) for ethane and propane derivatives. The Company utilizes discounted cash flow models for valuing its interest rate derivatives (Level 2). The net derivative values attributable to the Company’s interest rate derivative contracts as of September 30, 2019 are based on (i) the contracted notional amounts, (ii) active market-quoted LIBOR yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve.

The Company’s call options, two-way costless collars and three-way costless collars (Level 2) are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contract terms, including maturity, and market parameters, including assumptions of the NYMEX and OPIS futures index, interest rates, volatility and credit worthiness. The Company’s basis swaps (Level 2) are estimated using third-party calculations based upon forward commodity price curves. These instruments were previously classified as a Level 3 measurement in the fair value hierarchy but were updated to a Level 2 measurement in the second quarter of 2018 as a result of the Company’s ability to derive volatility inputs and forward commodity price curves from directly observable sources.

Inputs to the Black-Scholes model, including the volatility input, are obtained from a third-party pricing source, with independent verification of the most significant inputs on a monthly basis. An increase (decrease) in volatility would result in an increase (decrease) in fair value measurement, respectively.

Assets and liabilities measured at fair value on a recurring basis are summarized below:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document September 30, 2019

Fair Value Measurements Using:

Quoted Prices in Active Significant Other Observable Significant Unobservable Assets (Liabilities) at (in millions) Markets (Level 1) Inputs (Level 2) Inputs (Level 3) Fair Value

Assets (1) Fixed price swap – natural gas $ — $ 73 $ — $ 73 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 30 — 30 Fixed price swap – ethane — 13 — 13 Two-way costless collar – natural gas — 2 — 2 Two-way costless collar – oil — 7 — 7 Two-way costless collar – propane — 3 — 3 Three-way costless collar – natural gas — 147 — 147 Three-way costless collar – oil — 13 — 13 Basis swap – natural gas — 24 — 24 Purchased call option – natural gas — 3 — 3 Storage – fixed price swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (1) — (1) Three-way costless collar – natural gas — (113) — (113) Three-way costless collar – oil — (9) — (9) Basis swap – natural gas — (29) — (29) Sold call option – natural gas — (14) — (14)

Total $ — $ 169 $ — $ 169

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document December 31, 2018

Fair Value Measurements Using:

Quoted Prices in Active Significant Other Observable Significant Unobservable Assets (Liabilities) at (in millions) Markets (Level 1) Inputs (Level 2) Inputs (Level 3) Fair Value

Assets Fixed price swap – natural gas $ — $ 38 $ — $ 38 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 11 — 11 Fixed price swap – ethane — 8 — 8 Two-way costless collar – natural gas — 11 — 11 Two-way costless collar – oil — 11 — 11 Three-way costless collar – natural gas — 75 — 75 Basis swap – natural gas — 11 — 11 Purchased call option – natural gas — 6 — 6 Interest rate swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (6) — (6) Fixed price swap – natural gas — (10) — (10) Fixed price swap – ethane — (3) — (3) Two-way costless collar – natural gas — (7) — (7) Two-way costless collar – oil — (1) — (1) Three-way costless collar – natural gas — (68) — (68) Basis swap – natural gas — (22) — (22) Sold call option – natural gas — (22) — (22)

Total $ — $ 52 $ — $ 52

The table below presents reconciliations for the change in net fair value of derivative assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the nine months ended September 30, 2019 and 2018. There were no derivatives presented as Level 3 in the third quarters of 2019 and 2018. The fair values of Level 3 derivative instruments were estimated using proprietary valuation models that utilized both market observable and unobservable parameters. Level 3 instruments presented in the table consisted of net derivatives valued using pricing models incorporating assumptions that, in the Company’s judgment, reflected reasonable assumptions a marketplace participant would have used as of September 30, 2018. Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

?

For the nine months ended September 30,

(in millions) 2019 2018

Balance at beginning of period $ — $ 22 Total gains (losses): Included in earnings — (17) (1) Settlements — 1 (2) Transfers into/out of Level 3 — (6)

Balance at end of period $ — $ —

Change in gains (losses) included in earnings relating to derivatives still held as of September 30 $ — $ —

(1) Includes $1 million amortization of premiums paid related to certain purchased natural gas call options for the nine months ended September 30, 2018.

(1) Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

Assets and liabilities measured at fair value on a nonrecurring basis

In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool included in the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, the Company determined the carrying value of certain non-full cost pool assets exceeded the fair value less costs to sell, the Company recorded an impairment charge of $161 million during

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document the third quarter of 2018, of which $145 million related to midstream gathering assets and $15 million related to E&P assets which were both reflected as assets held for sale as of September 30, 2018. Additionally, the Company recorded an $1 million impairment related to other non-core assets that were not included in the sale. The estimated fair value of the gathering assets was based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of natural gas reserves, operating costs, projections of future rates of production, inflation factors and risk adjusted discount rates.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Natural Gas and Oil 9 Months Ended Properties Sep. 30, 2019 Oil and Gas Exploration and Production Industries Disclosures [Abstract] Natural Gas and Oil Properties NATURAL GAS AND OIL PROPERTIES

The Company utilizes the full cost method of accounting for costs related to the exploration, development and acquisition of natural gas and oil properties. Under this method, all such costs (productive and nonproductive), including salaries, benefits and other internal costs directly attributable to these activities, are capitalized on a country-by-country basis and amortized over the estimated lives of the properties using the units-of-production method. These capitalized costs are subject to a ceiling test that limits such pooled costs, net of applicable deferred taxes, to the aggregate of the present value of future net revenues attributable to proved natural gas, oil and NGL reserves discounted at 10% (standardized measure). Any costs in excess of the ceiling are written off as a non-cash expense. The expense may not be reversed in future periods, even though higher natural gas, oil and NGL prices may subsequently increase the ceiling. Companies using the full cost method are required to use the average quoted price from the first day of each month from the previous 12 months, including the impact of derivatives designated for hedge accounting, to calculate the ceiling value of their reserves.

Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $2.87 per MMBtu, West Texas Intermediate oil of $57.77 per Bbl and NGLs of $12.59 per Bbl, adjusted for differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount at September 30, 2019. The Company had no derivative positions that were designated for hedge accounting as of September 30, 2019. Decreases in market prices as well as changes in production rates, levels of reserves, evaluation of costs excluded from amortization, future development costs and production costs could result in future ceiling test impairments. Should market prices continue below the average of the previous 12-months, as was the case in the third quarter of 2019, such impairments may occur in upcoming quarters.

Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $2.91 per MMBtu, West Texas Intermediate oil of $63.43 per Bbl and NGLs of $17.47 per Bbl, adjusted for differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount at September 30, 2018. The Company had no derivative positions that were designated for hedge accounting as of September 30, 2018.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Restructuring Charges Sep. 30, 2019 Restructuring and Related Activities [Abstract] Restructuring Charges RESTRUCTURING CHARGES In June 2018, the Company notified affected employees of a workforce reduction plan, which resulted primarily from a previously announced study of structural, process and organizational changes to enhance shareholder value and continues with respect to other aspects of the Company’s business activities. Affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited.

In December 2018, the Company closed on the sale of the equity in certain of its subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets in Arkansas. As part of the transaction, most employees associated with those assets became employees of the buyer although the employment of some was terminated. All affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited. As of September 30, 2019, the Company has substantially completed the Fayetteville Shale sale-related employment terminations.

In July 2019, the Company terminated its existing lease agreement on its headquarters office building and entered into a new 10-year lease agreement for a smaller portion of the building. Approximately $3 million of the fees associated with the Company’s office consolidation are reflected as restructuring charges for the three months ended September 30, 2019. The Company also recognized additional severance costs in the third quarter of 2019, related to continued organizational restructuring, for which a liability of $1 million has been accrued as of September 30, 2019.

The following table presents a summary of the restructuring charges included in Operating Income (Loss) for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September 30, For the nine months ended September 30,

(in millions) 2019 2018 2019 2018

Severance (including payroll taxes) $ 1 $ 1 $ 4 $ 18 Office consolidation 3 — 5 — Professional fees — 1 — 2 (1) Total restructuring charges $ 4 $ 2 $ 9 $ 20

(1) Total restructuring charges were $4 million and $9 million for the Company’s E&P segment for the three and nine months ended September 30, 2019, respectively. Total restructuring charges were $2 million for the Company’s E&P segment for the three months ended September 30, 2018, and $18 million and $2 million for the Company’s E&P and Midstream segments, respectively, for the nine months ended September 30, 2018.

The following table presents a reconciliation of the liability associated with the Company’s restructuring activities at September 30, 2019, which is reflected in accounts payable on the consolidated balance sheet:

(in millions) Liability at December 31, 2018 $ 5 Additions 9 Distributions (13)

Liability at September 30, 2019 $ 1

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Cash and Cash Equivalents 9 Months Ended (Tables) Sep. 30, 2019 Cash and Cash Equivalents [Abstract] Summary of Cash and Cash Equivalents The following table presents a summary of cash and cash equivalents as of September 30, 2019 and December 31, 2018:

(in millions) September 30, 2019 December 31, 2018

Cash $ 9 $ 32 (1) Marketable securities 20 169

Total $ 29 $ 201

(1) Consists of government stable value money market funds.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value Measurements 9 Months Ended (Tables) Sep. 30, 2019 Fair Value Disclosures [Abstract] Carrying Amount and Estimated Fair Values of The carrying amounts and estimated fair values of the Company’s financial instruments as of September 30, 2019 and December 31, 2018 were as follows: Financial Instruments September 30, 2019 December 31, 2018

Carrying Fair Carrying Fair (in millions) Amount Value Amount Value

Cash and cash equivalents $ 29 $ 29 $ 201 $ 201 2018 revolving credit facility due April 2023 — — — — (1) Senior notes 2,292 2,109 2,342 2,190 (2) (2) Derivative instruments, net 169 169 52 52

(1) Excludes unamortized debt issuance costs and debt discounts.

(2) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet. Summary of Assets and Liabilities Measured at Fair Assets and liabilities measured at fair value on a recurring basis are summarized below: Value on Recurring Basis September 30, 2019

Fair Value Measurements Using:

Quoted Prices in Active Significant Other Observable Significant Unobservable Assets (Liabilities) at (in millions) Markets (Level 1) Inputs (Level 2) Inputs (Level 3) Fair Value

Assets (1) Fixed price swap – natural gas $ — $ 73 $ — $ 73 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 30 — 30 Fixed price swap – ethane — 13 — 13 Two-way costless collar – natural gas — 2 — 2 Two-way costless collar – oil — 7 — 7 Two-way costless collar – propane — 3 — 3 Three-way costless collar – natural gas — 147 — 147 Three-way costless collar – oil — 13 — 13 Basis swap – natural gas — 24 — 24 Purchased call option – natural gas — 3 — 3 Storage – fixed price swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (1) — (1) Three-way costless collar – natural gas — (113) — (113) Three-way costless collar – oil — (9) — (9) Basis swap – natural gas — (29) — (29) Sold call option – natural gas — (14) — (14)

Total $ — $ 169 $ — $ 169

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document December 31, 2018

Fair Value Measurements Using:

Quoted Prices in Active Significant Other Observable Significant Unobservable Assets (Liabilities) at (in millions) Markets (Level 1) Inputs (Level 2) Inputs (Level 3) Fair Value

Assets Fixed price swap – natural gas $ — $ 38 $ — $ 38 Fixed price swap – oil — 19 — 19 Fixed price swap – propane — 11 — 11 Fixed price swap – ethane — 8 — 8 Two-way costless collar – natural gas — 11 — 11 Two-way costless collar – oil — 11 — 11 Three-way costless collar – natural gas — 75 — 75 Basis swap – natural gas — 11 — 11 Purchased call option – natural gas — 6 — 6 Interest rate swap — 1 — 1 Liabilities Purchased fixed price swap – oil — (6) — (6) Fixed price swap – natural gas — (10) — (10) Fixed price swap – ethane — (3) — (3) Two-way costless collar – natural gas — (7) — (7) Two-way costless collar – oil — (1) — (1) Three-way costless collar – natural gas — (68) — (68) Basis swap – natural gas — (22) — (22) Sold call option – natural gas — (22) — (22)

Total $ — $ 52 $ — $ 52 Reconciliations for Change in Net Fair Value of Derivative The table below presents reconciliations for the change in net fair value of derivative assets and liabilities measured at fair value on a recurring basis using significant Assets and Liabilities unobservable inputs (Level 3) for the nine months ended September 30, 2019 and 2018. There were no derivatives presented as Level 3 in the third quarters of 2019 and 2018. Measured at Fair Value on a The fair values of Level 3 derivative instruments were estimated using proprietary valuation models that utilized both market observable and unobservable parameters. Level Recurring Basis Using 3 instruments presented in the table consisted of net derivatives valued using pricing models incorporating assumptions that, in the Company’s judgment, reflected reasonable Significant Unobservable assumptions a marketplace participant would have used as of September 30, 2018. Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the Inputs (Level 3) second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

?

For the nine months ended September 30,

(in millions) 2019 2018

Balance at beginning of period $ — $ 22 Total gains (losses): Included in earnings — (17) (1) Settlements — 1 (2) Transfers into/out of Level 3 — (6)

Balance at end of period $ — $ —

Change in gains (losses) included in earnings relating to derivatives still held as of September 30 $ — $ —

(1) Includes $1 million amortization of premiums paid related to certain purchased natural gas call options for the nine months ended September 30, 2018.

(1) Commodity derivatives previously presented as Level 3 were transferred to Level 2 in the second quarter of 2018 as the Company moved from using proprietary volatility inputs and forward curves to more widely available published information, increasing market observability.

Assets and liabilities measured at fair value on a nonrecurring basis

In accordance with accounting guidance for Property, Plant and Equipment, assets held for sale are measured at the lower of the carrying value or fair value less costs to sell. Because the assets outside of the full cost pool included in the Fayetteville Shale sale met the criteria for held for sale accounting as of September 30, 2018, the Company determined the carrying value of certain non-full cost pool assets exceeded the fair value less costs to sell, the Company recorded an impairment charge of $161 million during

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document the third quarter of 2018, of which $145 million related to midstream gathering assets and $15 million related to E&P assets which were both reflected as assets held for sale as of September 30, 2018. Additionally, the Company recorded an $1 million impairment related to other non-core assets that were not included in the sale. The estimated fair value of the gathering assets was based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of natural gas reserves, operating costs, projections of future rates of production, inflation factors and risk adjusted discount rates.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Natural Gas and Oil Sep. 30, 2019 Sep. 30, 2018 Properties (Narrative) derivative_position derivative_position (Details) $ / bbl $ / bbl $ / MMBTU $ / MMBTU Natural Gas and Oil Properties [Line Items] Natural gas, oil and NGL reserves discount 10.00% Period of time needed to calculate ceiling value of reserves 12 months Number of hedge positions designated for hedge accounting | 0 0 derivative_position Natural Gas | Henry Hub Natural Gas and Oil Properties [Line Items] Full cost ceiling test, price per MMBtu (in dollars per MMBtu) | $ / 2.87 2.91 MMBTU Oil | West Texas Intermediate Natural Gas and Oil Properties [Line Items] Full cost ceiling test, price per barrel (in dollars per bbl) 57.77 63.43 NGL | West Texas Intermediate Natural Gas and Oil Properties [Line Items] Full cost ceiling test, price per barrel (in dollars per bbl) 12.59 17.47

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Revenue Recognition 3 Months Ended 9 Months Ended (Disaggregation of Revenue by Segment) (Details) - USD Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 ($) $ in Millions Disaggregation of Revenue [Line Items] Total operating revenues $ 636 $ 951 $ 2,293 $ 2,687 E&P Disaggregation of Revenue [Line Items] Total operating revenues 357 639 1,288 1,809 Midstream Disaggregation of Revenue [Line Items] Total operating revenues 279 312 1,005 878 Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 348 633 1,261 1,790 Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 592 912 2,159 2,605 Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues 304 594 1,127 1,708 Intersegment Revenues | E&P Disaggregation of Revenue [Line Items] Total operating revenues (9) (6) (27) (19) Intersegment Revenues | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 313 600 1,154 1,727 Gas sales Disaggregation of Revenue [Line Items] Total operating revenues 238 465 943 1,412 Gas sales | Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 230 460 918 1,395 Gas sales | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 0 0 0 0 Gas sales | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues (8) (5) (25) (17) Oil sales Disaggregation of Revenue [Line Items] Total operating revenues 67 62 153 141 Oil sales | Operating Segments | E&P

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Disaggregation of Revenue [Line Items] Total operating revenues 66 61 151 139 Oil sales | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 0 0 0 0 Oil sales | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues (1) (1) (2) (2) NGL sales Disaggregation of Revenue [Line Items] Total operating revenues 52 112 191 252 NGL sales | Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 52 112 191 252 NGL sales | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 0 0 0 0 NGL sales | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues 0 0 0 0 Marketing Disaggregation of Revenue [Line Items] Total operating revenues 279 287 1,004 805 Marketing | Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 0 0 0 0 Marketing | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 592 846 2,158 2,403 Marketing | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues 313 559 1,154 1,598 Marketing | Intersegment Revenues | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 313 559 1,154 1,598 Gas gathering Disaggregation of Revenue [Line Items] Total operating revenues 0 25 0 73 Gas gathering | Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 0 0 Gas gathering | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 66 202

