Southwestern Energy (SWN) 10-Q 28 Apr 22 2022 Q1 Quarterly report Financial data

COVER PAGE

COVER PAGE - shares	3 Months Ended
	Mar. 31, 2022	Apr. 26, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	001-08246
Entity Registrant Name	Southwestern Energy Company
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Entity Central Index Key	0000007332
Current Fiscal Year End Date	--12-31
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
Title of 12(b) Security	Common Stock, Par Value $0.01
Trading Symbol	SWN
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		1,116,176,673

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 2,943	$ 1,072
Operating Costs and Expenses:
Operating expenses	381	250
General and administrative expenses	44	38
Merger-related expenses	25	1
Restructuring charges	0	6
Depreciation, depletion and amortization	275	96
Taxes, other than income taxes	57	24
Total operating costs and expense	1,644	771
Operating Income	1,299	301
Interest Expense:
Interest on debt	68	50
Other interest charges	3	3
Interest capitalized	(30)	(22)
Total interest expense	41	31
Loss on Derivatives	(3,927)	(191)
Loss on Early Extinguishment of Debt	(2)	0
Other Income, Net	0	1
Income (Loss) Before Income Taxes	(2,671)	80
Provision (Benefit) for Income Taxes:
Current	4	0
Deferred	0	0
Total provision (benefit) from income taxes	4	0
Net Income (Loss)	$ (2,675)	$ 80
Earnings (Loss) Per Common Share:
Basic (in dollars per share)	$ (2.40)	$ 0.12
Diluted (in dollars per share)	$ (2.40)	$ 0.12
Weighted Average Common Shares Outstanding:
Basic (in shares)	1,114,610,964	675,385,145
Diluted (in shares)	1,114,610,964	679,867,825
Gas sales
Operating Revenues:
Total operating revenues	$ 1,692	$ 464
Oil sales
Operating Revenues:
Total operating revenues	111	81
NGL sales
Operating Revenues:
Total operating revenues	272	173
Marketing
Operating Revenues:
Total operating revenues	866	352
Other
Operating Revenues:
Total operating revenues	2	2
Marketing purchases
Operating Costs and Expenses:
Marketing purchases	$ 862	$ 356

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Net income (loss)		$ (2,675)	$ 80
Change in value of pension and other postretirement liabilities:
Settlement adjustment	[1]	0	0
Total comprehensive loss		$ (2,675)	$ 80
[1]	Settlement adjustment was less than $1 million for the three months ended March 31, 2022.

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)
Statement of Comprehensive Income [Abstract]
Settlement adjustment	$ 1

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 21	$ 28
Accounts receivable, net	1,071	1,160
Derivative assets	103	183
Other current assets	43	42
Total current assets	1,238	1,413
Natural gas and oil properties, using the full cost method, including $2,228 million as of March 31, 2022 and $2,231 million as of December 31, 2021 excluded from amortization	34,184	33,631
Other	513	509
Less: Accumulated depreciation, depletion and amortization	(24,482)	(24,202)
Total property and equipment, net	10,215	9,938
Operating lease assets	186	187
Long-term derivative assets	126	226
Deferred tax assets	0	0
Other long-term assets	82	84
Total long-term assets	394	497
TOTAL ASSETS	11,847	11,848
Current liabilities:
Current portion of long-term debt	5	206
Accounts payable	1,488	1,282
Taxes payable	80	93
Interest payable	49	75
Derivative liabilities	3,940	1,279
Current operating lease liabilities	44	42
Other current liabilities	64	75
Total current liabilities	5,670	3,052
Long-term debt	4,895	5,201
Long-term operating lease liabilities	139	142
Long-term derivative liabilities	1,023	632
Pension and other postretirement liabilities	25	23
Other long-term liabilities	214	251
Total long-term liabilities	6,296	6,249
Commitments and contingencies (Note 12)
Equity/(deficit):
Common stock, $0.01 par value; 2,500,000,000 shares authorized; issued 1,160,451,456 shares as of March 31, 2022 and 1,158,672,666 shares as of December 31, 2021	12	12
Additional paid-in capital	7,159	7,150
Accumulated deficit	(7,063)	(4,388)
Accumulated other comprehensive loss	(25)	(25)
Common stock in treasury, 44,353,224 shares as of March 31, 2022 and December 31, 2021	(202)	(202)
Total equity/(deficit)	(119)	2,547
TOTAL LIABILITIES AND EQUITY	$ 11,847	$ 11,848

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Natural gas and oil properties, using the full cost method, costs excluded from amortization	$ 2,228	$ 2,231
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	2,500,000,000	2,500,000,000
Common stock, shares issued (in shares)	1,160,451,456	1,158,672,666
Treasury stock, shares (in shares)	44,353,224	44,353,224

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cash Flows From Operating Activities:
Net income (loss)	$ (2,675)	$ 80
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	275	96
Amortization of debt issuance costs	2	2
Loss on derivatives, unsettled	3,232	169
Stock-based compensation	1	0
Loss on early extinguishment of debt	2	0
Other	(1)	0
Change in assets and liabilities, excluding impact from acquisitions:
Accounts receivable	89	(33)
Accounts payable	126	33
Taxes payable	(13)	(8)
Interest payable	(16)	(2)
Inventories	4	9
Other assets and liabilities	(54)	1
Net cash provided by operating activities	972	347
Cash Flows From Investing Activities:
Capital investments	(500)	(227)
Proceeds from sale of property and equipment	0	1
Other	0	(1)
Net cash used in investing activities	(500)	(227)
Cash Flows From Financing Activities:
Payments on current portion of long-term debt	(202)	0
Payments on long-term debt	(21)	0
Payments on revolving credit facility	(2,803)	(923)
Borrowings under revolving credit facility	2,517	790
Change in bank drafts outstanding	34	7
Cash paid for tax withholding	(4)	(3)
Net cash used in financing activities	(479)	(129)
Decrease in cash and cash equivalents	(7)	(9)
Cash and cash equivalents at beginning of year	28	13
Cash and cash equivalents at end of period	$ 21	$ 4