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Gas gathering | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues 41 129 Other Disaggregation of Revenue [Line Items] Total operating revenues $ 0 $ 0 2 4 Other | Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 1 4 Other | Operating Segments | Midstream Disaggregation of Revenue [Line Items] Total operating revenues 1 0 Other | Intersegment Revenues Disaggregation of Revenue [Line Items] Total operating revenues $ 0 $ 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value Measurements 9 Months Ended (Reconciliations for Change in Net Fair Value of Derivative Assets and Liabilities Measured at Fair Sep. 30, Sep. 30, Value on a Recurring Basis 2019 2018 Using Significant Unobservable Inputs (Level 3)) (Details) - USD ($) $ in Millions Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] Balance at beginning of period $ 0 $ 22 Included in earnings 0 (17) Settlements 0 1 Transfers into/out of Level 3 0 (6) Balance at end of period 0 0 Change in gains (losses) included in earnings relating to derivatives still held as of June 30 $ 0 0 Natural Gas | Call Option Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] Amortization of premium paid $ 1

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 3 Months Ended 9 Months Ended (Narrative) (Details) - USD Mar. 31, Mar. 31, Sep. 30, ($) Sep. 30, 2019 2019 2018 2018 $ in Millions Share-based Compensation [Line Items] Service period 3 years Stock options Share-based Compensation [Line Items] Vesting period 3 years Expiration period 7 years Equity-classified awards, unrecognized compensation cost $ 9 Weighted average period over which unrecognized cost is 1 year 1 month 6 recognized, years days Restricted stock Share-based Compensation [Line Items] Vesting period 4 years RSUs Share-based Compensation [Line Items] Vesting period 4 years 4 years Weighted average period over which unrecognized cost is 3 years recognized, years Liability classified awards, unrecognized compensation $ 22 costs Performance units Share-based Compensation [Line Items] Vesting period 3 years 3 years Weighted average period over which unrecognized cost is 2 years 2 months recognized, years 12 days Liability classified awards, unrecognized compensation $ 7 costs

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Summary of Equity- Classified Performance Units Activity) (Details) - Sep. 30, 2019Sep. 30, 2018 Performance units - $ / shares Number of Shares Beginning balance (in shares) 598,000 Granted (in shares) 0 Vested (in shares) (371,000) Forfeited (in shares) (30,000) Ending balance (in shares) 197,000 Weighted Average Fair Value Beginning balance (in dollars per share) $ 10.01 Granted (in dollars per share) 0 Vested (in dollars per share) 9.73 Forfeited (in dollars per share) 10.47 Ending balance (in dollars per share) $ 10.47 Vesting period 3 years 3 years Minimum Number of Shares Granted (in shares) 0 Maximum Number of Shares Granted (in shares) 2

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Commitments and Contingencies (Narrative) Sep. 30, Jul. 31, Mar. 31, Dec. 31, (Details) - USD ($) 2019 2019 2019 2018 $ in Millions Commitments And Contingencies [Line Items] Obligation under transportation agreements $ 8,194 Guarantee obligations relative to the firms transportation agreements 323 and gathering project and services Contractual commitments assumed by buyer 135 Potential amount to be reimbursed to buyer 70 Liability for estimated future payments 57 $ 88 Operating lease commitment 190 $ 95 Term of contract 10 years Liability Associated With Indemnification Obligation 0 Pending regulatory approval and/or construction Commitments And Contingencies [Line Items] Obligation under transportation agreements 752 Appalachian Basin Commitments And Contingencies [Line Items] Obligation under transportation agreements $ 357 Reimbursed by seller $ 133 Office Building Commitments And Contingencies [Line Items] Operating lease commitment $ 87 Term of contract 10 years

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Pension Plan and Other 12 1 Months 6 Months 9 Months Postretirement Benefits 3 Months Ended Months Ended Ended Ended (Narrative) (Details) - USD Ended ($) Dec. 31, Sep. 30, Mar. 31, Sep. 30, Dec. 31, Sep. 30, Sep. 30, Dec. 31, $ in Millions 2018 2019 2019 2018 2018 2019 2018 2018 Defined Benefit Plan Disclosure [Line Items] Employer contributions $ 12 Treasury stock acquired (in 44,000,000 5,260,687 39,061,269 shares) Pension Defined Benefit Plan Disclosure [Line Items] Settlement loss $ 1 $ 0 5 $ 0 Lump sum payments for 19 settlement Net periodic benefit cost (gain) 3 2 11 7 Benefit obligation $ 34 26 $ 34 26 $ 34 Other Postretirement Benefits Defined Benefit Plan Disclosure [Line Items] Net periodic benefit cost (gain) 1 $ 1 1 $ 2 Benefit obligation $ 13 $ 13 $ 13 $ 13 $ 13 Non-Qualified Supplemental Employee Retirement Plan Defined Benefit Plan Disclosure [Line Items] Treasury stock acquired (in 5,115 10,653 shares)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Segment Information 3 Months Ended 9 Months Ended (Details) - USD ($) Sep. 30, Sep. 30, Sep. 30, Sep. 30, Dec. 31, $ in Millions 2019 2018 2019 2018 2018 Segment Reporting Information [Line Items] Total operating revenues $ 636 $ 951 $ 2,293 $ 2,687 Depreciation, depletion and amortization 125 151 352 426 expense Impairments 2 161 8 171 Operating Income (Loss) (29) 66 206 445 Interest expense 17 29 46 100 Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on early extinguishment of debt 7 0 7 (8) Other (loss) income, Net (2) (1) (7) 1 Provision (benefit) for income taxes 10 0 (401) 0 Assets 6,598 7,058 6,598 7,058 $ 5,797 Capital investments 240 298 933 1,039 Restructuring charges 4 2 9 20 Cash and cash equivalents 29 29 201 Property, plant and equipment 5,199 5,199 4,656 Unamortized debt expense 20 20 $ 23 Right-of-use asset 164 164 Change in accrued expenditures (53) (31) 52 21 Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues 304 594 1,127 1,708 E&P Segment Reporting Information [Line Items] Total operating revenues 357 639 1,288 1,809 Depreciation, depletion and amortization 123 140 345 383 expense Impairments 0 15 6 15 Operating Income (Loss) (21) 175 219 510 Interest expense 17 29 46 100 Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on early extinguishment of debt 0 0 0 Other (loss) income, Net (4) 0 (8) 3 Provision (benefit) for income taxes 10 (401) Assets 6,099 5,732 6,099 5,732 Capital investments 239 295 931 1,025 Restructuring charges 4 2 9 18 Assets held for sale 106 106

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document E&P | Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues (9) (6) (27) (19) Midstream Segment Reporting Information [Line Items] Total operating revenues 279 312 1,005 878 Depreciation, depletion and amortization 2 11 7 43 expense Impairments 2 145 2 155 Operating Income (Loss) (8) (108) (13) (64) Interest expense 0 0 0 0 Gain (Loss) on Derivatives 0 0 0 0 Gain (Loss) on early extinguishment of debt 0 0 0 Other (loss) income, Net 0 (1) 0 (2) Provision (benefit) for income taxes 0 0 Assets 272 1,115 272 1,115 Capital investments 0 0 0 9 Restructuring charges 2 Assets held for sale 738 738 Midstream | Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues 313 600 1,154 1,727 Other Segment Reporting Information [Line Items] Total operating revenues 0 0 0 0 Depreciation, depletion and amortization 0 0 0 0 expense Impairments 0 1 0 1 Operating Income (Loss) 0 (1) 0 (1) Interest expense 0 0 0 0 Gain (Loss) on Derivatives 0 0 0 0 Gain (Loss) on early extinguishment of debt 7 7 (8) Other (loss) income, Net 2 0 1 0 Provision (benefit) for income taxes 0 0 Assets 227 211 227 211 Capital investments 1 3 2 5 Cash and cash equivalents 29 9 29 9 Income tax receivable 61 89 61 89 Property, plant and equipment 31 69 31 69 Unamortized debt expense 12 12 12 12 Prepayments 7 12 7 12

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Non-qualified retirement plan 7 8 7 8 Right-of-use asset 84 84 Other | Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues 0 0 0 0 Marketing Segment Reporting Information [Line Items] Total operating revenues 279 287 1,004 805 Marketing | Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues 313 559 1,154 1,598 Marketing | Midstream | Intersegment Revenues Segment Reporting Information [Line Items] Total operating revenues $ 313 $ 559 $ 1,154 1,598 Non-Core Gathering Assets | Midstream Segment Reporting Information [Line Items] Impairments $ 10

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Fair Value Measurements 9 Months (Carrying Amount and Ended Estimated Fair Values of Financial Instruments) Dec. 31, Sep. 30, 2019 (Details) - USD ($) 2018 $ in Millions Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Derivative instruments, net $ 169 $ 52 Carrying Amount Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Cash and cash equivalents 29 201 Derivative instruments, net 169 52 Carrying Amount | Senior Notes Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Senior notes 2,292 2,342 Fair Value Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Cash and cash equivalents 29 201 Derivative instruments, net 169 52 Fair Value | Senior Notes Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Senior notes 2,109 2,190 2018 revolving credit facility due April 2023 | Carrying Amount | Long-term debt Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Credit facility 0 0 2018 revolving credit facility due April 2023 | Fair Value | Long-term debt Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Credit facility 0 $ 0 Fixed price swaps | Natural Gas Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] Premium paid $ 9

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk 9 Months Management (Balance Sheet Ended Classification of Derivative Financial Instruments) Dec. 31, Sep. 30, 2019 (Details) - USD ($) 2018 $ in Millions Not Designated as Hedging Instrument Derivatives, Fair Value [Line Items] Derivative assets $ 335 $ 191 Derivative liabilities 166 139 Not Designated as Hedging Instrument | Storage - fixed price swap | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 1 0 Not Designated as Hedging Instrument | Interest rate swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 0 1 Natural Gas | Fixed price swaps Derivatives, Fair Value [Line Items] Premium paid 9 Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps Derivatives, Fair Value [Line Items] Premium paid 9 Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 68 32 Premium paid 9 Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Other long- term assets Derivatives, Fair Value [Line Items] Derivative assets 5 6 Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 0 9 Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Other long- term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 0 1 Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 2 11

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 0 7 Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 84 41 Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 63 34 Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 53 33 Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Other long-term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 60 35 Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 17 8 Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 7 3 Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 24 18 Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Other long-term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 5 4 Natural Gas | Not Designated as Hedging Instrument | Sold call options | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 4 3 Natural Gas | Not Designated as Hedging Instrument | Sold call options | Other long- term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 10 19 Natural Gas | Not Designated as Hedging Instrument | Purchased call options | Derivative assets

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives, Fair Value [Line Items] Derivative assets 1 0 Natural Gas | Not Designated as Hedging Instrument | Purchased call options | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 2 6 Oil | Not Designated as Hedging Instrument | Purchased fixed price swaps | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 1 6 Oil | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 15 13 Oil | Not Designated as Hedging Instrument | Fixed price swaps | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 4 6 Oil | Not Designated as Hedging Instrument | Two-way costless collars | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 6 6 Oil | Not Designated as Hedging Instrument | Two-way costless collars | Other long- term assets Derivatives, Fair Value [Line Items] Derivative assets 1 5 Oil | Not Designated as Hedging Instrument | Two-way costless collars | Other long- term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 0 1 Oil | Not Designated as Hedging Instrument | Three-way costless collars | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 5 0 Oil | Not Designated as Hedging Instrument | Three-way costless collars | Other long- term assets Derivatives, Fair Value [Line Items] Derivative assets 8 0 Oil | Not Designated as Hedging Instrument | Three-way costless collars | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 3 0 Oil | Not Designated as Hedging Instrument | Three-way costless collars | Other long- term liabilities Derivatives, Fair Value [Line Items] Derivative liabilities 6 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Propane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 25 11 Propane | Not Designated as Hedging Instrument | Fixed price swaps | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 5 0 Propane | Not Designated as Hedging Instrument | Two-way costless collars | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 3 0 Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets Derivatives, Fair Value [Line Items] Derivative assets 12 7 Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Other long-term assets Derivatives, Fair Value [Line Items] Derivative assets 1 1 Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities Derivatives, Fair Value [Line Items] Derivative liabilities $ 0 $ 3

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Leases (Components of 9 Months Ended Lease Costs) (Details) Sep. 30, 2019 $ in Millions USD ($) Leases [Abstract] Operating lease cost $ 33 Short-term lease cost 49 Variable lease cost 1 Total lease cost $ 83

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Tables) Sep. 30, 2019 Share-based Compensation [Abstract] Schedule of Stock-Based Compensation Costs The Company recognized the following amounts in total employee stock-based compensation costs for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Stock-based compensation cost – expensed $ 1 $ 7 $ 12 $ 20 Stock-based compensation cost – capitalized 1 3 7 10

Schedule of Equity-Classified Stock-Based Compensation The Company recognized the following amounts in employee equity-classified stock-based compensation costs for the three and nine months ended September 30, 2019 Costs and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Equity-classified awards – expensed $ 2 $ 3 $ 6 $ 12 Equity-classified awards – capitalized 1 2 3 6

Summary of Equity-Classified Stock Option Activity The following table summarizes equity-classified stock option activity for the nine months ended September 30, 2019 and provides information for options outstanding and options exercisable as of September 30, 2019:

Number Weighted Average of Options Exercise Price

(in thousands) Outstanding at December 31, 2018 5,178 $ 17.06 Granted — $ — Exercised — $ — Forfeited or expired (76) $ 19.38

Outstanding at September 30, 2019 5,102 $ 17.02

Exercisable at September 30, 2019 4,680 $ 17.85

Summary of Equity-Classified Restricted Stock Activity The following table summarizes equity-classified restricted stock activity for the nine months ended September 30, 2019 and provides information for unvested shares as of September 30, 2019:

Number Weighted Average of Shares Fair Value

(in thousands) Unvested shares at December 31, 2018 2,717 $ 7.91 Granted 477 $ 3.09 Vested (1,101) $ 7.02 Forfeited (210) $ 8.38

Unvested shares at September 30, 2019 1,883 $ 7.17

Summary of Equity-Classified Performance Units Activity The following table summarizes equity-classified performance unit activity for the nine months ended September 30, 2019 and provides information for unvested units as of September 30, 2019. The performance unit awards granted in 2017 include a market condition based exclusively on the fair value of the Total Shareholder Return (“TSR”), as calculated by a Monte Carlo model. The total fair value of the performance units is amortized to compensation expense on a straight line basis over the vesting period of the award. The grant date fair value is calculated using the closing price of the Company’s common stock at the grant date.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Number Weighted Average (1) of Shares Fair Value

(in thousands) Unvested units at December 31, 2018 598 $ 10.01 Granted — $ — Vested (371) $ 9.73 Forfeited (30) $ 10.47

Unvested units at September 30, 2019 197 $ 10.47

(1) The actual payout of shares may range from a minimum of zero shares to a maximum of two shares per unit contingent upon TSR. The performance units have a three-year vesting term and the actual disbursement of shares, if any, is determined during the first quarter following the end of the three-year vesting period. Schedule of Liability- Classified Stock-Based The Company recognized the following amounts in employee liability-classified stock-based compensation costs for the three and nine months ended September 30, Compensation Costs 2019:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Liability-classified stock-based compensation cost – expensed $ (1) $ 4 $ 6 $ 8 Liability-classified stock-based compensation cost – capitalized — 1 4 4

Summary of Liability- As of September 30, 2019, there was $22 million of total unrecognized compensation cost related to liability-classified restricted stock units Classified Restricted Stock that is expected to be recognized over a weighted-average period of 3.0 years. The amount of unrecognized compensation cost for liability- Unit Activity classified awards will fluctuate over time as they are marked to market.

Number Weighted Average of Units Fair Value

(in thousands) Unvested shares at December 31, 2018 8,202 $ 3.41 Granted 8,659 $ 4.34 Vested (2,624) $ 4.09 Forfeited (1,000) $ 2.51

Unvested units at September 30, 2019 13,237 $ 1.93 Summary of Liability- Classified Performance Unit Number Weighted Average Activity of Shares Fair Value (in thousands) Unvested shares at December 31, 2018 2,803 $ 3.41 Granted 2,757 $ 4.34 Vested — $ — Forfeited (119) $ 4.65

Unvested units at September 30, 2019 5,441 $ 1.93

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 1 Months 6 Months 9 Months 3 Months Ended Divestitures (Details) - USD Ended Ended Ended ($) Dec. Jul. Sep. Sep. Sep. Sep. Jun. Aug. 30, Dec. 31, Mar. 31, Dec. 31, $ in Millions 03, 31, 30, 30, 30, 30, 30, 2018 2018 2019 2018 2018 2019 2019 2018 2019 2018 2019 Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Contractual commitments $ $ assumed by buyer 135 135 Potential amount to be 70 70 reimbursed to buyer Liability for estimated future $ 88 57 $ 88 57 payments Impairments $ 2 8 $ 171 161 Repayments of long-term debt 43 1,191 Treasury stock acquired 201 $ 21 25 $ 180 Commissions $ 1 Treasury stock acquired (in 44,000,000 5,260,687 39,061,269 shares) Non-Core Assets Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Impairments 1 1 Midstream Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Impairments 2 145 2 155 E&P Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Discontinued Operations [Line Items] Impairments 0 15 $ 6 15 Fayetteville Shale Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Ownership interest prior to 100.00% disposal Consideration $ 1,865 Proceeds from disposal $ 1,650 Adjustment due to differences from economic effective date to $ 215 close date Impairments 161 161 Fayetteville Shale | Midstream Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Impairments 145 145 Fayetteville Shale | E&P Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Impairments $ 15 $ 15 Non-core leasehold Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Consideration $ 25 Land Income Statement, Balance Sheet and Additional Disclosures by Disposal

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Groups, Including Discontinued Operations [Line Items] Consideration $ 16 Gain on disposal $ 2 Senior Notes Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] Repayment of debt $ 914 Repayments of long-term debt 900 $ 43 Cash paid for interest $ 9

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Segment Information Sep. 30, 2019 Segment Reporting [Abstract] Segment Information SEGMENT INFORMATION

The Company’s reportable business segments have been identified based on the differences in products or services provided. Revenues for the E&P segment are derived from the production and sale of natural gas and liquids. The Midstream segment generates revenue through the marketing of both Company and third-party produced natural gas and liquids volumes.

Prior to December 2018, the Midstream segment included the Company’s natural gas gathering business associated with its Fayetteville Shale assets. With the closing of the Fayetteville Shale sale in December 2018, the Company’s marketing business comprises substantially all of the Company’s Midstream segment.

Summarized financial information for the Company’s reportable segments is shown in the following table. The accounting policies of the segments are the same as those described in Note 1 of the Notes to Consolidated Financial Statements included in Item 8 of the 2018 Annual Report. Management evaluates the performance of its segments based on operating income, defined as operating revenues less operating costs. Income before income taxes, for the purpose of reconciling the operating income amount shown below to consolidated income before income taxes, is the sum of operating income, interest expense, gain (loss) on derivatives and other income (loss). The “Other” column includes items not related to the Company’s reportable segments, including real estate and corporate items.

E&P Midstream Other Total

Three months ended September 30, 2019 (in millions) Revenues from external customers $ 357 $ 279 $ — $ 636 Intersegment revenues (9) 313 — 304 Depreciation, depletion and amortization expense 123 2 — 125 Impairments — 2 — 2 (1) Operating loss (21) (8) — (29) (2) Interest expense 17 — — 17 Gain on derivatives 100 — — 100 Gain on extinguishment of debt — — 7 7 Other income (loss), net (4) — 2 (2) (2) Provision for income taxes 10 — — 10 (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 239 — 1 240

Three months ended September 30, 2018 Revenues from external customers $ 639 $ 312 $ — $ 951 Intersegment revenues (6) 600 — 594 Depreciation, depletion and amortization expense 140 11 — 151 Impairments 15 145 1 161 (6) (1) Operating income (loss) 175 (108) (1) 66 (2) Interest expense 29 — — 29 Loss on derivatives (65) — — (65) Other loss, net — (1) — (1) (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 295 — 3 298

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document E&P Midstream Other Total

Nine months ended September 30, 2019 (in millions) Revenues from external customers $ 1,288 $ 1,005 $ — $ 2,293 Intersegment revenues (27) 1,154 — 1,127 Depreciation, depletion and amortization expense 345 7 — 352 Impairments 6 2 — 8 (1) Operating income (loss) 219 (13) — 206 (2) Interest expense 46 — — 46 Gain on derivatives 220 — — 220 Gain on early extinguishment of debt — — 7 7 Other income (loss), net (8) — 1 (7) (2) Benefit from income taxes (401) — — (401) (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 931 — 2 933

Nine months ended September 30, 2018 Revenues from external customers $ 1,809 $ 878 $ — $ 2,687 Intersegment revenues (19) 1,727 — 1,708 Depreciation, depletion and amortization expense 383 43 — 426 (8) Impairments 15 155 1 171 (6) (1) (9) Operating income (loss) 510 (64) (1) 445 (2) Interest expense 100 — — 100 Loss on derivatives (108) — — (108) Loss on early extinguishment of debt — — (8) (8) Other income (loss), net 3 (2) — 1 (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 1,025 9 5 1,039

(1) Operating income for the E&P segment includes $4 million and $2 million of restructuring charges for the three months ended September 30, 2019 and 2018, respectively, and $9 million and $18 million of restructuring charges for the nine months ended September 30, 2019 and 2018, respectively.

(2) Interest expense and provision (benefit) for income taxes by segment is an allocation of corporate amounts as they are incurred at the corporate level.

(3) E&P assets includes office, technology, water infrastructure, drilling rigs and other ancillary equipment not directly related to natural gas and oil properties. This also includes deferred tax assets which are an allocation of corporate amounts as they are incurred at the corporate level. At September 30, 2018, E&P assets included $106 million of assets held for sale.

(4) Other assets represent corporate assets not allocated to segments and assets for non-reportable segments. At September 30, 2019 and 2018, other assets included approximately $29 million and $9 million, respectively, in cash and cash equivalents, $61 million and $89 million, respectively, in income taxes receivable, $31 million and $69 million, respectively, in property, plant and equipment, $9 million and $12 million, respectively, in unamortized debt expense, $7 million and $12 million, respectively, in prepayments and $7 million and $8 million, respectively, in a non-qualified retirement plan. Additionally, the September 30, 2019 asset balance includes $84 million in right-of-use lease assets.

(5) Capital investments include decreases of $53 million and $31 million for the three months ended September 30, 2019 and 2018, respectively, and increases of $52 million and $21 million for the nine months ended September 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between years.

(6) Includes the impact of Fayetteville Shale-related E&P and Midstream operations which were divested on December 3, 2018.

(7) Midstream assets includes $738 million of assets held for sale at September 30, 2018.

(8) Includes a $10 million impairment related to certain non-core gathering assets.

(9) Operating loss for the Midstream segment includes a $10 million impairment related to certain non-core gathering assets and $2 million related to restructuring charges for the nine months ended September 30, 2018.

Included in intersegment revenues of the Midstream segment are $313 million and $559 million for the three months ended September 30, 2019 and 2018, respectively, and $1,154 million and $1,598 million for the nine months ended September 30, 2019 and 2018, respectively, for marketing of the Company’s E&P sales. Corporate assets include cash and cash equivalents, furniture and fixtures and other assets. Corporate general and administrative costs, depreciation expense and taxes, other than income taxes, are allocated to the segments.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Commitments and 9 Months Ended Contingencies Sep. 30, 2019 Commitments and Contingencies Disclosure [Abstract] Commitments and COMMITMENTS AND CONTINGENCIES Contingencies Operating Commitments and Contingencies

As of September 30, 2019, the Company’s contractual obligations for demand and similar charges under firm transportation and gathering agreements to guarantee access capacity on natural gas and liquids pipelines and gathering systems totaled approximately $8.2 billion, $752 million of which related to access capacity on future pipeline and gathering infrastructure projects that still require the granting of regulatory approvals and additional construction efforts. The Company also had guarantee obligations of up to $323 million of that amount. As of September 30, 2019, future payments under non-cancelable firm transportation and gathering agreements were as follows:

Payments Due by Period

Less than 1 More than 8 (in millions) Total Year 1 to 3 Years 3 to 5 Years 5 to 8 Years Years

Infrastructure currently in service $ 7,442 $ 681 $ 1,272 $ 1,075 $ 1,528 $ 2,886 (1) Pending regulatory approval and/or construction 752 19 73 75 139 446

Total transportation charges $ 8,194 $ 700 $ 1,345 $ 1,150 $ 1,667 $ 3,332

(1) Based on estimated in-service dates as of September 30, 2019.

In December 2018, the Company closed the Fayetteville Shale sale. The Company retained certain contractual commitments related to firm transportation, with the buyer obligated to pay the transportation provider directly for these charges. As of September 30, 2019, approximately $135 million of these contractual commitments remain of which the Company will reimburse the buyer for certain of these potential obligations up to approximately $70 million through December 2020 depending on the buyer’s actual use, and has recorded a $57 million liability for the estimated future payments, down from $88 million recorded at December 31, 2018.

In the first quarter of 2019, the Company agreed to purchase firm transportation with pipelines in the Appalachian Basin starting in 2021 and running through 2032 totaling $357 million in total contractual commitments, which is presented in the table above; the seller has agreed to reimburse $133 million of these commitments.

In July 2019, the Company terminated its existing lease agreement and entered into a new lease agreement for a smaller portion of the headquarters office building, resulting in a contractual commitment totaling $87 million over the next ten years as of September 30, 2019.

Environmental Risk

The Company is subject to laws and regulations relating to the protection of the environment. Environmental and cleanup related costs of a non-capital nature are accrued when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. Management believes any future remediation or other compliance related costs will not have a material effect on the financial position, results of operations or cash flows of the Company.

Litigation

The Company is subject to various litigation, claims and proceedings that have arisen in the ordinary course of business, such as for alleged breaches of contract, miscalculation of royalties, employment matters, traffic accidents, pollution, contamination, encroachment on others’ property or nuisance. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. As of September 30, 2019, the Company does not currently have any material amounts accrued related to litigation matters. For any matters not accrued for, it is not possible at this time to estimate the amount of any additional loss, or range of loss, that is reasonably possible, but, based on the nature of the claims, management believes that current litigation, claims and proceedings, individually or in aggregate and after taking into account insurance, are not likely to have a material adverse impact on the Company’s financial position, results of operations or cash flows, for the period in which the effect of that outcome becomes reasonably estimable. Many of these matters are in early stages, so the allegations and the damage theories have not been fully developed, and are all subject to inherent uncertainties; therefore, management’s view may change in the future.

As of September 30, 2019, all certified class actions against the Company regarding royalty payments in Arkansas have been resolved favorably to the Company or settled. Some actions filed on behalf of mineral interest owners who opted out of the class actions remain pending, but the Company does not expect these cases to have a material impact on its financial position, results of operations, or cash flows.

Indemnifications

The Company has provided certain indemnifications to various third parties, including in relation to asset and entity dispositions, securities offerings and other financings. In the case of asset dispositions, these indemnifications typically relate to disputes, litigation or tax matters existing at the date of disposition. The Company likewise obtains indemnification for future matters when it sells assets, although there is no assurance the buyer will be capable of performing those obligations. In the case of equity offerings, these indemnifications typically relate to claims asserted against underwriters in connection with an offering. No material liabilities have been recognized in connection with these indemnifications.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Restructuring Charges 9 Months Ended (Tables) Sep. 30, 2019 Restructuring and Related Activities [Abstract] Summary of Restructuring Charges The following table presents a summary of the restructuring charges included in Operating Income (Loss) for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September 30, For the nine months ended September 30,

(in millions) 2019 2018 2019 2018

Severance (including payroll taxes) $ 1 $ 1 $ 4 $ 18 Office consolidation 3 — 5 — Professional fees — 1 — 2 (1) Total restructuring charges $ 4 $ 2 $ 9 $ 20

(1) Total restructuring charges were $4 million and $9 million for the Company’s E&P segment for the three and nine months ended September 30, 2019, respectively. Total restructuring charges were $2 million for the Company’s E&P segment for the three months ended September 30, 2018, and $18 million and $2 million for the Company’s E&P and Midstream segments, respectively, for the nine months ended September 30, 2018.

The following table presents a reconciliation of the liability associated with the Company’s restructuring activities at September 30, 2019, which is reflected in accounts payable on the consolidated balance sheet:

(in millions) Liability at December 31, 2018 $ 5 Additions 9 Distributions (13)

Liability at September 30, 2019 $ 1

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED 9 Months Ended STATEMENTS OF CASH Sep. 30, Sep. 30, FLOWS - USD ($) 2019 2018 $ in Millions Cash Flows From Operating Activities: Net income $ 781 $ 230 [1] Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 352 426 Amortization of debt issuance costs 5 6 Impairments 8 171 Deferred income taxes (400) 0 (Gain) loss on derivatives, unsettled (108) 113 Stock-based compensation 6 12 (Gain) loss on early extinguishment of debt (7) 8 Loss on sale of assets 3 0 Other 11 7 Change in assets and liabilities: Accounts receivable 257 (7) Accounts payable (124) 60 Taxes payable (3) 0 Interest payable 2 (5) Inventories (2) (9) Other assets and liabilities (42) (41) Net cash provided by operating activities 739 971 Cash Flows From Investing Activities: Capital investments (877) (1,008) Proceeds from sale of property and equipment 42 9 Other 0 4 Net cash used in investing activities (835) (995) Cash Flows From Financing Activities: Payments on long-term debt (43) (1,191) Payments on revolving credit facility 0 (1,122) Borrowings under revolving credit facility 0 1,482 Change in bank drafts outstanding (11) 10 Debt issuance costs 0 (9) Purchase of treasury stock (21) (25) Preferred stock dividend 0 (27) Cash paid for tax withholding (1) (1) Net cash used in financing activities (76) (883) Decrease in cash and cash equivalents (172) (907) Cash and cash equivalents at beginning of year 201 916 Cash and cash equivalents at end of period $ 29 $ 9

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED 3 Months Ended 9 Months Ended STATEMENTS OF COMPREHENSIVE Sep. 30, Sep. 30, [1] Sep. 30, Sep. 30, [1] INCOME - USD ($) 2019 2018 2019 2018 $ in Millions Statement of Comprehensive Income [Abstract] Net income (loss) $ 49 $ (29) $ 781 $ 230 Change in value of pension and other postretirement liabilities: Amortization of prior service cost and net loss included in net [2] 1 4 5 4 periodic pension cost Comprehensive income (loss) $ 50 $ (25) $ 786 $ 234 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance. [2]Primarily related to settlement of pension assets in 2019 and the curtailment of pension assets in 2018. Net of less than $1 million and $1 million in taxes for the three months ended September 30, 2019 and 2018, respectively, and $2 million and $1 million in taxes for the nine months ended September 30, 2019 and 2018, respectively.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Commitments and 9 Months Ended Contingencies (Tables) Sep. 30, 2019 Commitments and Contingencies Disclosure [Abstract] Schedule of Future Obligation As of September 30, 2019, future payments under non-cancelable firm transportation and gathering agreements were as follows: under Transportation Agreements Payments Due by Period Less than 1 More than 8 (in millions) Total Year 1 to 3 Years 3 to 5 Years 5 to 8 Years Years

Infrastructure currently in service $ 7,442 $ 681 $ 1,272 $ 1,075 $ 1,528 $ 2,886 (1) Pending regulatory approval and/or construction 752 19 73 75 139 446

Total transportation charges $ 8,194 $ 700 $ 1,345 $ 1,150 $ 1,667 $ 3,332

(1) Based on estimated in-service dates as of September 30, 2019.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Leases (Tables) Sep. 30, 2019 Leases [Abstract] Lease costs The components of lease costs are shown below:

For the nine months ended (in millions) September 30, 2019 Operating lease cost $ 33 Short-term lease cost 49 Variable lease cost 1

Total lease cost $ 83

As of September 30, 2019, the Company has operating leases of $20 million, related primarily to compressor leases, that have been executed but not yet commenced. These operating leases are planned to commence during 2019 with lease terms expiring through 2023. The Company’s existing operating leases do not contain any material restrictive covenants.

Supplemental cash flow information related to leases is set forth below:

For the nine months ended (in millions) September 30, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 34

Right-of-use assets obtained in exchange for new operating liabilities: Operating leases $ 88

Supplemental balance sheet information Supplemental balance sheet information related to leases is as follows:

Right-of-use asset balance: (in millions) September 30, 2019 Operating leases $ 164

Lease liability balance: (in millions) Short-term operating leases $ 35 Long-term operating leases 124 Total operating leases $ 159

Weighted average remaining lease term: (years) Operating leases 6.8

Weighted average discount rate: Operating leases 5.54 %

Lease maturity schedule Maturity analysis of operating lease liabilities:

(in millions) September 30, 2019

2019 $ 12 2020 40 2021 31 2022 21 2023 19 2024 15 Thereafter 52 Total undiscounted lease liability 190 Imputed interest (31)

Total discounted lease liability $ 159

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) December 31, 2018

2019 $ 38 2020 28 2021 14 2022 6 2023 5 Thereafter 4

Total minimum payments required $ 95

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk 9 Months Ended Management (Tables) Sep. 30, 2019 Derivative Instruments and Hedging Activities Disclosure [Abstract] Schedule of Derivative Instruments Notional Amount, The following tables provide information about the Company’s financial instruments that are sensitive to changes in commodity prices and that are used to protect the Weighted Average Contract Company’s exposure. None of the financial instruments below are designated for hedge accounting treatment. The tables present the notional amount, the weighted average Prices and Fair Value contract prices and the fair value by expected maturity dates as of September 30, 2019:

Financial Protection on Production Weighted Average Price per MMBtu Fair Value at September 30, 2019 Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential (in millions)

Natural Gas 2019 Fixed price swaps 61 $ 2.89 $ — $ — $ — $ — $ 28 Two-way costless collars 6 — — 2.78 2.92 — 2 Three-way costless collars 44 — 2.43 2.82 3.15 — 13 Total 111 $ 43 2020 (1) Fixed price swaps 151 $ 2.58 $ — $ — $ — $ — $ 45 Three-way costless collars 209 — 2.34 2.67 2.98 — 22 Total 360 $ 67 2021 Three-way costless collars 134 $ — $ 2.27 $ 2.55 $ 2.85 $ — $ (1) 2022 Three-way costless collars 23 $ — $ 2.30 $ 2.70 $ 3.14 $ — $ —

Basis Swaps 2019 35 $ — $ — $ — $ — $ (0.40) $ 9 2020 141 — — — — (0.31) (13) 2021 65 — — — — (0.48) (1) 2022 45 — — — — (0.50) — Total 286 $ (5)

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Weighted Average Strike Price per Bbl Fair Value at September 30, Volume 2019 (MBbls) Swaps Sold Puts Purchased Puts Sold Calls (in millions) Oil 2019 (1) Fixed price swaps 632 $ 60.65 $ — $ — $ — $ 4 Two-way costless collars 382 — — 61.45 67.16 3 Three-way costless collars 138 — 45.00 55.00 63.67 — Total 1,152 $ 7 2020 Fixed price swaps 1,556 $ 60.18 $ — $ — $ — $ 14 Two-way costless collars 366 — — 60.00 69.80 4 Three-way costless collars 915 — 45.00 55.00 61.75 3 Total 2,837 $ 21 2021 Three-way costless collars 730 $ — $ 45.00 $ 53.00 $ 59.50 $ 1