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Common Stock	Additional Paid-In Capital	Accumulated Deficit	Accumulated Other Comprehensive Income (Loss)	Common Stock in Treasury
Balance (in shares) at Dec. 31, 2020		718,795,700				44,353,224
Balance beginning at Dec. 31, 2020	$ 497	$ 7	$ 5,093	$ (4,363)	$ (38)	$ (202)
Comprehensive income (loss):
Net income (loss)	80			80
Total comprehensive income (loss)	80
Issuance of restricted stock (in shares)		10,067
Cancellation of restricted stock (in shares)		(405)
Restricted units vested (in shares)		2,136,882
Restricted units vested	8		8
Performance units vested (in shares)		1,001,505
Performance units vested	4		4
Tax withholding - stock compensation (in shares)		(748,627)
Tax withholding – stock compensation	(3)		(3)
Balance (in shares) at Mar. 31, 2021		721,195,122				44,353,224
Balance ending at Mar. 31, 2021	586	$ 7	5,102	(4,283)	(38)	$ (202)
Balance (in shares) at Dec. 31, 2021		1,158,672,666				44,353,224
Balance beginning at Dec. 31, 2021	2,547	$ 12	7,150	(4,388)	(25)	$ (202)
Comprehensive income (loss):
Net income (loss)	(2,675)			(2,675)
Total comprehensive income (loss)	(2,675)
Stock-based compensation	1		1
Performance units vested (in shares)		2,499,860
Performance units vested	12		12
Tax withholding - stock compensation (in shares)		(721,070)
Tax withholding – stock compensation	(4)		(4)
Balance (in shares) at Mar. 31, 2022		1,160,451,456				44,353,224
Balance ending at Mar. 31, 2022	$ (119)	$ 12	$ 7,159	$ (7,063)	$ (25)	$ (202)

BASIS OF PRESENTATION

BASIS OF PRESENTATION	3 Months Ended
	Mar. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF PRESENTATION	BASIS OF PRESENTATION Nature of Operations Southwestern Energy Company (including its subsidiaries, collectively “Southwestern” or the “Company”) is an independent energy company engaged in natural gas, oil and NGLs development, exploration and production (“E&P”). The Company is also focused on creating and capturing additional value through its marketing business (“Marketing”). Southwestern conducts most of its business through subsidiaries and operates principally in two segments: E&P and Marketing. E&P. Southwestern’s primary business is the development and production of natural gas as well as associated NGLs and oil, with ongoing operations focused on unconventional natural gas and oil reservoirs located in Pennsylvania, West Virginia, Ohio and Louisiana. The Company’s operations in Pennsylvania, West Virginia and Ohio, herein referred to as “Appalachia,” are primarily focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and liquids reservoirs. The Company’s operations in Louisiana, herein referred to as “Haynesville,” are primarily focused on the Haynesville and Bossier natural gas reservoirs (“Haynesville and Bossier Shales”). The Company also operates drilling rigs and provides certain oilfield products and services, principally serving the Company’s E&P operations through vertical integration. Marketing. 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. Basis of Presentation The accompanying consolidated financial statements were prepared using accounting principles generally accepted in the United States (“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 comparability of certain 2022 amounts to prior periods could be impacted as a result of the Indigo Merger (as defined below) completed on September 1, 2021, and the GEPH Merger (as defined below) completed on December 31, 2021. The Company believes the disclosures made are adequate to make the information presented not misleading. Principles of Consolidation 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, 2021 (“2021 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 2021 Annual Report.