Propane 2019 Fixed price swaps 978 $ 30.18 $ — $ — $ — $ 11 Two-way costless collars 138 — — 25.62 28.77 1 Total 1,116 $ 12 2020 Fixed price swaps 2,928 $ 25.58 $ — $ — $ — $ 18 Two-way costless collars 366 — — 25.20 $ 29.40 2 Total 3,294 $ 20 2021 Fixed price swaps 456 $ 22.24 $ — $ — $ — $ 1

Ethane 2019 Fixed price swaps 2,194 $ 10.53 $ — $ — $ — $ 6 2020 Fixed price swaps 3,843 $ 9.80 $ — $ — $ — $ 7

(1) Includes 69 MBbls of purchased fixed price oil swaps hedged at $69.10 per Bbl with a fair value of ($1) million and 701 MBbls of sold fixed price oil swaps hedged at $61.48 per Bbl with a fair value of $5 million.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Other Derivative Contracts Volume Weighted Average Strike Fair Value at September 30, (Bcf) Price per MMBtu 2019 (in millions)

Purchased Call Options – Natural Gas 2019 5 $ 3.50 $ — 2020 68 3.63 1 2021 57 3.52 2 Total 130 $ 3

Sold Call Options – Natural Gas 2019 13 $ 3.50 $ — 2020 137 3.39 (5) 2021 114 3.33 (6) 2023 6 3.00 (1) 2024 9 3.00 (2) Total 279 $ (14)

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Volume Weighted Average Strike Basis Differential per Fair Value at September 30, (Bcf) Price per MMBtu MMBtu 2019 (in millions) (1) Storage 2019 Purchased fixed price swaps — $ 2.90 $ — $ — Purchased basis swaps — — (0.61) — Total — $ — 2020 Purchased fixed price swaps — $ 2.37 $ — $ — Purchased basis swaps — — (0.32) — Sold fixed price swaps 2 3.06 — 1 Sold basis swaps — — (0.32) — Total 2 $ 1

(1) The Company has entered into certain derivatives to protect the value of volumes of natural gas injected into a storage facility that will be withdrawn at a later date. Balance Sheet Classification of Derivative Financial The balance sheet classification of the assets and liabilities related to derivative financial instruments (none of which are designated for hedge accounting treatment) is Instruments summarized below as of September 30, 2019 and December 31, 2018:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative Assets Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: (1) Fixed price swaps – natural gas Derivative assets $ 68 $ 32 Fixed price swaps – oil Derivative assets 15 13 Fixed price swaps – propane Derivative assets 25 11 Fixed price swaps – ethane Derivative assets 12 7 Two-way costless collars – natural gas Derivative assets 2 11 Two-way costless collars – oil Derivative assets 6 6 Two-way costless collars – propane Derivative assets 3 — Three-way costless collars – natural gas Derivative assets 84 41 Three-way costless collars – oil Derivative assets 5 — Basis swaps – natural gas Derivative assets 17 8 Purchased call options – natural gas Derivative assets 1 — Storage – fixed price swaps Derivative assets 1 — Interest rate swaps Derivative assets — 1 Fixed price swaps – natural gas Other long-term assets 5 6 Fixed price swaps – oil Other long-term assets 4 6 Fixed price swaps – propane Other long-term assets 5 — Fixed price swaps – ethane Other long-term assets 1 1 Two-way costless collars – oil Other long-term assets 1 5 Three-way costless collars – natural gas Other long-term assets 63 34 Three-way costless collars – oil Other long-term assets 8 — Basis swaps – natural gas Other long-term assets 7 3 Purchased call options – natural gas Other long-term assets 2 6

Total derivative assets $ 335 $ 191

Derivative Liabilities Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: Purchased fixed price swap – oil Derivative liabilities $ 1 $ 6 Fixed price swaps – natural gas Derivative liabilities — 9 Fixed price swaps – ethane Derivative liabilities — 3 Two-way costless collars – natural gas Derivative liabilities — 7 Three-way costless collars – natural gas Derivative liabilities 53 33 Three-way costless collars – oil Derivative liabilities 3 — Basis swaps – natural gas Derivative liabilities 24 18 Sold call options – natural gas Derivative liabilities 4 3 Fixed price swaps – natural gas Other long-term liabilities — 1 Two-way costless collars – oil Other long-term liabilities — 1 Three-way costless collars – natural gas Other long-term liabilities 60 35 Three-way costless collars – oil Other long-term liabilities 6 — Basis swap – natural gas Other long-term liabilities 5 4 Sold call options – natural gas Other long-term liabilities 10 19

Total derivative liabilities $ 166 $ 139 (1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Summary of Before Tax Effect The following tables summarize the before-tax effect of the Company’s derivative instruments on the consolidated statements of operations for the three and nine months of Fair Value Hedges not ended September 30, 2019 and 2018: Designated for Hedge Accounting Unsettled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Unsettled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ 5 $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives (19) (17) 36 (46) Fixed price swaps – oil Gain (Loss) on Derivatives 8 — — — Fixed price swaps – propane Gain (Loss) on Derivatives 10 (10) 19 (19) Fixed price swaps – ethane Gain (Loss) on Derivatives 1 (27) 8 (29) Two-way costless collars – natural gas Gain (Loss) on Derivatives (11) 2 (2) 4 Two-way costless collars – oil Gain (Loss) on Derivatives — — (3) — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 3 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 3 (7) 27 (36) Three-way costless collars – oil Gain (Loss) on Derivatives 3 — 4 — Basis swaps – natural gas Gain (Loss) on Derivatives 12 (5) 6 11 Purchased call options – natural gas Gain (Loss) on Derivatives (1) (2) (3) 2 Sold call options – natural gas Gain (Loss) on Derivatives 2 5 8 2 Sold call options – oil Gain (Loss) on Derivatives — 1 — (5) Storage – fixed price swap Gain (Loss) on Derivatives 2 — 1 — Interest rate swaps Gain (Loss) on Derivatives 1 1 (1) 3

Total gain (loss) on unsettled derivatives $ 12 $ (59) $ 108 $ (113)

(1) Settled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Settled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ (2) $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives 45 5 53 18 Fixed price swaps – oil Gain (Loss) on Derivatives 3 — 7 — Fixed price swaps – propane Gain (Loss) on Derivatives 11 (5) 20 (6) Fixed price swaps – ethane Gain (Loss) on Derivatives 6 (6) 12 (6) Two-way costless collars – natural gas Gain (Loss) on Derivatives 10 — 12 4 Two-way costless collars – oil Gain (Loss) on Derivatives 2 — 4 — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 1 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 15 5 19 24 Basis swaps – natural gas Gain (Loss) on Derivatives (3) (4) (11) (28) (2) (2) (3) Purchased call options – natural gas Gain (Loss) on Derivatives (1) — (1) 2 Sold call options – natural gas Gain (Loss) on Derivatives — — (1) (1) Sold call options – oil Gain (Loss) on Derivatives — (1) — (2) Storage – fixed price swap Gain (Loss) on Derivatives (1) — (1) — Total gain (loss) on settled derivatives $ 88 $ (6) $ 112 $ 5

Total gain (loss) on derivatives $ 100 $ (65) $ 220 $ (108)

(1) The Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that settled within the period.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (2) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the three and nine months ended September 30, 2019, which is included in gain (loss) on derivatives on the consolidated statements of operations.

(3) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the nine months ended September 30, 2018, which is included in gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk 9 Months Ended Management Sep. 30, 2019 Derivative Instruments and Hedging Activities Disclosure [Abstract] Derivatives and Risk DERIVATIVES AND RISK MANAGEMENTThe Company is exposed to volatility in market prices and basis differentials for natural gas, oil Management and NGLs which impacts the predictability of its cash flows related to the sale of those commodities. These risks are managed by the Company’s use of certain derivative financial instruments. As of September 30, 2019, the Company’s derivative financial instruments consisted of fixed price swaps, two-way costless collars, three-way costless collars, basis swaps, call options and interest rate swaps. A description of the Company’s derivative financial instruments is provided below:

Fixed price swaps If the Company sells a fixed price swap, the Company receives a fixed price for the contract and pays a floating market price to the counterparty. If the Company purchases a fixed price swap, the Company receives a floating market price for the contract and pays a fixed price to the counterparty.

Two-way costless collars Arrangements that contain a fixed floor price (purchased put option) and a fixed ceiling price (sold call option) based on an index price which, in aggregate, have no net cost. At the contract settlement date, (1) if the index price is higher than the ceiling price, the Company pays the counterparty the difference between the index price and ceiling price, (2) if the index price is between the floor and ceiling prices, no payments are due from either party, and (3) if the index price is below the floor price, the Company will receive the difference between the floor price and the index price.

Three-way costless collars Arrangements that contain a purchased put option, a sold call option and a sold put option based on an index price which, in aggregate, have no net cost. At the contract settlement date, (1) if the index price is higher than the sold call strike price, the Company pays the counterparty the difference between the index price and sold call strike price, (2) if the index price is between the purchased put strike price and the sold call strike price, no payments are due from either party, (3) if the index price is between the sold put strike price and the purchased put strike price, the Company will receive the difference between the purchased put strike price and the index price, and (4) if the index price is below the sold put strike price, the Company will receive the difference between the purchased put strike price and the sold put strike price.

Basis swaps Arrangements that guarantee a price differential for natural gas from a specified delivery point. If the Company sells a basis swap, the Company receives a payment from the counterparty if the price differential is greater than the stated terms of the contract and pays the counterparty if the price differential is less than the stated terms of the contract. If the Company purchases a basis swap, the Company pays the counterparty if the price differential is greater than the stated terms of the contract and receives a payment from the counterparty if the price differential is less than the stated terms of the contract.

Call options The Company purchases and sells call options in exchange for a premium. If the Company purchases a call option, the Company receives from the counterparty the excess (if any) of the market price over the strike price of the call option at the time of settlement, but if the market price is below the call’s strike price, no payment is due from either party. If the Company sells a call option, the Company pays the counterparty the excess (if any) of the market price over the strike price of the call option at the time of settlement, but if the market price is below the call’s strike price, no payment is due from either party.

Interest rate swaps Interest rate swaps are used to fix or float interest rates on existing or anticipated indebtedness. The purpose of these instruments is to manage the Company’s existing or anticipated exposure to unfavorable interest rate changes.

The Company chooses counterparties for its derivative instruments that it believes are creditworthy at the time the transactions are entered into, and the Company actively monitors the credit ratings and credit default swap rates of these counterparties where applicable. However, there can be no assurance that a counterparty will be able to meet its obligations to the Company. The Company presents its derivative positions on a gross basis and does not net the asset and liability positions.

As part of the Fayetteville Shale sale, the Company entered into certain natural gas derivative positions that were subsequently novated to the buyer in conjunction with finalization of the sale. The derivatives that were novated to the buyer are not included in the tables below.

The following tables provide information about the Company’s financial instruments that are sensitive to changes in commodity prices and that are used to protect the Company’s exposure. None of the financial instruments below are designated for hedge accounting treatment. The tables present the notional amount, the weighted average contract prices and the fair value by expected maturity dates as of September 30, 2019:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Financial Protection on Production Weighted Average Price per MMBtu Fair Value at September 30, 2019 Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential (in millions)

Natural Gas 2019 Fixed price swaps 61 $ 2.89 $ — $ — $ — $ — $ 28 Two-way costless collars 6 — — 2.78 2.92 — 2 Three-way costless collars 44 — 2.43 2.82 3.15 — 13 Total 111 $ 43 2020 (1) Fixed price swaps 151 $ 2.58 $ — $ — $ — $ — $ 45 Three-way costless collars 209 — 2.34 2.67 2.98 — 22 Total 360 $ 67 2021 Three-way costless collars 134 $ — $ 2.27 $ 2.55 $ 2.85 $ — $ (1) 2022 Three-way costless collars 23 $ — $ 2.30 $ 2.70 $ 3.14 $ — $ —

Basis Swaps 2019 35 $ — $ — $ — $ — $ (0.40) $ 9 2020 141 — — — — (0.31) (13) 2021 65 — — — — (0.48) (1) 2022 45 — — — — (0.50) — Total 286 $ (5)

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Weighted Average Strike Price per Bbl Fair Value at September 30, Volume 2019 (MBbls) Swaps Sold Puts Purchased Puts Sold Calls (in millions) Oil 2019 (1) Fixed price swaps 632 $ 60.65 $ — $ — $ — $ 4 Two-way costless collars 382 — — 61.45 67.16 3 Three-way costless collars 138 — 45.00 55.00 63.67 — Total 1,152 $ 7 2020 Fixed price swaps 1,556 $ 60.18 $ — $ — $ — $ 14 Two-way costless collars 366 — — 60.00 69.80 4 Three-way costless collars 915 — 45.00 55.00 61.75 3 Total 2,837 $ 21 2021 Three-way costless collars 730 $ — $ 45.00 $ 53.00 $ 59.50 $ 1

Propane 2019 Fixed price swaps 978 $ 30.18 $ — $ — $ — $ 11 Two-way costless collars 138 — — 25.62 28.77 1 Total 1,116 $ 12 2020 Fixed price swaps 2,928 $ 25.58 $ — $ — $ — $ 18 Two-way costless collars 366 — — 25.20 $ 29.40 2 Total 3,294 $ 20 2021 Fixed price swaps 456 $ 22.24 $ — $ — $ — $ 1

Ethane 2019 Fixed price swaps 2,194 $ 10.53 $ — $ — $ — $ 6 2020 Fixed price swaps 3,843 $ 9.80 $ — $ — $ — $ 7

(1) Includes 69 MBbls of purchased fixed price oil swaps hedged at $69.10 per Bbl with a fair value of ($1) million and 701 MBbls of sold fixed price oil swaps hedged at $61.48 per Bbl with a fair value of $5 million.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Other Derivative Contracts Volume Weighted Average Strike Fair Value at September 30, (Bcf) Price per MMBtu 2019 (in millions)

Purchased Call Options – Natural Gas 2019 5 $ 3.50 $ — 2020 68 3.63 1 2021 57 3.52 2 Total 130 $ 3

Sold Call Options – Natural Gas 2019 13 $ 3.50 $ — 2020 137 3.39 (5) 2021 114 3.33 (6) 2023 6 3.00 (1) 2024 9 3.00 (2) Total 279 $ (14)

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Volume Weighted Average Strike Basis Differential per Fair Value at September 30, (Bcf) Price per MMBtu MMBtu 2019 (in millions) (1) Storage 2019 Purchased fixed price swaps — $ 2.90 $ — $ — Purchased basis swaps — — (0.61) — Total — $ — 2020 Purchased fixed price swaps — $ 2.37 $ — $ — Purchased basis swaps — — (0.32) — Sold fixed price swaps 2 3.06 — 1 Sold basis swaps — — (0.32) — Total 2 $ 1

(1) The Company has entered into certain derivatives to protect the value of volumes of natural gas injected into a storage facility that will be withdrawn at a later date.

At September 30, 2019, the net fair value of the Company’s financial instruments related to commodities was a $169 million asset.

As of September 30, 2019, the Company had no positions designated for hedge accounting treatment. Gains and losses on derivatives that are not designated for hedge accounting treatment, or do not meet hedge accounting requirements, are recorded as a component of gain (loss) on derivatives on the consolidated statements of operations. Accordingly, the gain (loss) on derivatives component of the statement of operations reflects the gain and losses on both settled and unsettled derivatives. The Company calculates gains and losses on settled derivatives as the summation of gains and losses on positions which have settled within the reporting period. Only the settled gains and losses are included in the Company’s realized commodity price calculations.

The Company is a party to interest rate swaps that were entered into to mitigate the Company’s exposure to volatility in interest rates. The interest rate swaps have a notional amount of $170 million and expire in June 2020. The Company did not designate the interest rate swaps for hedge accounting treatment. Changes in the fair value of the interest rate swaps are included in gain (loss) on derivatives on the consolidated statements of operations.

The balance sheet classification of the assets and liabilities related to derivative financial instruments (none of which are designated for hedge accounting treatment) is summarized below as of September 30, 2019 and December 31, 2018:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivative Assets Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: (1) Fixed price swaps – natural gas Derivative assets $ 68 $ 32 Fixed price swaps – oil Derivative assets 15 13 Fixed price swaps – propane Derivative assets 25 11 Fixed price swaps – ethane Derivative assets 12 7 Two-way costless collars – natural gas Derivative assets 2 11 Two-way costless collars – oil Derivative assets 6 6 Two-way costless collars – propane Derivative assets 3 — Three-way costless collars – natural gas Derivative assets 84 41 Three-way costless collars – oil Derivative assets 5 — Basis swaps – natural gas Derivative assets 17 8 Purchased call options – natural gas Derivative assets 1 — Storage – fixed price swaps Derivative assets 1 — Interest rate swaps Derivative assets — 1 Fixed price swaps – natural gas Other long-term assets 5 6 Fixed price swaps – oil Other long-term assets 4 6 Fixed price swaps – propane Other long-term assets 5 — Fixed price swaps – ethane Other long-term assets 1 1 Two-way costless collars – oil Other long-term assets 1 5 Three-way costless collars – natural gas Other long-term assets 63 34 Three-way costless collars – oil Other long-term assets 8 — Basis swaps – natural gas Other long-term assets 7 3 Purchased call options – natural gas Other long-term assets 2 6

Total derivative assets $ 335 $ 191

Derivative Liabilities Fair Value

(in millions) Balance Sheet Classification September 30, 2019 December 31, 2018 Derivatives not designated as hedging instruments: Purchased fixed price swap – oil Derivative liabilities $ 1 $ 6 Fixed price swaps – natural gas Derivative liabilities — 9 Fixed price swaps – ethane Derivative liabilities — 3 Two-way costless collars – natural gas Derivative liabilities — 7 Three-way costless collars – natural gas Derivative liabilities 53 33 Three-way costless collars – oil Derivative liabilities 3 — Basis swaps – natural gas Derivative liabilities 24 18 Sold call options – natural gas Derivative liabilities 4 3 Fixed price swaps – natural gas Other long-term liabilities — 1 Two-way costless collars – oil Other long-term liabilities — 1 Three-way costless collars – natural gas Other long-term liabilities 60 35 Three-way costless collars – oil Other long-term liabilities 6 — Basis swap – natural gas Other long-term liabilities 5 4 Sold call options – natural gas Other long-term liabilities 10 19

Total derivative liabilities $ 166 $ 139

(1) Includes $9 million in premiums paid related to certain natural gas fixed price swaps recognized as a component of derivative assets within current assets on the consolidated balance sheet at September 30, 2019. As certain natural gas fixed price swaps settle, the premium will be amortized and recognized as a component of gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The following tables summarize the before-tax effect of the Company’s derivative instruments on the consolidated statements of operations for the three and nine months ended September 30, 2019 and 2018:

Unsettled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Unsettled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ 5 $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives (19) (17) 36 (46) Fixed price swaps – oil Gain (Loss) on Derivatives 8 — — — Fixed price swaps – propane Gain (Loss) on Derivatives 10 (10) 19 (19) Fixed price swaps – ethane Gain (Loss) on Derivatives 1 (27) 8 (29) Two-way costless collars – natural gas Gain (Loss) on Derivatives (11) 2 (2) 4 Two-way costless collars – oil Gain (Loss) on Derivatives — — (3) — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 3 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 3 (7) 27 (36) Three-way costless collars – oil Gain (Loss) on Derivatives 3 — 4 — Basis swaps – natural gas Gain (Loss) on Derivatives 12 (5) 6 11 Purchased call options – natural gas Gain (Loss) on Derivatives (1) (2) (3) 2 Sold call options – natural gas Gain (Loss) on Derivatives 2 5 8 2 Sold call options – oil Gain (Loss) on Derivatives — 1 — (5) Storage – fixed price swap Gain (Loss) on Derivatives 2 — 1 — Interest rate swaps Gain (Loss) on Derivatives 1 1 (1) 3

Total gain (loss) on unsettled derivatives $ 12 $ (59) $ 108 $ (113)

(1) Settled Gain (Loss) on Derivatives Recognized in Earnings

Consolidated Statement of Operations For the three months ended For the nine months ended Classification of Gain (Loss) September 30, September 30, Derivative Instrument on Derivatives, Settled 2019 2018 2019 2018

(in millions) Purchased fixed price swaps – oil Gain (Loss) on Derivatives $ — $ — $ (2) $ — Fixed price swaps – natural gas Gain (Loss) on Derivatives 45 5 53 18 Fixed price swaps – oil Gain (Loss) on Derivatives 3 — 7 — Fixed price swaps – propane Gain (Loss) on Derivatives 11 (5) 20 (6) Fixed price swaps – ethane Gain (Loss) on Derivatives 6 (6) 12 (6) Two-way costless collars – natural gas Gain (Loss) on Derivatives 10 — 12 4 Two-way costless collars – oil Gain (Loss) on Derivatives 2 — 4 — Two-way costless collars – propane Gain (Loss) on Derivatives 1 — 1 — Three-way costless collars – natural gas Gain (Loss) on Derivatives 15 5 19 24 Basis swaps – natural gas Gain (Loss) on Derivatives (3) (4) (11) (28) (2) (2) (3) Purchased call options – natural gas Gain (Loss) on Derivatives (1) — (1) 2 Sold call options – natural gas Gain (Loss) on Derivatives — — (1) (1) Sold call options – oil Gain (Loss) on Derivatives — (1) — (2) Storage – fixed price swap Gain (Loss) on Derivatives (1) — (1) — Total gain (loss) on settled derivatives $ 88 $ (6) $ 112 $ 5

Total gain (loss) on derivatives $ 100 $ (65) $ 220 $ (108)

(1) The Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that settled within the period.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (2) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the three and nine months ended September 30, 2019, which is included in gain (loss) on derivatives on the consolidated statements of operations.

(3) Includes $1 million amortization of premiums paid related to certain natural gas purchased call options for the nine months ended September 30, 2018, which is included in gain (loss) on derivatives on the consolidated statements of operations.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Revenue Recognition Sep. 30, 2019 Revenue from Contract with Customer [Abstract] Revenue Recognition REVENUE RECOGNITION

Revenues from Contracts with Customers

Natural gas and liquids. Natural gas, oil and NGL sales are recognized when control of the product is transferred to the customer at a designated delivery point. The pricing provisions of the Company’s contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, quality of the product and prevailing supply and demand conditions in the geographic areas in which the Company operates. Under the Company’s sales contracts, the delivery of each unit of natural gas, oil and NGLs represents a separate performance obligation, and revenue is recognized at the point in time when the performance obligations are fulfilled. There is no significant financing component to the Company’s revenues as payment terms are typically within 30 to 60 days of control transfer. Furthermore, consideration from a customer corresponds directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognizes revenue in the amount to which the Company has a right to invoice and has not disclosed information regarding its remaining performance obligations.

The Company records revenue from its natural gas and liquids production in the amount of its net revenue interest in sales from its properties. Accordingly, natural gas and liquid sales are not recognized for deliveries in excess of the Company’s net revenue interest, while natural gas and liquid sales are recognized for any under-delivered volumes. Production imbalances are recorded as receivables and payables and not contract assets or contract liabilities as the imbalances are between the Company and other working interest owners, not the end customer.

Marketing. The Company, through its marketing affiliate, generally markets natural gas, oil and NGLs for its affiliated E&P company as well as other joint interest owners who choose to market with Southwestern. In addition, the Company markets some products purchased from third parties. Marketing revenues for natural gas, oil and NGL sales are recognized when control of the product is transferred to the customer at a designated delivery point. The pricing provisions of the Company’s contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, quality of the product and prevailing supply and demand conditions. Under the Company’s marketing contracts, the delivery of each unit of natural gas, oil and NGLs represents a separate performance obligation, and revenue is recognized at the point in time when the performance obligations are fulfilled. Customers are invoiced and revenues are recorded each month as natural gas, oil and NGLs are delivered, and payment terms are typically within 30 to 60 days of control transfer. Furthermore, consideration from a customer corresponds directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognizes revenue in the amount to which the Company has a right to invoice and has not disclosed information regarding its remaining performance obligations.

Gas gathering. Prior to the Fayetteville Shale sale in December 2018, the Company, through its gathering affiliate, gathered natural gas pursuant to a variety of contracts with customers, including an affiliated E&P company. The performance obligations for gas gathering services included delivery of each unit of natural gas to the designated delivery point, which may include treating of certain natural gas units to meet interstate pipeline specifications. Revenue was recognized at the point in time when performance obligations were fulfilled. Under the Company’s gathering contracts, customers were invoiced and revenue was recognized each month based on the volume of natural gas transported and treated at a contractually agreed upon price per unit. Payment terms were typically within 30 to 60 days of completion of the performance obligations. Furthermore, consideration from a customer corresponded directly with the value to the customer of the Company’s performance completed to date. As a result, the Company recognized revenue in the amount to which the Company had a right to invoice and had not disclosed information regarding its remaining performance obligations. Any imbalances were settled on a monthly basis by cashing-out with the respective shipper. Accordingly, there were no contract assets or contract liabilities related to the Company’s gas gathering revenues.

Disaggregation of Revenues

The Company presents a disaggregation of E&P revenues by product on the consolidated statements of operations net of intersegment revenues. The following table reconciles operating revenues as presented on the consolidated statements of operations to the operating revenues by segment:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Intersegment (in millions) E&P Midstream Revenues Total

Three months ended September 30, 2019 Gas sales $ 230 $ — $ 8 $ 238 Oil sales 66 — 1 67 NGL sales 52 — — 52 Marketing — 592 (313) 279

Total $ 348 $ 592 $ (304) $ 636

Three months ended September 30, 2018 Gas sales $ 460 $ — $ 5 $ 465 Oil sales 61 — 1 62 NGL sales 112 — — 112 Marketing — 846 (559) 287 (1) Gas gathering — 66 (41) 25

Total $ 633 $ 912 $ (594) $ 951

Intersegment (in millions) E&P Midstream Revenues Total Nine months ended September 30, 2019 Gas sales $ 918 $ — $ 25 $ 943 Oil sales 151 — 2 153 NGL sales 191 — — 191 Marketing — 2,158 (1,154) 1,004 (2) Other 1 1 — 2 Total $ 1,261 $ 2,159 $ (1,127) $ 2,293

Nine months ended September 30, 2018 Gas sales $ 1,395 $ — $ 17 $ 1,412 Oil sales 139 — 2 141 NGL sales 252 — — 252 Marketing — 2,403 (1,598) 805 (1) Gas gathering — 202 (129) 73 (2) Other 4 — — 4 Total $ 1,790 $ 2,605 $ (1,708) $ 2,687

(1) The Company’s gas gathering assets were divested in December 2018 as part of the Fayetteville Shale sale.

(2) Other E&P revenues consists primarily of water sales to third-party operators, and other Midstream revenues consists primarily of sales of gas from storage.

Associated E&P revenues are also disaggregated for analysis on a geographic basis by the core areas in which the Company operates, which are in Pennsylvania and West Virginia. In December 2018, the Company sold 100% of its Fayetteville Shale assets.

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Northeast Appalachia $ 175 $ 254 $ 740 $ 794 Southwest Appalachia 173 235 519 557 Fayetteville Shale — 140 — 431 Other — 4 2 8

Total $ 348 $ 633 $ 1,261 $ 1,790

Receivables from Contracts with Customers

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The following table reconciles the Company’s receivables from contracts with customers to consolidated accounts receivable as presented on the consolidated balance sheet:

(in millions) September 30, 2019 December 31, 2018

Receivables from contracts with customers $ 235 $ 494 Other accounts receivable 88 87

Total accounts receivable $ 323 $ 581

Amounts recognized against the Company’s allowance for doubtful accounts related to receivables arising from contracts with customers were immaterial for the three and nine months ended September 30, 2019 and 2018. The Company has no contract assets or contract liabilities associated with its revenues from contracts with customers.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 1 Months 3 Months Ended 9 Months Ended Debt (2018 Revolving Credit Ended Facility - Narrative) (Details) Sep. Sep. 30, - USD ($) Apr. 26, 2018 Apr. 30, 2018 Sep. 30, 2019 30, Sep. 30, 2019 Dec. 31, 2018 2018 2018 Debt Instrument [Line Items] Debt instrument $ $ 2,292,000,000 $ 2,292,000,000 2,342,000,000 (Gain) loss on early $ (7,000,000) $ 0 (7,000,000) extinguishment of debt 8,000,000 Unamortized issuance expense 20,000,000 $ 20,000,000 $ 23,000,000 Subsidiary ownership 100.00% Letter of Credit Debt Instrument [Line Items] Current aggregate commitment 172,000,000 $ 172,000,000 Long-term debt | 2016 Credit Facility Debt Instrument [Line Items] Debt instrument $ 743,000,000 Long-term debt | 2018 revolving credit facility due April 2023 Debt Instrument [Line Items] Maximum borrowing capacity $ 3,500,000,000 Current aggregate commitment 2,000,000,000.0 2,000,000,000.0 Limit on securing $ $ indebtedness 2,000,000,000.0 2,000,000,000.0 Percentage of consolidated net 25.00% tangible assets Minimum interest coverage 1.00 ratio Long-term debt | 2018 revolving credit facility due April 2023 | Maximum Debt Instrument [Line Items] Leverage ratio, percentage of 10.00% credit limit Leverage ratio, amount of $ 150,000,000 credit limit Long-term debt | 2018 revolving credit facility due April 2023 | Eurodollar | Minimum

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Debt Instrument [Line Items] Basis points 1.50% Long-term debt | 2018 revolving credit facility due April 2023 | Eurodollar | Maximum Debt Instrument [Line Items] Basis points 2.50% Long-term debt | 2018 revolving credit facility due April 2023 | Base Rate | Minimum Debt Instrument [Line Items] Basis points 0.50% Long-term debt | 2018 revolving credit facility due April 2023 | Base Rate | Maximum Debt Instrument [Line Items] Basis points 1.50% 2016 Term Loan due December 2020 | Long-term debt Debt Instrument [Line Items] Debt instrument $ 1,191,000,000 Secured term loan | Long-term debt Debt Instrument [Line Items] Debt instrument $ 743,000,000 Extinguishment of debt 1,191,000,000 (Gain) loss on early 8,000,000 extinguishment of debt Unamortized issuance expense $ 4,000,000 June 30, 2018 Through March 31, 2019 | Long-term debt | 2018 revolving credit facility due April 2023 | Maximum Debt Instrument [Line Items] Leverage ratio 4.50 June 30, 2019 Through March 31, 2020 | Long-term debt | 2018 revolving credit facility due April 2023 | Maximum

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Debt Instrument [Line Items] Leverage ratio 4.25 After June 30, 2020 | Long- term debt | 2018 revolving credit facility due April 2023 | Maximum Debt Instrument [Line Items] Leverage ratio 4.00

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Summary of Equity- Classified Stock Option Sep. 30, 2019 Activity) (Details) - Stock $ / shares options shares shares in Thousands Number of Options Beginning balance (in shares) | shares 5,178 Granted (in shares) | shares 0 Exercised (in shares) | shares 0 Forfeited or expired (in shares) | shares (76) Ending balance (in shares) | shares 5,102 Exercisable (in shares) | shares 4,680 Weighted Average Exercise Price Beginning balance (in dollars per share) | $ / shares $ 17.06 Granted (in dollars per share) | $ / shares 0 Exercised (in dollars per share) | $ / shares 0 Forfeited or expired (in dollars per share) | $ / shares 19.38 Ending balance (in dollars per share) | $ / shares 17.02 Exercisable (in dollars per share) | $ / shares $ 17.85

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Summary of Liability- Classified Restricted Stock Sep. 30, 2019 Unit Activity) (Details) - $ / shares RSUs shares shares in Thousands Number of Shares Beginning balance (in shares) | shares 8,202 Granted (in shares) | shares 8,659 Vested (in shares) | shares (2,624) Forfeited (in shares) | shares (1,000) Ending balance (in shares) | shares 13,237 Weighted Average Fair Value Beginning balance (in dollars per share) | $ / shares $ 3.41 Granted (in dollars per share) | $ / shares 4.34 Vested (in dollars per share) | $ / shares 4.09 Forfeited (in dollars per share) | $ / shares 2.51 Ending balance (in dollars per share) | $ / shares $ 1.93

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Income Taxes (Narrative) 3 Months Ended 9 Months Ended (Details) - USD ($) Sep. 30, Sep. 30, Sep. 30, Sep. 30, $ in Millions 2019 2018 2019 2018 Income Tax Expense (Benefit), Continuing Operations [Abstract] Effective tax rate 18.00% 0.00% (105.00%) 0.00% Increase (decrease) in valuation allowance $ (522) Valuation allowance related to operating loss $ 87 87 Discrete tax benefit $ 399

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Revenue Recognition (Reconciliation of Accounts Receivable) (Details) - USD Sep. 30, 2019Dec. 31, 2018 ($) $ in Millions Revenue from Contract with Customer [Abstract] Receivables from contracts with customers $ 235 $ 494 Other accounts receivable 88 87 Total accounts receivable $ 323 $ 581

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Leases (Maturity Schedule) (Details) - USD ($) Sep. 30, 2019Dec. 31, 2018 $ in Millions Leases [Abstract] 2019 $ 12 $ 38 2020 40 28 2021 31 14 2022 21 6 2023 19 5 2024 15 Thereafter 2023 4 Thereafter 2024 52 Total undiscounted lease liability 190 $ 95 Imputed interest (31) Total discounted lease liability $ 159

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Earnings Per Share 3 Months Ended 9 Months Ended (Schedule of Earnings Per Jun. Mar. Jun. Mar. Share) (Details) - USD ($) Sep. 30, Sep. 30, 30, 31, Sep. 30, 2018 30, 31, Sep. 30, 2018 $ / shares in Units, $ in 2019 2019 2019 2019 2018 2018 Millions Earnings Per Share [Abstract] Net income $ 49 $ 138 $ 594 $ (29) [1] $ 51 $ 208 $ 781 $ 230 [1] Participating securities – mandatory convertible 0 0 0 1 preferred stock Net Income (Loss) $ 49 $ (29) $ 781 $ 229 Attributable to Common Stock Number of common shares: Weighted average outstanding 539,221,101 581,171,753 539,315,170577,912,421 (in shares) Issued upon assumed exercise of outstanding stock options 0 0 0 0 (in shares) Effect of issuance of non- vested restricted common 187,706 0 400,120 640,365 stock (in shares) Effect of issuance of non- vested performance units (in 629,380 0 727,359 1,276,072 shares) Weighted average and potential dilutive outstanding 540,038,187 581,171,753 540,442,649579,828,858 (in shares) Earnings per common share Basic (in dollars per share) $ 0.09 $ (0.05) $ 1.45 $ 0.40 Diluted (in dollars per share) $ 0.09 $ (0.05) $ 1.44 $ 0.39 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Revenue Recognition 9 Months Ended (Tables) Sep. 30, 2019 Revenue from Contract with Customer [Abstract] Disaggregation of Revenue by The following table reconciles operating revenues as presented on the consolidated statements of operations to the operating revenues by Segment segment:

Intersegment (in millions) E&P Midstream Revenues Total

Three months ended September 30, 2019 Gas sales $ 230 $ — $ 8 $ 238 Oil sales 66 — 1 67 NGL sales 52 — — 52 Marketing — 592 (313) 279

Total $ 348 $ 592 $ (304) $ 636

Three months ended September 30, 2018 Gas sales $ 460 $ — $ 5 $ 465 Oil sales 61 — 1 62 NGL sales 112 — — 112 Marketing — 846 (559) 287 (1) Gas gathering — 66 (41) 25

Total $ 633 $ 912 $ (594) $ 951

Intersegment (in millions) E&P Midstream Revenues Total Nine months ended September 30, 2019 Gas sales $ 918 $ — $ 25 $ 943 Oil sales 151 — 2 153 NGL sales 191 — — 191 Marketing — 2,158 (1,154) 1,004 (2) Other 1 1 — 2 Total $ 1,261 $ 2,159 $ (1,127) $ 2,293

Nine months ended September 30, 2018 Gas sales $ 1,395 $ — $ 17 $ 1,412 Oil sales 139 — 2 141 NGL sales 252 — — 252 Marketing — 2,403 (1,598) 805 (1) Gas gathering — 202 (129) 73 (2) Other 4 — — 4 Total $ 1,790 $ 2,605 $ (1,708) $ 2,687

(1) The Company’s gas gathering assets were divested in December 2018 as part of the Fayetteville Shale sale.