ACQUISITIONS

ACQUISITIONS	3 Months Ended
	Mar. 31, 2022
Business Combination and Asset Acquisition [Abstract]
ACQUISITIONS	ACQUISITIONS In September 2021, Southwestern completed the Indigo Merger, as defined and described below, to establish operations into the Haynesville and Bossier Shales. In December 2021, Southwestern completed the GEPH Merger, as defined and described below, to extend those operations in the Haynesville and Bossier Shales. For the three months ended March 31, 2022, revenues and operating income associated with the operations acquired through the Indigo and GEPH Mergers totaled $753 million and $482 million, respectively. GEP Haynesville, LLC Merger On November 3, 2021, Southwestern entered into an Agreement and Plan of Merger with Mustang Acquisition Company, LLC (“Mustang”), GEP Haynesville, LLC (“GEPH”) and GEPH Unitholder Rep, LLC (the “GEPH Merger Agreement”). Pursuant to the terms of the GEPH Merger Agreement, GEPH merged with and into Mustang, a subsidiary of Southwestern, and became a wholly-owned subsidiary of Southwestern (the “GEPH Merger”). The GEPH Merger closed on December 31, 2021 and expanded the Company’s operations in the Haynesville. Under the terms and conditions of the GEPH Merger Agreement, the outstanding equity interests in GEPH were cancelled and converted into the right to receive $1,269 million in cash consideration and 99,337,748 shares of Southwestern common stock. These shares of Southwestern common stock had an aggregate dollar value equal to approximately $463 million, based on the closing price of $4.66 per share of Southwestern common stock on the NYSE on December 31, 2021. In addition, the Company assumed GEPH’s revolving line of credit balance of $81 million as of December 31, 2021. This balance was subsequently repaid, and the GEPH revolving line of credit was retired on December 31, 2021. See Note 11 for additional information. The GEPH Merger constituted a business combination, and was accounted for using the acquisition method of accounting. For tax purposes, the GEPH Merger was treated as a sale of partnership interests and an acquisition of assets. The following table presents the fair value of consideration transferred to GEPH equity holders as a result of the GEPH Merger: (in millions, except share, per share amounts) As of December 31, 2021 Shares of Southwestern common stock issued 99,337,748 NYSE closing price per share of Southwestern common shares on December 31, 2021 $ 4.66 $ 463 Cash consideration 1,269 Total consideration $ 1,732 The following table sets forth the preliminary fair value of the assets acquired and liabilities assumed as of the acquisition date. Certain data necessary to complete the purchase price allocation is still under evaluation, including, but not limited to, the final actualization of accrued liabilities and receivable balances as well as the valuation of natural gas and oil properties. The Company will finalize the purchase price allocation during the twelve-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. (in millions) As of December 31, 2021 Consideration: Total consideration $ 1,732 Fair Value of Assets Acquired: Cash and cash equivalents 11 Accounts receivable 171 Other current assets 3 Commodity derivative assets 56 Evaluated oil and gas properties 1,783 Unevaluated oil and gas properties (1) 58 Other property, plant and equipment 2 Other long-term assets 3 Total assets acquired 2,087 Fair Value of Liabilities Assumed: Accounts payable (2) 164 Other current liabilities 1 Derivative liabilities 75 Revolving credit facility 81 Asset retirement obligations 24 Other noncurrent liabilities (2) 10 Total liabilities assumed 355 Net Assets Acquired and Liabilities Assumed $ 1,732 (1) Reflects $1 million purchase price adjustment during the three months ended March 31, 2022. (2) Reflects purchase price adjustments reflecting a decrease of $6 million to accounts payable and a $5 million increase to other noncurrent liabilities during the three months ended March 31, 2022. The assets acquired and liabilities assumed were recorded at their preliminary estimated fair values at the date of the GEPH Merger. Acquired working capital amounts are expected to approximate fair value due to their short-term nature. The valuation of certain assets, including property, are based on preliminary appraisals. The fair value of acquired equipment is based on both available market data and a cost approach. With the completion of the GEPH Merger, Southwestern acquired proved and unproved properties of approximately $1,783 million and $58 million, respectively, primarily associated with the Haynesville and Bossier formations. The remaining $2 million in Other property, plant and equipment consists of land, facilities and various equipment. The income approach was utilized for unevaluated and evaluated oil and gas properties based on underlying reserve projections at the GEPH Merger date. Income approaches are considered Level 3 fair value estimates and include significant assumptions of future production, commodity prices, and operating and capital cost estimates, discounted using weighted average cost of capital for industry peers, and risk adjustment factors based on reserve category. Price assumptions were based on observable market pricing adjusted for historical differentials. Cost estimates were based on current observable costs inflated based on historical and expected future inflation. Taxes were based on current statutory rates. The Company considered the borrowings under the revolving credit facility to approximate fair value as the balance on the GEPH revolving credit facility was immediately paid off after the GEPH Merger close. The value of derivative instruments was based on observable inputs, primarily forward commodity-price curves, and is considered Level 2. Indigo Natural Resources Merger On June 1, 2021, Southwestern entered into an Agreement and Plan of Merger with Ikon Acquisition Company, LLC (“Ikon”), Indigo Natural Resources LLC (“Indigo”) and Ibis Unitholder Representative LLC (the “Indigo Merger Agreement”). Pursuant to the terms of the Indigo Merger Agreement, Indigo merged with and into Ikon, a subsidiary of Southwestern, and became a wholly-owned subsidiary of Southwestern (the “Indigo Merger”). On August 27, 2021, Southwestern’s stockholders voted to approve the Indigo Merger and the transaction closed on September 1, 2021. The Indigo Merger established Southwestern’s natural gas operations in the Haynesville and Bossier Shales. The outstanding equity interests in Indigo were cancelled and converted into the right to receive (i) $373 million in cash consideration, subject to adjustment as provided in the Indigo Merger Agreement, and (ii) 337,827,171 shares of Southwestern common stock. These shares of Southwestern common stock had an aggregate dollar value equal to approximately $1,588 million, based on the closing price of $4.70 per share of Southwestern common stock on the NYSE on September 1, 2021. Additionally, Southwestern assumed $700 million in aggregate principal amount of Indigo’s 5.375% Senior Notes due 2029 (the “Indigo Notes”) with a fair value of $726 million as of September 1, 2021, which were subsequently exchanged for $700 million of newly issued 5.375% Senior Notes due 2029. In addition, the Company assumed Indigo’s revolving line of credit balance of $95 million as of September 1, 2021. This balance was subsequently repaid in September 2021, and the Indigo revolving line of credit was retired in September 2021. See Note 7 and Note 11 for additional information. The Indigo Merger constituted a business combination, and was accounted for using the acquisition method of accounting. For tax purposes, the Indigo Merger was treated as a sale of partnership interests and an acquisition of assets. The following table presents the fair value of consideration transferred to Indigo equity holders as a result of the Indigo Merger: (in millions, except share, per share amounts) As of September 1, 2021 Shares of Southwestern common stock issued 337,827,171 NYSE closing price per share of Southwestern common shares on September 1, 2021 $ 4.70 $ 1,588 Cash consideration 373 Total consideration $ 1,961 The following table sets forth the preliminary fair value of the assets acquired and liabilities assumed as of the acquisition date. Certain data necessary to complete the purchase price allocation is still under evaluation, including, but not limited to, the valuation of natural gas and oil properties and the resolution of certain matters that the Company is indemnified for under the Indigo Merger Agreement. The Company will finalize the purchase price allocation during the twelve-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. (in millions) As of September 1, 2021 Consideration: Total consideration $ 1,961 Fair Value of Assets Acquired: Cash and cash equivalents 55 Accounts receivable 192 Other current assets 2 Commodity derivative assets 2 Evaluated oil and gas properties 2,724 Unevaluated oil and gas properties (1) 693 Other property, plant and equipment 4 Other long-term assets 27 Total assets acquired 3,699 Fair Value of Liabilities Assumed: Accounts payable (1) 283 Other current liabilities 55 Derivative liabilities 501 Revolving credit facility 95 Senior unsecured notes 726 Asset retirement obligations 8 Other noncurrent liabilities 70 Total liabilities assumed 1,738 Net Assets Acquired and Liabilities Assumed $ 1,961 (1) Reflects $9 million purchase price adjustment during the three months ended March 31, 2022. The assets acquired and liabilities assumed were recorded at their preliminary estimated fair values at the date of the Indigo Merger. Acquired working capital amounts are expected to approximate fair value due to their short-term nature. The valuation of certain assets, including property, are based on preliminary appraisals. The fair value of acquired equipment is based on both available market data and a cost approach. With the completion of the Indigo Merger, Southwestern acquired proved and unproved properties of approximately $2,724 million and $693 million, respectively, primarily associated with the Haynesville and Bossier formations. The remaining $4 million in Other property, plant and equipment consists of land, water facilities and various equipment. The income approach was utilized for unevaluated and evaluated oil and gas properties based on underlying reserve projections at the Indigo Merger date. Income approaches are considered Level 3 fair value estimates and include significant assumptions of future production, commodity prices, and operating and capital cost estimates, discounted using weighted average cost of capital for industry peers, and risk adjustment factors based on reserve category. Price assumptions were based on observable market pricing adjusted for historical differentials. Cost estimates were based on current observable costs inflated based on historical and expected future inflation. Taxes were based on current statutory rates. The measurement of senior unsecured notes was based on unadjusted quoted prices in an active market and are Level 1. The Company considered the borrowings under the 2018 credit facility to approximate fair value as the outstanding Indigo revolving credit facility was immediately paid off after the Indigo Merger close. The value of derivative instruments was based on observable inputs, primarily forward commodity-price and interest-rate curves and is considered Level 2. Prior to the Indigo Merger, in May 2021, Indigo closed on an agreement to divest its Cotton Valley natural gas and oil properties. Indigo retained certain contractual commitments related to volume commitments associated with natural gas gathering, for which Southwestern has assumed the obligation to pay the gathering provider for any unused portion of the volume commitment under the agreement through 2027, depending on the buyer’s actual use. As of March 31, 2022, up to approximately $34 million of these contractual commitments remain, and the Company has recorded a $17 million liability for the estimated future payments. Excluding the Cotton Valley gathering agreement (discussed above), the Company has recorded additional liabilities totaling $35 million as of March 31, 2022, primarily related to purchase or volume commitments associated with gathering and fresh water. These amounts will be recognized as payments are made over a period of two years. Merger-Related Expenses The following table summarizes the merger-related expenses incurred: For the three months ended March 31, 2022 2021 (in millions) Indigo Merger GEPH Merger Total Montage Merger Transition services $ — $ 18 $ 18 $ — Professional fees (bank, legal, consulting) — 1 1 — Contract buyouts, terminations and transfers — 2 2 — Due diligence and environmental 1 — 1 — Employee-related — 1 1 1 Other — 2 2 — Total merger-related expenses $ 1 $ 24 $ 25 $ 1 Pro Forma Information The following table summarizes the unaudited pro forma condensed financial information for the three months ended March 31, 2021 as if the Indigo Merger and the GEPH Merger each had occurred on January 1, 2020: (in millions) For the three months ended Revenues $ 1,471 Net income attributable to common stock $ 30 Net income attributable to common stock per share - basic $ 0.03 Net income attributable to common stock per share - diluted $ 0.03 The unaudited pro forma information is not necessarily indicative of the operating results that would have occurred had the Indigo Merger and the GEPH Merger each been completed at January 1, 2020, nor is it necessarily indicative of future operating results of the combined entities. The unaudited pro forma information gives effect to the Indigo Merger and the GEPH Merger and any related equity and debt issuances, along with the use of proceeds therefrom, as if they had occurred on January 1, 2020 and is a result of combining the statements of operations of Southwestern with the pre-merger results of Indigo and GEPH, including adjustments for revenues and direct expenses. The pro forma results exclude any cost savings anticipated as a result of the Indigo Merger and the GEPH Merger, and include adjustments to DD&A (depreciation, depletion and amortization) based on the purchase price allocated to property, plant, and equipment and the estimated useful lives as well as adjustments to interest expense. Interest expense was adjusted to reflect any retirement of assumed senior notes, credit facilities, all related accrued interest and the associated decrease in amortization of issuance costs related to notes retired and revolving lines of credit. Interest expense was also adjusted to include the impact of the assumption and exchange of Indigo’s $700 million of 5.375% Senior Notes due 2029 for equivalent Southwestern senior notes and to reflect the retirement of the Indigo and GEPH credit facilities, all related accrued interest and the associated decreases in amortization of issuance costs related to the respective revolving lines of credit. Management believes the estimates and assumptions are reasonable, and the relative effects of the Indigo Merger and the GEPH Merger are properly reflected.