(2) Other E&P revenues consists primarily of water sales to third-party operators, and other Midstream revenues consists primarily of sales of gas from storage.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Disaggregation of Revenue on Geographic Basis For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Northeast Appalachia $ 175 $ 254 $ 740 $ 794 Southwest Appalachia 173 235 519 557 Fayetteville Shale — 140 — 431 Other — 4 2 8

Total $ 348 $ 633 $ 1,261 $ 1,790 Reconciliation of Accounts Receivable The following table reconciles the Company’s receivables from contracts with customers to consolidated accounts receivable as presented on the consolidated balance sheet:

(in millions) September 30, 2019 December 31, 2018

Receivables from contracts with customers $ 235 $ 494 Other accounts receivable 88 87

Total accounts receivable $ 323 $ 581

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Reclassifications from 9 Months Ended Accumulated Other Comprehensive Income Sep. 30, 2019 (Loss) (Tables) Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] Components of Accumulated The following tables detail the components of accumulated other comprehensive income and the related tax effects for the nine months ended Other Comprehensive Income September 30, 2019: (Loss) Pension and Other (in millions) Postretirement Foreign Currency Total

Beginning balance December 31, 2018 $ (22) $ (14) $ (36) Other comprehensive income before reclassifications — — — (1) Amounts reclassified from other comprehensive income 5 — 5

Net current-period other comprehensive income 5 — 5

Ending balance September 30, 2019 $ (17) $ (14) $ (31)

(1) See separate table below for details about these reclassifications. Amounts Reclassified from Accumulated Other Details about Accumulated Other Affected Line Item in the Amount Reclassified from Accumulated Other Comprehensive Income (Loss) Comprehensive Income Consolidated Statement of Operations Comprehensive Income For the nine months ended September 30, 2019

(in millions) Pension and other postretirement: (1) Amortization of prior service cost and net loss Other Income, Net $ 7 Provision for income taxes 2

Net income $ 5

Total reclassifications for the period Net income $ 5

?

(1) See Note 15 for additional details regarding the Company’s pension and other postretirement benefit plans.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Pension Plan and Other 9 Months Ended Postretirement Benefits Sep. 30, 2019 (Tables) Retirement Benefits [Abstract] Pension and Other The Company maintains defined pension and other postretirement benefit plans, which cover substantially all of the Company’s employees. Net periodic pension costs Postretirement Benefit Costs include the following components for the three and nine months ended September 30, 2019 and 2018:

Consolidated Statements of For the three months ended September For the nine months ended September Operations Classification of 30, 30, (in millions) Net Periodic Benefit Cost 2019 2018 2019 2018 Service cost General and administrative expenses $ 1 $ 2 $ 5 $ 8 Interest cost Other Income (Loss), Net 2 1 4 4 Expected return on plan assets Other Income (Loss), Net (1) (2) (4) (6) Amortization of prior service cost Other Income (Loss), Net — — — — Amortization of net loss Other Income (Loss), Net — 1 1 1 Settlement loss Other Income (Loss), Net 1 — 5 —

Net periodic benefit cost $ 3 $ 2 $ 11 $ 7

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Earnings Per Share Sep. 30, 2019 Earnings Per Share [Abstract] Earnings Per Share EARNINGS PER SHAREBasic earnings per common share is computed by dividing net income attributable to common stock by the weighted average number of common shares outstanding during the reportable period. The diluted earnings per share calculation adds to the weighted average number of common shares outstanding: the incremental shares that would have been outstanding assuming the exercise of dilutive stock options, the vesting of unvested restricted shares of common stock, performance units and the assumed conversion of mandatory convertible preferred stock. An antidilutive impact is an increase in earnings per share or a reduction in net loss per share resulting from the conversion, exercise or contingent issuance of certain securities.

In January 2015, the Company issued 34,500,000 depositary shares that entitled the holder to a proportional fractional interest in the rights and preferences of the mandatory convertible preferred stock, including conversion, dividend, liquidation and voting rights. The mandatory convertible preferred stock had the non-forfeitable right to participate on an as-converted basis at the conversion rate then in effect in any common stock dividends declared and, therefore, was considered a participating security. Accordingly, it has been included in the computation of basic and diluted earnings per share, pursuant to the two-class method. In the calculation of basic earnings per share attributable to common shareholders, earnings are allocated to participating securities based on actual dividend distributions received plus a proportionate share of undistributed net income attributable to common shareholders, if any, after recognizing distributed earnings. The Company’s participating securities do not participate in undistributed net losses because they are not contractually obligated to do so. On January 12, 2018, all outstanding shares of mandatory convertible preferred stock converted to 74,998,614 shares of the Company’s common stock. The Company paid out its last dividend payment of approximately $27 million associated with the depositary shares in January 2018.

During the second half of 2018, the Company repurchased 39,061,269 shares of its outstanding common stock for approximately $180 million at an average price of $4.63 per share. In the first quarter of 2019, the Company completed its share repurchase program by purchasing 5,260,687 shares of its outstanding common stock for approximately $21 million at an average price of $3.84 per share.

The following table presents the computation of earnings per share for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions, except share/per share amounts) 2019 2018 2019 2018

Net income (loss) $ 49 $ (29) $ 781 $ 230 Participating securities – mandatory convertible preferred stock — — — 1

Net income (loss) attributable to common stock $ 49 $ (29) $ 781 $ 229

Number of common shares: Weighted average outstanding 539,221,101 581,171,753 539,315,170 577,912,421 Issued upon assumed exercise of outstanding stock options — — — — Effect of issuance of non-vested restricted common stock 187,706 — 400,120 640,365 Effect of issuance of non-vested performance units 629,380 — 727,359 1,276,072

Weighted average and potential dilutive outstanding 540,038,187 581,171,753 540,442,649 579,828,858

Earnings per common share Basic $ 0.09 $ (0.05) $ 1.45 $ 0.40

Diluted $ 0.09 $ (0.05) $ 1.44 $ 0.39

The following table presents the common stock shares equivalent excluded from the calculation of diluted earnings per share for the three and nine months ended September 30, 2019 and 2018, as they would have had an antidilutive effect:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the three months ended September For the nine months ended September 30, 30,

2019 2018 2019 2018

Unexercised stock options 5,102,882 717 5,115,334 — Unvested share-based payment 2,136,453 3,463,802 1,797,963 4,246,492 Performance units 240,450 2,000,553 247,443 856,703 Mandatory convertible preferred stock — — — 3,296,642

Total 7,479,785 5,465,072 7,160,740 8,399,837

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Leases Sep. 30, 2019 Leases [Abstract] Leases LEASES

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. The codification was amended through additional ASUs. For public entities, Update 2016-02 became effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company adopted ASC 842 with an effective date of January 1, 2019 using the modified retrospective approach for all leases that existed at the date of initial application. The Company elected to apply the transition as of the beginning of the period of adoption. For leases that existed at the period of adoption on January 1, 2019, the incremental borrowing rate as of the application date was used to calculate the present value of remaining lease payments.

The standard provides optional practical expedients to ease the burden of transition. The Company has adopted the following practical expedients through implementation:

• an election not to apply the recognition requirements in the leases standard to short-term leases and recognize lease payments in the consolidated statement of operations (a lease that at commencement date has an initial term of 12 months or less and does not contain a purchase option that the Company is reasonably certain to exercise);

• a package of practical expedients to not reassess: whether a contract is or contains a lease, lease classification and initial direct costs;

• a practical expedient that permits combining lease and non-lease components in a contract and accounting for the combination as a lease (elected by asset class);

• a practical expedient to not reassess certain land easements in existence prior to January 1, 2019; and

• an election to adopt the modified retrospective approach for all leases existing at or entered into after the initial date of adoption which does not require a restatement of prior period. No cumulative-effect adjustment to retained earnings was required as a result of the modified retrospective approach.

Upon adoption of ASC 842, the Company recognized a discounted right-of-use asset and corresponding lease liability with opening balances of approximately $105 million as of January 1, 2019. The adoption of the standard did not materially change the Company’s consolidated statement of operations or its consolidated statement of cash flows.

The Company determines if a contract contains a lease at inception. A lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment (an identified asset) for a period of time in exchange for consideration. A right-of-use asset and corresponding lease liability are recognized on the balance sheet at commencement at an amount based on the present value of the remaining lease payments over the lease term. As the implicit rate of the lease is not always readily determinable, the Company uses the incremental borrowing rate to calculate the present value of the lease payments based on information available at commencement date. Operating right-of-use assets are included in other long-term assets while operating lease liabilities are included in other current and other long-term liabilities on the consolidated balance sheet. The Company does not have any financing lease type of arrangements as of September 30, 2019. By policy election, leases with an initial term of twelve months or less are not recorded on the balance sheet. The Company recognizes lease expense for these leases on a straight-line basis, and variable lease payments are recognized in the period as incurred.

Certain leases contain both lease and non-lease components. The Company has chosen to account for most of these leases as a single lease component instead of bifurcating lease and non-lease components. However, for compression service leases and fleet vehicle leases, the lease and non-lease components are accounted for separately.

The Company leases drilling rigs, pressure pumping equipment, vehicles, office space, certain water transportation lines, an aircraft and other equipment under non- cancelable operating leases expiring through 2032. Certain lease agreements include options to renew the lease, early terminate the lease or purchase the underlying asset(s). The Company determines the lease term at the lease commencement date as the non-cancelable period of the lease, including options to extend or terminate the lease when such an option is reasonably certain to be exercised. The Company’s water transportation lines are the only leases with renewal options that are reasonably certain to be exercised. These renewal options are reflected in the right-of-use asset and lease liability balances.

In July 2019, the Company terminated its existing lease agreement and entered into a new 10-year lease agreement for a smaller portion of the headquarters office building, which resulted in the Company making a $6 million residual value guarantee short-fall payment to the building’s previous lessor. The net impact to the Company’s right of use asset balance increased $56 million in the third quarter of 2019 as a result of entering into the new lease agreement, which was partially offset

by the early lease termination of the previous lease. The Company’s variable lease costs are primarily comprised of variable operating charges incurred in connection with the new building lease which are expected to continue throughout the lease term. There are currently no material residual value guarantees in the Company’s existing leases.

The components of lease costs are shown below:

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document For the nine months ended (in millions) September 30, 2019 Operating lease cost $ 33 Short-term lease cost 49 Variable lease cost 1

Total lease cost $ 83

As of September 30, 2019, the Company has operating leases of $20 million, related primarily to compressor leases, that have been executed but not yet commenced. These operating leases are planned to commence during 2019 with lease terms expiring through 2023. The Company’s existing operating leases do not contain any material restrictive covenants.

Supplemental cash flow information related to leases is set forth below:

For the nine months ended (in millions) September 30, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 34

Right-of-use assets obtained in exchange for new operating liabilities: Operating leases $ 88

Supplemental balance sheet information related to leases is as follows:

Right-of-use asset balance: (in millions) September 30, 2019 Operating leases $ 164

Lease liability balance: (in millions) Short-term operating leases $ 35 Long-term operating leases 124 Total operating leases $ 159

Weighted average remaining lease term: (years) Operating leases 6.8

Weighted average discount rate: Operating leases 5.54 %

Maturity analysis of operating lease liabilities:

(in millions) September 30, 2019

2019 $ 12 2020 40 2021 31 2022 21 2023 19 2024 15 Thereafter 52 Total undiscounted lease liability 190 Imputed interest (31)

Total discounted lease liability $ 159

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document (in millions) December 31, 2018

2019 $ 38 2020 28 2021 14 2022 6 2023 5 Thereafter 4

Total minimum payments required $ 95

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 3 Months 9 Months Debt (Senior Notes - 1 Months Ended Ended Ended Narrative) (Details) - USD Sep. Dec. Jun. Feb. Jan. Sep. Sep. Sep. Sep. Jul. Jul. ($) 30, 31, 30, 29, 31, 30, 30, 30, 30, 31, 31, $ in Millions 2019 2018 2016 2016 2015 2019 2018 2019 2018 2018 2016 Debt Instrument [Line Items] Repayments of long-term debt $ $ 43 1,191 Gain on extinguishment of debt $ 7 $ 0 $ 7 $ (8) Senior Notes Debt Instrument [Line Items] Repayments of long-term debt $ 900 $ 43 Gain on extinguishment of debt $ 7 Senior Notes | LIBOR Debt Instrument [Line Items] Incremental increase in basis points resulting from 0.25% downgrades Incremental decrease in basis 0.25% points resulting from upgrades Increase in basis spread 1.75% 1.75% 4.05% Senior Notes due January 2020 | Long-term debt Debt Instrument [Line Items] Senior notes $ 850 Stated interest rate 6.05% 4.05% 6.05% 6.05% 5.30% 5.80% 4.05% Senior Notes due January 2020 | Senior Notes Debt Instrument [Line Items] Stated interest rate 4.05% 4.05% 4.05% 4.05% 4.95% Senior Notes due January 2025 | Long-term debt Debt Instrument [Line Items] Senior notes $ 1,000 Stated interest rate 6.95% 4.95% 6.95% 6.95% 6.20% 6.70% 4.95% Senior Notes due January 2025 | Senior Notes Debt Instrument [Line Items] Stated interest rate 4.95% 4.95% 4.95% 4.95% Repurchased amount $ 31 $ 31 $ 31 7.50% Senior Notes due 2025 | Senior Notes Debt Instrument [Line Items] Stated interest rate 7.50% 7.50% 7.50% 7.50%

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Repurchased amount $ 11 $ 11 $ 11 7.75% Senior Notes due 2026 | Senior Notes Debt Instrument [Line Items] Stated interest rate 7.75% 7.75% 7.75% 7.75% Repurchased amount $ 8 $ 8 $ 8

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Summary of Equity- Classified Restricted Stock Sep. 30, 2019 Activity) (Details) - $ / shares Restricted stock shares shares in Thousands Number of Shares Beginning balance (in shares) | shares 2,717 Granted (in shares) | shares 477 Vested (in shares) | shares (1,101) Forfeited (in shares) | shares (210) Ending balance (in shares) | shares 1,883 Weighted Average Fair Value Beginning balance (in dollars per share) | $ / shares $ 7.91 Granted (in dollars per share) | $ / shares 3.09 Vested (in dollars per share) | $ / shares 7.02 Forfeited (in dollars per share) | $ / shares 8.38 Ending balance (in dollars per share) | $ / shares $ 7.17

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Stock-Based Compensation 9 Months Ended (Summary of Liability- Classified Performance Unit Sep. 30, 2019 Activity) (Details) - $ / shares Performance units shares shares in Thousands Number of Shares Beginning balance (in shares) | shares 2,803 Granted (in shares) | shares 2,757 Vested (in shares) | shares 0 Forfeited (in shares) | shares (119) Ending balance (in shares) | shares 5,441 Weighted Average Fair Value Beginning balance (in dollars per share) | $ / shares $ 3.41 Granted (in dollars per share) | $ / shares 4.34 Vested (in dollars per share) | $ / shares 0 Forfeited (in dollars per share) | $ / shares 4.65 Ending balance (in dollars per share) | $ / shares $ 1.93

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Pension Plan and Other 3 Months Ended 9 Months Ended Postretirement Benefits (Pension and Other Postretirement Benefit Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 Costs) (Details) - Pension - USD ($) $ in Millions Defined Benefit Plan Disclosure [Line Items] Service cost $ 1 $ 2 $ 5 $ 8 Interest cost 2 1 4 4 Expected return on plan assets (1) (2) (4) (6) Amortization of prior service cost 0 0 0 0 Amortization of net loss 0 1 1 1 Settlement loss 1 0 5 0 Net periodic benefit cost $ 3 $ 2 $ 11 $ 7