RESTRUCTURING CHARGES

RESTRUCTURING CHARGES	3 Months Ended
	Mar. 31, 2022
Restructuring and Related Activities [Abstract]
RESTRUCTURING CHARGES	RESTRUCTURING CHARGES The following table presents a summary of the restructuring charges included in Operating Income for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Severance (including payroll taxes) (1) $ — $ 6 (1) All restructuring charges were recorded on the Company’s E&P segment for all periods presented. On February 24, 2021, the Company notified employees of a workforce reduction plan as part of an ongoing strategic effort to reposition its portfolio, optimize operational performance and improve margins. Affected employees were offered a severance package, which included a one-time payment depending on length of service and, if applicable, the current value of unvested long-term incentive awards that were forfeited. These costs were recognized as restructuring charges for the three months ended March 31, 2021, and were substantially complete by the end of the first quarter of 2021.

REVENUE RECOGNITION

REVENUE RECOGNITION	3 Months Ended
	Mar. 31, 2022
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 for 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. Marketing. The Company, through its marketing affiliate, generally markets natural gas, oil and NGLs for its affiliated E&P companies as well as other joint owners who choose to market with the Company. 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 market indices 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 for which the Company has a right to invoice and has not disclosed information regarding its remaining performance obligations. 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: (in millions) E&P Marketing Intersegment Total Three months ended March 31, 2022 Gas sales $ 1,690 $ — $ 2 $ 1,692 Oil sales 110 — 1 111 NGL sales 272 — — 272 Marketing — 2,755 (1,889) 866 Other (1) 2 — — 2 Total $ 2,074 $ 2,755 $ (1,886) $ 2,943 Three months ended March 31, 2021 Gas sales $ 451 $ — $ 13 $ 464 Oil sales 80 — 1 81 NGL sales 173 — — 173 Marketing — 996 (644) 352 Other (2) 1 1 — 2 Total $ 705 $ 997 $ (630) $ 1,072 (1) For the three months ended March 31, 2022, other E&P revenues consists primarily of gains on purchaser imbalances associated with natural gas and certain NGLs. (2) For the three months ended March 31, 2021, other E&P revenues consists primarily of gains on purchaser imbalances associated with certain NGLs and other Marketing 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 primarily Appalachia and Haynesville. For the three months (in millions) 2022 2021 Appalachia $ 1,321 $ 704 Haynesville 753 — Other — 1 Total $ 2,074 $ 705 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) March 31, 2022 December 31, 2021 Receivables from contracts with customers $ 972 $ 1,085 Other accounts receivable 99 75 Total accounts receivable $ 1,071 $ 1,160 Amounts recognized against the Company’s allowance for doubtful accounts related to receivables arising from contracts with customers were immaterial for the three months ended March 31, 2022 and 2021, respectively. The Company has no contract assets or contract liabilities associated with its revenues from contracts with customers.

CASH AND CASH EQUIVALENTS

CASH AND CASH EQUIVALENTS	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and December 31, 2021: (in millions) March 31, 2022 December 31, 2021 Cash $ 21 $ 28 Marketable securities (1) — — Total $ 21 $ 28 (1) Typically consists of government stable value money market funds.

NATURAL GAS AND OIL PROPERTIES

NATURAL GAS AND OIL PROPERTIES	3 Months Ended
	Mar. 31, 2022
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 development, exploration 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. The Company had no hedge positions that were designated for hedge accounting as of March 31, 2022. Prices used to calculate the ceiling value of reserves were as follows: March 31, 2022 March 31, 2021 Natural gas (per MMBtu) $ 4.09 $ 2.16 Oil (per Bbl) $ 75.39 $ 40.01 NGLs (per Bbl) $ 32.75 $ 13.57 Using the average quoted prices above, adjusted for market differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount at March 31, 2022. 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 non-cash ceiling test impairments to the Company’s natural gas and oil properties.

EARNINGS PER SHARE

EARNINGS PER SHARE	3 Months Ended
	Mar. 31, 2022
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE Basic earnings per common share is computed by dividing net income (loss) 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, restricted stock units and performance units. 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. On December 31, 2021, the Company issued 99,337,748 shares of its common stock in conjunction with the GEPH Merger. These shares of Southwestern common stock had an aggregate dollar value equal to approximately $463 million, based on the closing price of $4.66 per share of Southwestern common stock on the NYSE on December 31, 2021. See Note 2 for additional details on the GEPH Merger. In September 2021, the Company issued 337,827,171 shares of its common stock in conjunction with the Indigo Merger. These shares of Southwestern common stock had an aggregate dollar value equal to approximately $1,588 million, based on the closing price of $4.70 per share of Southwestern common stock on the NYSE on September 1, 2021. See Note 2 for additional details on the Indigo Merger. The following table presents the computation of earnings per share for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions, except share/per share amounts) 2022 2021 Net income (loss) $ (2,675) $ 80 Number of common shares: Weighted average outstanding 1,114,610,964 675,385,145 Issued upon assumed exercise of outstanding stock options — — Effect of issuance of non-vested restricted common stock — 870,541 Effect of issuance of non-vested restricted units — 804,944 Effect of issuance of non-vested performance units — 2,807,195 Weighted average and potential dilutive outstanding 1,114,610,964 679,867,825 Earnings (loss) per common share Basic $ (2.40) $ 0.12 Diluted $ (2.40) $ 0.12 The following table presents the common stock shares equivalent excluded from the calculation of diluted earnings per share for the three months ended March 31, 2022 and 2021, as they would have had an antidilutive effect: For the three months ended March 31, 2022 2021 Unexercised stock options 2,948,488 3,795,091 Stock-based compensation 1,436,920 — Restricted stock units 2,528,005 3,987,291 Performance units 1,917,579 — Total 8,830,992 7,782,382

DERIVATIVES AND RISK MANAGEMENT

DERIVATIVES AND RISK MANAGEMENT	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVES AND RISK MANAGEMENT	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 March 31, 2022, the Company’s derivative financial instruments consisted of fixed price swaps, two-way costless collars, three-way costless collars, basis swaps, call options, swaptions 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 that, 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. Options (Calls and Puts) The Company purchases and sells options in exchange for premiums. 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. If the Company purchases a put option, the Company receives from the counterparty the excess (if any) of the strike price over the market price of the put option at the time of settlement, but if the market price is above the put’s strike price, no payment is due from either party. If the Company sells a put option, the Company pays the counterparty the excess (if any) of the strike price over the market price of the put option at the time of settlement, but if the market price is above the put’s strike price, no payment is due from either party. Index swaps Natural gas index swaps are used to manage the Company’s exposure to volatility in daily cash market pricing. When the Company sells an index swap, the Company pays an amount equal to the average of the daily index price for a given month at a specified location, and receives a first of month index price based on the same location. Swaptions Instruments that refer to an option to enter into a fixed price swap. In exchange for an option premium, the purchaser gains the right but not the obligation to enter a specified swap agreement with the issuer for specified future dates. If the Company sells a swaption, the counterparty has the right to enter into a fixed price swap wherein the Company receives a fixed price for the contract and pays a floating market price to the counterparty. If the Company purchases a swaption, the Company has the right to enter into a fixed price swap wherein the Company receives a floating market price for the contract and pays a fixed price to the counterparty. 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 contracts with 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 derivatives position on a gross basis and does not net the asset and liability positions. 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 March 31, 2022: Financial Protection on Production Weighted Average Price per MMBtu Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential Fair Value at March 31, 2022 (in millions) Natural Gas 2022 Fixed price swaps 627 $ 3.04 $ — $ — $ — $ — $ (1,672) Two-way costless collars 78 — — 2.53 2.92 — (216) Three-way costless collars 277 — 2.03 2.48 2.88 — (784) Total 982 $ (2,672) 2023 Fixed price swaps 504 $ 3.08 $ — $ — $ — $ — $ (675) Two-way costless collars 219 — — 3.03 3.55 — (217) Three-way costless collars 215 — 2.09 2.54 3.00 — (355) Total 938 $ (1,247) 2024 Fixed price swaps 224 $ 2.96 $ — $ — $ — $ — $ (174) Two-way costless collars 44 — — 3.07 3.53 — (19) Three-way costless collars 11 — 2.25 2.80 3.54 — (12) Total 279 $ (205) Basis Swaps 2022 277 $ — $ — $ — $ — $ (0.53) $ 72 2023 250 — — — — (0.47) 20 2024 46 — — — — (0.71) 9 2025 9 — — — — (0.64) 3 Total 582 $ 104 Volume (MBbls) Weighted Average Strike Price per Bbl Fair Value at March 31, 2022 (in millions) Swaps Sold Puts Purchased Puts Sold Calls Oil 2022 Fixed price swaps 2,376 $ 53.32 $ — $ — $ — $ (94) Three-way costless collars 1,037 — 39.83 50.17 57.01 (38) Total 3,413 $ (132) 2023 Fixed price swaps 846 $ 55.98 $ — $ — $ — $ (23) Three-way costless collars 1,268 — 33.97 45.51 56.12 (36) Total 2,114 $ (59) 2024 Fixed price swaps 603 $ 68.68 $ — $ — $ — $ (5) Ethane 2022 Fixed price swaps 4,142 $ 11.27 $ — $ — $ — $ (26) 2023 Fixed price swaps 1,308 $ 11.91 $ — $ — $ — $ (3) Propane 2022 Fixed price swaps 4,643 $ 31.09 $ — $ — $ — $ (118) Three-way costless collars 230 — 16.80 21.00 31.92 (6) Total 4,873 $ (124) 2023 Fixed price swaps 1,066 $ 37.15 $ — $ — $ — $ (8) Normal Butane 2022 Fixed price swaps 1,388 $ 36.22 $ — $ — $ — $ (43) 2023 Fixed price swaps 329 $ 40.64 $ — $ — $ — $ (3) Natural Gasoline 2022 Fixed price swaps 1,497 $ 55.78 $ — $ — $ — $ (57) 2023 Fixed price swaps 359 $ 66.00 $ — $ — $ — $ (5) Other Derivative Contracts Volume (Bcf) Weighted Average Strike Price per MMBtu Fair Value at March 31, 2022 (in millions) Call Options – Natural Gas (Net) 2022 63 $ 3.01 $ (171) 2023 46 2.94 (74) 2024 9 3.00 (13) Total 118 $ (258) Volume (Bcf) Weighted Average Strike Price per MMBtu Fair Value at March 31, 2022 (in millions) Swaps Basis Differential Storage (1) 2022 Purchased fixed price swaps — $ 2.14 $ — $ 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 and sold at a later date. At March 31, 2022, the net fair value of the Company’s financial instruments was a $4,734 million liability, which included net reduction of the liability of $8 million related to non-performance risk. See Note 10 for additional details regarding the Company’s fair value measurements of its derivatives position. As of March 31, 2022, 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 gains and losses on both settled and unsettled derivatives. Only the settled gains and losses are included in the Company’s realized commodity price calculations. The balance sheet classification of the assets and liabilities related to derivative financial instruments are summarized below as of March 31, 2022 and December 31, 2021: Derivative Assets Fair Value (in millions) Balance Sheet Classification March 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments: Fixed price swaps – natural gas Derivative assets $ — $ 79 Fixed price swaps – ethane Derivative assets — 2 Fixed price swaps – propane Derivative assets — 2 Fixed price swaps – normal butane Derivative assets — 1 Two-way costless collars – natural gas Derivative assets 10 9 Three-way costless collars – natural gas Derivative assets 9 12 Three-way costless collars – oil Derivative assets 1 1 Basis swaps – natural gas Derivative assets 82 77 Purchased fixed price swaps – natural gas storage Derivative