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Earnings Per Share 3 Months 6 Months 1 Months Ended (Narrative) (Details) - USD Ended Ended ($) Jan. Sep. Dec. 31, Jan. 31, Mar. 31, Dec. 31, Jan. 12, $ / shares in Units, $ in 31, 30, 2018 2015 2019 2018 2018 Millions 2018 2018 Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items] Treasury stock acquired (in shares) 44,000,000 5,260,687 39,061,269 Treasury stock acquired $ 201 $ 21 $ 25 $ 180 Treasury stock acquired, average cost per $ 3.84 $ 4.63 share (in dollars per share) Depositary Shares Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items] Shares issued (in shares) 34,500,000 Dividend payment $ 27 Common Stock Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items] Shares issued upon conversion (in shares) 74,998,614

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Revenue Recognition 3 Months Ended 9 Months Ended (Disaggregation of Revenue on Geographic Basis) Sep. 30, 2019Sep. 30, 2018Sep. 30, 2019Sep. 30, 2018 (Details) - USD ($) $ in Millions Disaggregation of Revenue [Line Items] Total operating revenues $ 636 $ 951 $ 2,293 $ 2,687 E&P Disaggregation of Revenue [Line Items] Total operating revenues 357 639 1,288 1,809 Operating Segments | E&P Disaggregation of Revenue [Line Items] Total operating revenues 348 633 1,261 1,790 Operating Segments | E&P | Northeast Appalachia Disaggregation of Revenue [Line Items] Total operating revenues 175 254 740 794 Operating Segments | E&P | Southwest Appalachia Disaggregation of Revenue [Line Items] Total operating revenues 173 235 519 557 Operating Segments | E&P | Fayetteville Shale Disaggregation of Revenue [Line Items] Total operating revenues 0 140 0 431 Operating Segments | E&P | Other Disaggregation of Revenue [Line Items] Total operating revenues $ 0 $ 4 $ 2 $ 8

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Leases (Supplemental 9 Months Ended Information) (Details) Sep. 30, 2019 $ in Millions USD ($) Leases [Abstract] Operating cash flows from operating leases $ 34 Right-of use assets obtained in exchange for new operating liabilities 88 Right-of-use asset 164 Lease liability balance: (in millions) Short-term operating leases 35 Long-term operating leases 124 Total operating leases $ 159 Weighted average remaining lease term 6 years 9 months 18 days Weighted average discount rate 5.54%

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Reclassifications from 9 Months 3 Months Ended Accumulated Other Ended Comprehensive Income (Loss) (Amounts Reclassified Sep. Jun. Mar. Sep. Jun. Mar. Sep. Sep. from Accumulated Other 30, 30, 31, 30, 30, 31, 30, 30, Comprehensive Income 2019 2019 2019 2018 2018 2018 2019 2018 (Loss)) (Details) - USD ($) $ in Millions Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] Other Income, Net $ $ (2) $ (7) $ 1 (1) Provision for income taxes 10 0 (401) 0 Net income $ $ $ 49 $ 138 $ 594 [1] $ 51 $ 208 781 [1] (29) 230 Amount Reclassified from Accumulated Other Comprehensive Income Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] Net income 5 Amortization of prior service cost and net loss | Amount Reclassified from Accumulated Other Comprehensive Income Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] Other Income, Net 7 Provision for income taxes 2 Net income $ 5 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Condensed Consolidating 9 Months Ended Financial Information (Condensed Consolidating Statements of Cash Flows) Sep. 30, 2019Sep. 30, 2018 (Details) - USD ($) $ in Millions Condensed Cash Flow Statements, Captions [Line Items] Net cash provided by (used in) operating activities $ 739 $ 971 Investing activities: Capital investments (877) (1,008) Proceeds from sale of property and equipment 42 9 Other 0 4 Net cash used in investing activities (835) (995) Financing activities: Intercompany activities 0 0 Payments on long-term debt (43) (1,191) Payments on revolving credit facility 0 (1,122) Borrowings under revolving credit facility 0 1,482 Change in bank drafts outstanding (11) 10 Debt issuance costs 0 (9) Purchase of treasury stock (21) (25) Preferred stock dividend 0 (27) Cash paid for tax withholding (1) (1) Net cash used in financing activities (76) (883) Decrease in cash and cash equivalents (172) (907) Cash and cash equivalents at beginning of year 201 916 Cash and cash equivalents at end of period 29 9 Parent Condensed Cash Flow Statements, Captions [Line Items] Net cash provided by (used in) operating activities 1,154 57 Investing activities: Capital investments 0 (12) Proceeds from sale of property and equipment 0 0 Other 4 Net cash used in investing activities 0 (8) Financing activities: Intercompany activities (1,250) (71) Payments on long-term debt (43) (1,191) Payments on revolving credit facility (1,122) Borrowings under revolving credit facility 1,482 Change in bank drafts outstanding (11) 10 Debt issuance costs (9) Purchase of treasury stock (21) (25) Preferred stock dividend (27)

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Cash paid for tax withholding (1) (1) Net cash used in financing activities (1,326) (954) Decrease in cash and cash equivalents (172) (905) Cash and cash equivalents at beginning of year 201 914 Cash and cash equivalents at end of period 29 9 Guarantors Condensed Cash Flow Statements, Captions [Line Items] Net cash provided by (used in) operating activities 404 1,396 Investing activities: Capital investments (875) (996) Proceeds from sale of property and equipment 42 9 Other 0 Net cash used in investing activities (833) (987) Financing activities: Intercompany activities 429 (411) Payments on long-term debt 0 0 Payments on revolving credit facility 0 Borrowings under revolving credit facility 0 Change in bank drafts outstanding 0 0 Debt issuance costs 0 Purchase of treasury stock 0 0 Preferred stock dividend 0 Cash paid for tax withholding 0 0 Net cash used in financing activities 429 (411) Decrease in cash and cash equivalents 0 (2) Cash and cash equivalents at beginning of year 0 2 Cash and cash equivalents at end of period 0 0 Non-Guarantors Condensed Cash Flow Statements, Captions [Line Items] Net cash provided by (used in) operating activities 0 0 Investing activities: Capital investments (2) 0 Proceeds from sale of property and equipment 0 0 Other 0 Net cash used in investing activities (2) 0 Financing activities: Intercompany activities 2 0 Payments on long-term debt 0 0 Payments on revolving credit facility 0 Borrowings under revolving credit facility 0 Change in bank drafts outstanding 0 0 Debt issuance costs 0 Purchase of treasury stock 0 0 Preferred stock dividend 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Cash paid for tax withholding 0 0 Net cash used in financing activities 2 0 Decrease in cash and cash equivalents 0 0 Cash and cash equivalents at beginning of year 0 0 Cash and cash equivalents at end of period 0 0 Eliminations Condensed Cash Flow Statements, Captions [Line Items] Net cash provided by (used in) operating activities (819) (482) Investing activities: Capital investments 0 0 Proceeds from sale of property and equipment 0 Other 0 Net cash used in investing activities 0 0 Financing activities: Intercompany activities 819 482 Payments on long-term debt 0 0 Payments on revolving credit facility 0 Borrowings under revolving credit facility 0 Change in bank drafts outstanding 0 0 Debt issuance costs 0 Purchase of treasury stock 0 0 Preferred stock dividend 0 Cash paid for tax withholding 0 0 Net cash used in financing activities 819 482 Decrease in cash and cash equivalents 0 0 Cash and cash equivalents at beginning of year 0 0 Cash and cash equivalents at end of period $ 0 $ 0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Derivatives and Risk Management (Narrative) Sep. 30, 2019Dec. 31, 2018 (Details) - USD ($) $ in Millions Commodities Derivative [Line Items] Derivative assets $ 169 Interest rate swaps Derivative [Line Items] Derivative assets $ 1 Not Designated as Hedging Instrument | Interest rate swaps Derivative [Line Items] Notional amount $ 170

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Segment Information 9 Months Ended (Tables) Sep. 30, 2019 Segment Reporting [Abstract] Summary of Financial Information for Company's Summarized financial information for the Company’s reportable segments is shown in the following table. The accounting policies of the segments are the same as Reportable Segments those described in Note 1 of the Notes to Consolidated Financial Statements included in Item 8 of the 2018 Annual Report. Management evaluates the performance of its segments based on operating income, defined as operating revenues less operating costs. Income before income taxes, for the purpose of reconciling the operating income amount shown below to consolidated income before income taxes, is the sum of operating income, interest expense, gain (loss) on derivatives and other income (loss). The “Other” column includes items not related to the Company’s reportable segments, including real estate and corporate items.

E&P Midstream Other Total

Three months ended September 30, 2019 (in millions) Revenues from external customers $ 357 $ 279 $ — $ 636 Intersegment revenues (9) 313 — 304 Depreciation, depletion and amortization expense 123 2 — 125 Impairments — 2 — 2 (1) Operating loss (21) (8) — (29) (2) Interest expense 17 — — 17 Gain on derivatives 100 — — 100 Gain on extinguishment of debt — — 7 7 Other income (loss), net (4) — 2 (2) (2) Provision for income taxes 10 — — 10 (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 239 — 1 240

Three months ended September 30, 2018 Revenues from external customers $ 639 $ 312 $ — $ 951 Intersegment revenues (6) 600 — 594 Depreciation, depletion and amortization expense 140 11 — 151 Impairments 15 145 1 161 (6) (1) Operating income (loss) 175 (108) (1) 66 (2) Interest expense 29 — — 29 Loss on derivatives (65) — — (65) Other loss, net — (1) — (1) (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 295 — 3 298

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document E&P Midstream Other Total

Nine months ended September 30, 2019 (in millions) Revenues from external customers $ 1,288 $ 1,005 $ — $ 2,293 Intersegment revenues (27) 1,154 — 1,127 Depreciation, depletion and amortization expense 345 7 — 352 Impairments 6 2 — 8 (1) Operating income (loss) 219 (13) — 206 (2) Interest expense 46 — — 46 Gain on derivatives 220 — — 220 Gain on early extinguishment of debt — — 7 7 Other income (loss), net (8) — 1 (7) (2) Benefit from income taxes (401) — — (401) (3) (4) Assets 6,099 272 227 6,598 (5) Capital investments 931 — 2 933

Nine months ended September 30, 2018 Revenues from external customers $ 1,809 $ 878 $ — $ 2,687 Intersegment revenues (19) 1,727 — 1,708 Depreciation, depletion and amortization expense 383 43 — 426 (8) Impairments 15 155 1 171 (6) (1) (9) Operating income (loss) 510 (64) (1) 445 (2) Interest expense 100 — — 100 Loss on derivatives (108) — — (108) Loss on early extinguishment of debt — — (8) (8) Other income (loss), net 3 (2) — 1 (3) (7) (4) Assets 5,732 1,115 211 7,058 (5) Capital investments 1,025 9 5 1,039

(1) Operating income for the E&P segment includes $4 million and $2 million of restructuring charges for the three months ended September 30, 2019 and 2018, respectively, and $9 million and $18 million of restructuring charges for the nine months ended September 30, 2019 and 2018, respectively.

(2) Interest expense and provision (benefit) for income taxes by segment is an allocation of corporate amounts as they are incurred at the corporate level.

(3) E&P assets includes office, technology, water infrastructure, drilling rigs and other ancillary equipment not directly related to natural gas and oil properties. This also includes deferred tax assets which are an allocation of corporate amounts as they are incurred at the corporate level. At September 30, 2018, E&P assets included $106 million of assets held for sale.

(4) Other assets represent corporate assets not allocated to segments and assets for non-reportable segments. At September 30, 2019 and 2018, other assets included approximately $29 million and $9 million, respectively, in cash and cash equivalents, $61 million and $89 million, respectively, in income taxes receivable, $31 million and $69 million, respectively, in property, plant and equipment, $9 million and $12 million, respectively, in unamortized debt expense, $7 million and $12 million, respectively, in prepayments and $7 million and $8 million, respectively, in a non-qualified retirement plan. Additionally, the September 30, 2019 asset balance includes $84 million in right-of-use lease assets.

(5) Capital investments include decreases of $53 million and $31 million for the three months ended September 30, 2019 and 2018, respectively, and increases of $52 million and $21 million for the nine months ended September 30, 2019 and 2018, respectively, relating to the change in accrued expenditures between years.

(6) Includes the impact of Fayetteville Shale-related E&P and Midstream operations which were divested on December 3, 2018.

(7) Midstream assets includes $738 million of assets held for sale at September 30, 2018.

(8) Includes a $10 million impairment related to certain non-core gathering assets.

(9) Operating loss for the Midstream segment includes a $10 million impairment related to certain non-core gathering assets and $2 million related to restructuring charges for the nine months ended September 30, 2018.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Restructuring Charges 3 Months Ended 9 Months Ended (Summary of Restructuring Sep. 30, Sep. 30, Sep. 30, Sep. 30, Jul. 31, Dec. 31, Charges) (Details) - USD ($) 2019 2018 2019 2018 2019 2018 $ in Millions Restructuring Cost and Reserve [Line Items] Term of contract 10 years Total restructuring charges $ 4.0 $ 2.0 $ 9.0 $ 20.0 E&P Restructuring Cost and Reserve [Line Items] Total restructuring charges 4.0 2.0 9.0 18.0 Midstream Restructuring Cost and Reserve [Line Items] Total restructuring charges 2.0 Workforce Reduction Restructuring Cost and Reserve [Line Items] Restructuring liability 1.0 1.0 $ 5.0 Severance (including payroll taxes) 1.0 1.0 4.0 18.0 Office consolidation 3.0 0.0 5.0 0.0 Professional fees 0.0 1.0 0.0 2.0 Total restructuring charges 4.0 2.0 9.0 20.0 Workforce Reduction | E&P Restructuring Cost and Reserve [Line Items] Total restructuring charges $ 4.0 $ 2.0 $ 9.0 18.0 Workforce Reduction | Midstream Restructuring Cost and Reserve [Line Items] Total restructuring charges $ 2.0

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Leases (Narrative) (Details) Sep. 30, 2019 $ in Millions USD ($) Leases [Abstract] Operating leases not yet commenced (less than) $ 20

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document New Accounting 9 Months Ended Pronouncements (Policies) Sep. 30, 2019 Accounting Policies [Abstract] New Accounting Standards Implemented/New Accounting New Accounting Standards Implemented Standards Not Yet In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases Implemented (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. The codification was amended through additional ASUs. For public entities, Update 2016-02 became effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company adopted ASC 842 with an effective date of January 1, 2019 using the modified retrospective approach for all leases that existed at the date of initial application. The Company elected to apply the transition as of the beginning of the period of adoption. For leases that existed at the period of adoption on January 1, 2019, the incremental borrowing rate as of the application date was used to calculate the present value of remaining lease payments. Upon adoption of ASC 842, the Company recognized a discounted right-of-use asset and corresponding lease liability with opening balances of approximately $105 million as of January 1, 2019. The adoption of the standard did not materially change the Company’s consolidated statement of operations or its consolidated statement of cash flows. Please refer to Note 4 – “Leases” for full disclosure.

New Accounting Standards Not Yet Implemented

In June 2016, the FASB issued Accounting Standards Update No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“Update 2016-13”). Update 2016-13 replaces the incurred loss model with an expected loss model, which is referred to as the current expected credit loss (“CECL”) model. The CECL model is applicable to the measurement of credit losses on financial assets measured at amortized cost, including but not limited to trade receivables.

From evaluation of the Company’s current credit portfolio, which includes trade receivables from commodity sales, joint interest billings due from partners and other receivables, historical credit losses have been de minimis. The Company believes that its expected future credit losses will not be significant, and therefore Southwestern does not believe the adoption of the standard will have a material impact on its consolidated financial statements. The Company will continue to monitor changes in its credit portfolio as evaluation progresses. For public business entities, the new standard is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Stock-Based Compensation Sep. 30, 2019 Share-based Compensation [Abstract] Stock-Based Compensation STOCK-BASED COMPENSATION

The Company recognized the following amounts in total employee stock-based compensation costs for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Stock-based compensation cost – expensed $ 1 $ 7 $ 12 $ 20 Stock-based compensation cost – capitalized 1 3 7 10

The Company’s stock-based compensation is classified as either equity awards or liability awards in accordance with GAAP. The fair value of an equity-classified award is determined at the grant date and is amortized to general and administrative expense and capitalized expense on a straight-line basis over the vesting period of the award. The fair value of a liability-classified award is determined on a quarterly basis beginning at the grant date until final vesting. Changes in the fair value of liability- classified awards are recorded to general and administrative expense over the vesting period of the award. A portion of this general and administrative expense is capitalized into natural gas and oil properties, included in property and equipment. Generally, stock options granted to employees and directors vest ratably over three years from the grant date and expire seven years from the date of grant. The Company issues shares of restricted stock or restricted stock units to employees and directors which generally vest over four years. Restricted stock, restricted stock units and stock options granted to participants under the 2013 Incentive Plan, as amended and restated, immediately vest upon death, disability or retirement (subject to a minimum of three years of service). The Company issues performance unit awards to employees which historically have vested at or over three years.

In December 2018, the Company closed the sale of the equity in certain of its subsidiaries that owned and operated its Fayetteville Shale E&P and related midstream gathering assets in Arkansas. As part of this transaction, most employees associated with those assets became employees of the buyer although the employment of some was terminated. All affected employees were offered a severance package, which included a one-time cash payment depending on length of service and, if applicable, the current value of a portion of equity awards that were forfeited. Stock-based compensation costs recognized prior to the cancellation as either general and administrative expense or capitalized expense were reversed and the severance payments were subsequently recognized as restructuring charges for the year ended December 31, 2018 and the nine months ended September 30, 2019 on the consolidated statements of operations.

Equity-Classified Awards

The Company recognized the following amounts in employee equity-classified stock-based compensation costs for the three and nine months ended September 30, 2019 and 2018:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Equity-classified awards – expensed $ 2 $ 3 $ 6 $ 12 Equity-classified awards – capitalized 1 2 3 6

As of September 30, 2019, there was $9 million of total unrecognized compensation cost related to the Company’s unvested equity-classified stock option grants, equity- classified restricted stock grants and equity-classified performance units. This cost is expected to be recognized over a weighted-average period of 1.1 years.

Equity-Classified Stock Options

The following table summarizes equity-classified stock option activity for the nine months ended September 30, 2019 and provides information for options outstanding and options exercisable as of September 30, 2019:

Number Weighted Average of Options Exercise Price

(in thousands) Outstanding at December 31, 2018 5,178 $ 17.06 Granted — $ — Exercised — $ — Forfeited or expired (76) $ 19.38

Outstanding at September 30, 2019 5,102 $ 17.02

Exercisable at September 30, 2019 4,680 $ 17.85

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Equity-Classified Restricted Stock

The following table summarizes equity-classified restricted stock activity for the nine months ended September 30, 2019 and provides information for unvested shares as of September 30, 2019:

Number Weighted Average of Shares Fair Value

(in thousands) Unvested shares at December 31, 2018 2,717 $ 7.91 Granted 477 $ 3.09 Vested (1,101) $ 7.02 Forfeited (210) $ 8.38

Unvested shares at September 30, 2019 1,883 $ 7.17

Equity-Classified Performance Units

The following table summarizes equity-classified performance unit activity for the nine months ended September 30, 2019 and provides information for unvested units as of September 30, 2019. The performance unit awards granted in 2017 include a market condition based exclusively on the fair value of the Total Shareholder Return (“TSR”), as calculated by a Monte Carlo model. The total fair value of the performance units is amortized to compensation expense on a straight line basis over the vesting period of the award. The grant date fair value is calculated using the closing price of the Company’s common stock at the grant date.

Number Weighted Average (1) of Shares Fair Value

(in thousands) Unvested units at December 31, 2018 598 $ 10.01 Granted — $ — Vested (371) $ 9.73 Forfeited (30) $ 10.47

Unvested units at September 30, 2019 197 $ 10.47

(1) The actual payout of shares may range from a minimum of zero shares to a maximum of two shares per unit contingent upon TSR. The performance units have a three-year vesting term and the actual disbursement of shares, if any, is determined during the first quarter following the end of the three-year vesting period.

Liability-Classified Awards

The Company recognized the following amounts in employee liability-classified stock-based compensation costs for the three and nine months ended September 30, 2019:

For the three months ended September For the nine months ended September 30, 30,

(in millions) 2019 2018 2019 2018

Liability-classified stock-based compensation cost – expensed $ (1) $ 4 $ 6 $ 8 Liability-classified stock-based compensation cost – capitalized — 1 4 4

Liability-Classified Restricted Stock Units

In the first quarter of 2019 and 2018, the Company granted restricted stock units that vest over a period of four years and are payable in either cash or shares at the option of the Compensation Committee of the Company’s Board of Directors. The Company has accounted for these as liability-classified awards, and accordingly changes in the market value of the instruments will be recorded to general and administrative expense and capitalized expense over the vesting period of the award. As of September 30, 2019, there was $22 million of total unrecognized compensation cost related to liability-classified restricted stock units that is expected to be recognized over a weighted- average period of 3.0 years. The amount of unrecognized compensation cost for liability-classified awards will fluctuate over time as they are marked to market.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Number Weighted Average of Units Fair Value

(in thousands) Unvested shares at December 31, 2018 8,202 $ 3.41 Granted 8,659 $ 4.34 Vested (2,624) $ 4.09 Forfeited (1,000) $ 2.51

Unvested units at September 30, 2019 13,237 $ 1.93

Liability-Classified Performance Units

In 2019 and 2018, the Company granted performance units that vest at the end of, or over, a three-year period and are payable in either cash or shares at the option of the Compensation Committee of the Company’s Board of Directors. The Company has accounted for these as liability-classified awards, and accordingly changes in the fair market value of the instruments will be recorded to general and administrative expense and capitalized expense over the vesting period of the awards. The performance unit awards granted in 2018 include a performance condition based on cash flow per debt-adjusted share and two market conditions, one based on absolute TSR and the other on relative TSR as compared to a group of the Company’s peers. The performance unit awards granted in 2019 include a performance condition based on return on average capital employed and two market conditions, one based on absolute TSR and the other on relative TSR. The fair values of the two market conditions are calculated by Monte Carlo models on a quarterly basis. As of September 30, 2019, there was $7 million of total unrecognized compensation cost related to liability-classified performance units. This cost is expected to be recognized over a weighted-average period of 2.2 years. The amount of unrecognized compensation cost for liability-classified awards will fluctuate over time as they are marked to market. The final value of the performance unit awards is contingent upon the Company’s actual performance against these performance measures.

Number Weighted Average of Shares Fair Value

(in thousands) Unvested shares at December 31, 2018 2,803 $ 3.41 Granted 2,757 $ 4.34 Vested — $ — Forfeited (119) $ 4.65

Unvested units at September 30, 2019 5,441 $ 1.93

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document 9 Months Ended Debt Sep. 30, 2019 Debt Disclosure [Abstract] Debt DEBT

The components of debt as of September 30, 2019 and December 31, 2018 consisted of the following:

September 30, 2019

Unamortized Issuance Unamortized Debt (in millions) Debt Instrument Expense Discount Total Current portion of long-term debt: (1) 4.05% Senior Notes due January 2020 $ 52 $ — $ — $ 52

Total current portion of long-term debt $ 52 $ — $ — $ 52

Long-term debt: (2) Variable rate (3.420% at September 30, 2019) 2018 revolving credit $ — $ — $ — $ — facility, due April 2023 4.10% Senior Notes due March 2022 213 (1) — 212 (1)(3) 4.95% Senior Notes due January 2025 896 (7) (1) 888 (3) 7.50% Senior Notes due April 2026 639 (7) — 632 (3) 7.75% Senior Notes due October 2027 492 (5) — 487

Total long-term debt $ 2,240 $ (20) $ (1) $ 2,219

Total debt $ 2,292 $ (20) $ (1) $ 2,271

December 31, 2018

Unamortized Issuance Unamortized Debt (in millions) Debt Instrument Expense Discount Total Long-term debt: (2) Variable rate (3.920% at December 31, 2018) 2018 term loan facility, due $ — $ — $ — $ — April 2023 (1) 4.05% Senior Notes due January 2020 52 — — 52 4.10% Senior Notes due March 2022 213 (1) — 212 (1) 4.95% Senior Notes due January 2025 927 (7) (1) 919 7.50% Senior Notes due April 2026 650 (8) — 642 7.75% Senior Notes due October 2027 500 (7) — 493

Total long-term debt $ 2,342 $ (23) $ (1) $ 2,318

(1) In February and June 2016, Moody’s and S&P downgraded certain senior notes, increasing the interest rates by 175 basis points effective July 2016. As a result of the downgrades, interest rates increased to 5.80% for the 2020 Notes and 6.70% for the 2025 Notes. S&P and Moody’s upgraded certain senior notes in April and May 2018, respectively. As a result of these upgrades, interest rates decreased to 5.30% for the 2020 Notes and 6.20% for the 2025 Notes effective July 2018. The first coupon payment to the bondholders at the lower interest rate was paid in January 2019.

(2) At September 30, 2019 and December 31, 2018, unamortized issuance expense of $9 million and $12 million, respectively, associated with the 2018 revolving credit facility is classified as other long-term assets on the consolidated balance sheets.

(3) During the third quarter of 2019, the Company purchased $31 million in 2025 Notes, $11 million in 2026 Notes and $8 million in 2027 Notes for $43 million in cash, reducing the Company’s outstanding debt by $50 million. This resulted in a gain on early extinguishment of debt of $7 million for the three and nine months ended September 30, 2019.

Credit Facilities

2018 Revolving Credit Facility

In April 2018, the Company replaced its 2016 credit facility (which consisted of a $1,191 million secured term loan and an unsecured $743 million revolving credit facility) with a new revolving credit facility (the “2018 credit facility”). Concurrent with the closing of the 2018 credit facility agreement on April 26, 2018, the Company repaid the $1,191 million secured term loan balance and recognized a loss on early debt extinguishment of $8 million on the consolidated income statement related to the unamortized issuance expense. In addition, approximately $4 million of unamortized issuance expense associated with the closed $743 million revolving credit facility was carried forward into the unamortized issuance expenses of the 2018 credit facility.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document The 2018 credit facility has an aggregate maximum revolving credit amount of $3.5 billion with a current aggregate commitment of $2.0 billion and a borrowing base (limit on availability) that is redetermined each April and October. The 2018 credit facility is secured by substantially all of the assets owned by the Company and its subsidiaries. The permitted lien provisions in the senior note indentures currently limit liens securing indebtedness to the greater of $2.0 billion and 25% of adjusted consolidated net tangible assets. On October 8, 2019, the Company entered into an amendment to the 2018 credit facility that, among other things, established the October 2019 borrowing base at $2.1 billion and extended the maturity date to April 2024.

Loans under the 2018 credit facility are subject to varying rates of interest based on whether the loan is a Eurodollar loan or an alternate base rate loan. Eurodollar loans bear interest at the Eurodollar rate, which is adjusted LIBOR for such interest period plus the applicable margin (as those terms are defined in the 2018 credit facility documentation). The applicable margin for Eurodollar loans under the 2018 credit facility ranges from 1.50% to 2.50% based on the Company’s utilization of the borrowing base under the 2018 credit facility. Alternate base rate loans bear interest at the alternate base rate plus the applicable margin. The applicable margin for alternate base rate loans under the 2018 credit facility ranges from 0.50% to 1.50% based on the Company’s utilization of the borrowing base under the 2018 credit facility.

The 2018 credit facility contains customary representations and warranties and contains covenants including, among others, the following:

• a prohibition against incurring debt, subject to permitted exceptions;

• a restriction on creating liens on assets, subject to permitted exceptions;

• restrictions on mergers and asset dispositions;

• restrictions on use of proceeds, investments, transactions with affiliates, or change of principal business; and

• maintenance of the following financial covenants, commencing with the fiscal quarter ending June 30, 2018:

1. Minimum current ratio of no less than 1.00 to 1.00, whereby current ratio is defined as the Company’s consolidated current assets (including unused commitments under the credit agreement, but excluding non-cash derivative assets) to consolidated current liabilities (excluding non-cash derivative obligations and current maturities of long-term debt).

2. Maximum total net leverage ratio of no greater than (i) with respect to each fiscal quarter ending during the period from June 30, 2018 through March 31, 2019, 4.50 to 1.00, (ii) with respect to each fiscal quarter ending during the period from June 30, 2019 through March 31, 2020, 4.25 to 1.00, and (iii) with respect to each fiscal quarter ending on or after June 30, 2020, 4.00 to 1.00. Total net leverage ratio is defined as total debt less cash on hand (up to the lesser of 10% of credit limit or $150 million) divided by consolidated EBITDAX for the last four consecutive quarters. EBITDAX, as defined in the Company’s 2018 credit agreement, excludes the effects of interest expense, depreciation, depletion and amortization, income tax, any non-cash impacts from impairments, certain non- cash hedging activities, stock-based compensation expense, non-cash gains or losses on asset sales, unamortized issuance cost, unamortized debt discount and certain restructuring costs.

The 2018 credit facility contains customary events of default that include, among other things, the failure to comply with the financial covenants described above, non-payment of principal, interest or fees, violation of covenants, inaccuracy of representations and warranties, bankruptcy and insolvency events, material judgments and cross-defaults to material indebtedness. If an event of default occurs and is continuing, all amounts outstanding under the 2018 credit facility may become immediately due and payable. As of September 30, 2019, the Company was in compliance with all of the covenants of the credit agreement.

Each United States domestic subsidiary of the Company for which the Company owns 100% guarantees the 2018 credit facility. Pursuant to requirements under the indentures governing its senior notes, each subsidiary that became a guarantor of the 2018 credit facility also became a guarantor of each of the Company’s senior notes. See Note 19 for the Company’s Condensed Consolidated Financial Information, presented in accordance with Rule 3-10 of Regulation S-X.

As of September 30, 2019, the Company had $172 million in letters of credit and no borrowings outstanding under the 2018 revolving credit facility.

Senior Notes

In January 2015, the Company completed a public offering of $850 million aggregate principal amount of its 4.05% senior notes due 2020 (the “2020 Notes”) and $1.0 billion aggregate principal amount of its 4.95% senior notes due 2025 (the “2025 Notes” together with the 2020 Notes, the “Notes”). The interest rates on the Notes are determined based upon the public bond ratings from Moody’s and S&P. Downgrades on the Notes from either rating agency increase interest costs by 25 basis points per downgrade level and upgrades decrease interest costs by 25 basis points per upgrade level, up to the stated coupon rate, on the following semi-annual bond interest payment. In February and June 2016, Moody’s and S&P downgraded the Notes, increasing the interest rates by 175 basis points effective July 2016. As a result of these downgrades, interest rates increased to 5.80% for the 2020 Notes and 6.70% for the 2025 Notes. In the event of future downgrades, the coupons for this series of notes are capped at 6.05% and 6.95%, respectively. The first coupon payment to the bondholders at the higher interest rates was paid in January 2017. S&P and Moody’s upgraded the Notes in April and May 2018, respectively. As a result of these upgrades, interest rates decreased to 5.30% for the 2020 Notes and 6.20% for the 2025 Notes effective July 2018. The first coupon payment to the bondholders at the lower interest rates was paid in January 2019.

In the third quarter of 2019, the Company repurchased $31 million of its 4.95% Senior Notes due 2025, $11 million of its 7.50% Senior Notes due 2025 and $8 million of its 7.75% Senior Notes due 2026 for $43 million, and recognized a $7 million gain on the extinguishment of debt.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED BALANCE SHEETS Sep. 30, 2019 Dec. 31, 2018 (Parenthetical) - USD ($) $ in Millions Statement of Financial Position [Abstract] Natural gas and oil properties, using the full cost method, costs excluded from $ 1,518 $ 1,755 amortization Common stock, par value (in dollars per shares) $ 0.01 $ 0.01 Common stock, shares authorized (in shares) 1,250,000,0001,250,000,000 Common stock, shares issued (in shares) 585,637,420 585,407,107 Treasury stock, shares (in shares) 44,353,224 39,092,537

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document CONSOLIDATED 3 Months Ended 9 Months Ended STATEMENTS OF Sep. 30, Sep. 30, OPERATIONS - USD ($) Sep. 30, 2018 Sep. 30, 2018 2019 2019 $ in Millions Operating Revenues: Total operating revenues $ 636 $ 951 $ 2,293 $ 2,687 Operating Costs and Expenses: Operating expenses 189 206 523 588 General and administrative expenses 42 51 119 165 Loss on sale of operating assets 0 0 3 0 Restructuring charges 4 2 9 20 Depreciation, depletion and amortization 125 151 352 426 Impairments 2 161 8 171 Taxes, other than income taxes 15 26 51 64 Total operating costs and expense 665 885 2,087 2,242 Operating Income (Loss) (29) 66 206 445 Interest Expense: Interest on debt 42 56 125 180 Other interest charges 2 2 5 6 Interest capitalized (27) (29) (84) (86) Total Interest Expense 17 29 46 100 Gain (Loss) on Derivatives 100 (65) 220 (108) Gain (Loss) on Early Extinguishment of Debt 7 0 7 (8) Other Income (Loss), Net (2) (1) (7) 1 Income (Loss) Before Income Taxes 59 (29) 380 230 Provision (Benefit) for Income Taxes Current (1) 0 (1) 0 Deferred 11 0 (400) 0 Total Provision (Benefit) from Income Taxes 10 0 (401) 0 Net Income (Loss) 49 (29) [1] 781 230 [1] Participating securities – mandatory convertible 0 0 0 1 preferred stock Net Income (Loss) Attributable to Common Stock $ 49 $ (29) $ 781 $ 229 Earnings (Loss) Per Common Share Basic (in dollars per share) $ 0.09 $ (0.05) $ 1.45 $ 0.40 Diluted (in dollars per share) $ 0.09 $ (0.05) $ 1.44 $ 0.39 Weighted Average Common Shares Outstanding: Basic (in shares) 539,221,101581,171,753 539,315,170577,912,421 Diluted (in shares) 540,038,187581,171,753 540,442,649579,828,858 Gas sales Operating Revenues: Total operating revenues $ 238 $ 465 $ 943 $ 1,412 Oil sales

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document Operating Revenues: Total operating revenues 67 62 153 141 NGL sales Operating Revenues: Total operating revenues 52 112 191 252 Marketing Operating Revenues: Total operating revenues 279 287 1,004 805 Gas gathering Operating Revenues: Total operating revenues 0 25 0 73 Other Operating Revenues: Total operating revenues 0 0 2 4 Marketing purchases Operating Costs and Expenses: Marketing purchases $ 288 $ 288 $ 1,022 $ 808 [1]In 2018, deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Copyright © 2019 www.secdatabase.com. All Rights Reserved. Please Consider the Environment Before Printing This Document