assets 1 — Fixed price swaps – natural gas Other long-term assets — 64 Two-way costless collars – natural gas Other long-term assets 44 100 Three-way costless collars – natural gas Other long-term assets 12 37 Three-way costless collars – oil Other long-term assets 1 3 Basis swaps – natural gas Other long-term assets 70 22 Interest rate swaps Other long-term assets — 2 Total derivative assets $ 230 $ 411 Derivative Liabilities Fair Value (in millions) Balance Sheet Classification March 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments: Fixed price swaps – natural gas storage Derivative liabilities $ — $ 1 Fixed price swaps – natural gas Derivative liabilities 1,999 565 Fixed price swaps – oil Derivative liabilities 101 60 Fixed price swaps – ethane Derivative liabilities 28 10 Fixed price swaps – propane Derivative liabilities 122 78 Fixed price swaps – normal butane Derivative liabilities 44 27 Fixed price swaps – natural gasoline Derivative liabilities 59 33 Two-way costless collars – natural gas Derivative liabilities 316 104 Two-way costless collars – ethane Derivative liabilities — 1 Three-way costless collars – natural gas Derivative liabilities 977 298 Three-way costless collars – oil Derivative liabilities 49 24 Three-way costless collars – propane Derivative liabilities 6 4 Basis swaps – natural gas Derivative liabilities 43 9 Call options – natural gas Derivative liabilities 201 67 Fixed price swaps – natural gas Long-term derivative liabilities 522 246 Fixed price swaps – oil Long-term derivative liabilities 21 9 Fixed price swaps – ethane Long-term derivative liabilities 1 — Fixed price swaps – propane Long-term derivative liabilities 4 1 Fixed price swaps – normal butane Long-term derivative liabilities 2 — Fixed price swaps – natural gasoline Long-term derivative liabilities 3 1 Two-way costless collars – natural gas Long-term derivative liabilities 190 115 Three-way costless collars – natural gas Long-term derivative liabilities 195 178 Three-way costless collars – oil Long-term derivative liabilities 27 21 Basis swap – natural gas Long-term derivative liabilities 5 22 Call options – natural gas Long-term derivative liabilities 57 42 Total derivative liabilities $ 4,972 $ 1,916 Net Derivative Position March 31, 2022 December 31, 2021 (in millions) Net current derivative liabilities $ (3,842) $ (1,098) Net long-term derivative liabilities (900) (407) Non-performance risk adjustment 8 3 Net total derivative liabilities $ (4,734) $ (1,502) The following tables summarize the before-tax effect of the Company’s derivative instruments on the consolidated statements of operations for the three months ended March 31, 2022 and 2021: Unsettled Gain (Loss) on Derivatives Recognized in Earnings Consolidated Statement of Operations Classification of Gain (Loss) on Derivatives, Unsettled For the three months ended March 31, Derivative Instrument 2022 2021 (in millions) Fixed price swaps – natural gas Gain (Loss) on Derivatives $ (1,853) $ (22) Fixed price swaps – oil Gain (Loss) on Derivatives (53) (40) Fixed price swaps – ethane Gain (Loss) on Derivatives (21) (2) Fixed price swaps – propane Gain (Loss) on Derivatives (49) (45) Fixed price swaps – normal butane Gain (Loss) on Derivatives (20) (15) Fixed price swaps – natural gasoline Gain (Loss) on Derivatives (28) (20) Two-way costless collars – natural gas Gain (Loss) on Derivatives (342) (12) Two-way costless collars – oil Gain (Loss) on Derivatives — (1) Two-way costless collars – ethane Gain (Loss) on Derivatives 1 — Three-way costless collars – natural gas Gain (Loss) on Derivatives (724) — Three-way costless collars – oil Gain (Loss) on Derivatives (33) (18) Three-way costless collars – propane Gain (Loss) on Derivatives (2) (1) Basis swaps – natural gas Gain (Loss) on Derivatives 36 3 Call options – natural gas Gain (Loss) on Derivatives (149) 3 Call options – oil Gain (Loss) on Derivatives — (1) Swaptions – natural gas Gain (Loss) on Derivatives — 1 Purchased fixed price swap – natural gas storage Gain (Loss) on Derivatives 1 — Fixed price swap – natural gas storage Gain (Loss) on Derivatives 1 — Interest rate swaps Gain (Loss) on Derivatives (2) 1 Total loss on unsettled derivatives $ (3,237) $ (169) Settled Gain (Loss) on Derivatives Recognized in Earnings (1) Consolidated Statement of Operations Classification of Gain (Loss) on Derivatives, Settled For the three months ended March 31, Derivative Instrument 2022 2021 (in millions) Fixed price swaps – natural gas Gain (Loss) on Derivatives $ (297) $ 5 Fixed price swaps – oil Gain (Loss) on Derivatives (33) (17) Fixed price swaps – ethane Gain (Loss) on Derivatives (8) (4) Fixed price swaps – propane Gain (Loss) on Derivatives (41) (30) Fixed price swaps – normal butane Gain (Loss) on Derivatives (14) (7) Fixed price swaps – natural gasoline Gain (Loss) on Derivatives (19) (9) Two-way costless collars – natural gas Gain (Loss) on Derivatives (104) 2 Two-way costless collars – oil Gain (Loss) on Derivatives — (1) Two-way costless collars – ethane Gain (Loss) on Derivatives (1) — Three-way costless collars – natural gas Gain (Loss) on Derivatives (121) 1 Three-way costless collars – oil Gain (Loss) on Derivatives (13) (1) Three-way costless collars – propane Gain (Loss) on Derivatives (2) — Basis swaps – natural gas Gain (Loss) on Derivatives 1 41 Index swaps – natural gas Gain (Loss) on Derivatives (1) — Call options – natural gas Gain (Loss) on Derivatives (39) — Put options – natural gas Gain (Loss) on Derivatives — (2) (2) Fixed price swaps – natural gas storage Gain (Loss) on Derivatives (3) — Total loss on settled derivatives $ (695) $ (22) (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 $2 million in amortization of premiums paid related to certain natural gas put options for the three months ended March 31, 2021, which is included in gain (loss) on derivatives on the consolidated statements of operations. Total Gain (Loss) on Derivatives Recognized in Earnings For the three months ended March 31, 2022 2021 (in millions) Total loss on unsettled derivatives $ (3,237) $ (169) Total loss on settled derivatives (695) (22) Non-performance risk adjustment 5 — Total loss on derivatives $ (3,927) $ (191)

RECLASSIFICATIONS FROM ACCUMULA

RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	3 Months Ended
	Mar. 31, 2022
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) The following tables detail the components of accumulated other comprehensive income and the related tax effects for the three months ended March 31, 2022: (in millions) Pension and Other Postretirement Foreign Currency Total Beginning balance December 31, 2021 $ (11) $ (14) $ (25) Other comprehensive income before reclassifications — — — Amounts reclassified from other comprehensive income (1) — — — Net current-period other comprehensive income — — — Ending balance March 31, 2022 $ (11) $ (14) $ (25) (1) For the three months ended March 31, 2022, the amounts reclassified from accumulated other comprehensive income was less than $1 million. See Note 14 for additional details regarding the Company’s pension and other postretirement benefit plans.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	3 Months Ended
	Mar. 31, 2022
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 March 31, 2022 and December 31, 2021 were as follows: March 31, 2022 December 31, 2021 (in millions) Carrying Fair Carrying Fair Cash and cash equivalents $ 21 $ 21 $ 28 $ 28 2018 revolving credit facility due April 2024 174 174 460 460 Term Loan B due 2027 549 549 550 550 Senior notes (1) 4,209 4,318 4,430 4,745 Derivative instruments, net (4,734) (4,734) (1,502) (1,502) (1) Excludes unamortized debt issuance costs and debt discounts. 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 are 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. The fair values of the Company’s senior notes are considered to be a Level 1 measurement as these are actively traded in the market. The carrying values of the borrowings under both the Company’s 2018 credit facility (to the extent utilized) and Term Loan approximates fair value because the interest rates are variable and reflective of market rates. The Company considers the fair values of its 2018 credit facility and Term Loan to be a Level 1 measurement on the fair value hierarchy. Derivative Instruments: The Company measures the fair value of its derivative instruments based upon a pricing model that utilizes market-based inputs, including, but not limited to, the contractual price of the underlying position, current market prices, natural gas and liquids forward curves, discount rates for a similar duration of each outstanding position, volatility factors and non-performance risk. Non-performance risk considers the effect of the Company’s credit standing on the fair value of derivative liabilities and the effect of counterparty credit standing on the fair value of derivative assets. Both inputs to the model are based on published credit default swap rates and the duration of each outstanding derivative position. As of March 31, 2022 and December 31, 2021, the impact of non-performance risk on the fair value of the Company’s net derivative liability position was a reduction of the net liability of $8 million and $3 million, respectively. The Company has classified its derivative instruments into 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 March 31, 2022 and December 31, 2021 are based on (i) the contracted notional amounts, (ii) active market-quoted London Interbank Offered Rate (“LIBOR”) yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve. The Company’s call and put 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. 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. Swaptions are valued using a variant of the Black-Scholes model referred to as the Black Swaption model, which uses its own separate volatility inputs. The Company’s basis swaps (Level 2) are estimated using third-party calculations based upon forward commodity price curves. Assets and liabilities measured at fair value on a recurring basis are summarized below: March 31, 2022 Fair Value Measurements Using: (in millions) Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets (Liabilities) at Fair Value Assets Two-way costless collars $ — $ 54 $ — $ 54 Three-way costless collars — 23 — 23 Basis swaps — 152 — 152 Purchased fixed price swaps – storage — 1 — 1 Liabilities Fixed price swaps — (2,906) — (2,906) Two-way costless collars — (506) — (506) Three-way costless collars — (1,254) — (1,254) Basis swaps — (48) — (48) Call options — (258) — (258) Total (1) $ — $ (4,742) $ — $ (4,742) (1) Excludes a net reduction to the liability fair value of $8 million related to estimated non-performance risk. December 31, 2021 Fair Value Measurements Using: (in millions) Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets (Liabilities) at Fair Value Assets Fixed price swaps $ — $ 148 $ — $ 148 Two-way costless collars — 109 — 109 Three-way costless collars — 53 — 53 Basis swaps — 99 — 99 Interest rate swaps — 2 — 2 Liabilities Fixed price swaps — (1,031) — (1,031) Two-way costless collars — (220) — (220) Three-way costless collars — (525) — (525) Basis swaps — (31) — (31) Call options — (109) — (109) Total (1) $ — $ (1,505) $ — $ (1,505) (1) Excludes a net reduction to the liability fair value of $3 million related to estimated non-performance risk. See Note 14 for a discussion of the fair value measurement of the Company’s pension plan assets. Assets and liabilities measured at fair value on a non-recurring basis The Company completed the Indigo Merger and the GEPH Merger on September 1, 2021 and December 31, 2021, respectively. See Note 2 for a discussion of the fair value measurement of assets acquired and liabilities assumed.

DEBT

DEBT	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
DEBT	DEBT The components of debt as of March 31, 2022 and December 31, 2021 consisted of the following: March 31, 2022 (in millions) Debt Instrument Unamortized Issuance Expense Unamortized Debt Premium/Discount Total Current portion of long-term debt: Variable rate (3.3% at March 31, 2022) Term Loan B due June 2027 $ 5 (1) $ — $ — $ 5 Total current portion of long-term debt $ 5 $ — $ — $ 5 Long-term debt: Variable rate (2.10% at March 31, 2022) 2018 revolving credit facility due April 2024 $ 174 $ — (2) $ — $ 174 4.95% Senior Notes due January 2025 (3) 389 (1) — 388 Variable rate (3.3% at March 31, 2022) Term Loan B due June 2027 544 (7) (1) 536 7.75% Senior Notes due October 2027 425 (4) — 421 8.375% Senior Notes due September 2028 345 (5) — 340 5.375% Senior Notes due February 2029 700 (6) 24 718 5.375% Senior Notes due September 2030 1,200 (16) — 1,184 4.75% Senior Notes due February 2032 1,150 (16) — 1,134 Total long-term debt $ 4,927 $ (55) $ 23 $ 4,895 Total debt $ 4,932 $ (55) $ 23 $ 4,900 December 31, 2021 (in millions) Debt Instrument Unamortized Issuance Expense Unamortized Debt Premium/Discount Total Current portion of long-term debt: 4.10% Senior Notes due March 2022 $ 201 $ — $ — $ 201 Variable rate (3.0% at December 31, 2021) Term Loan B due June 2027 5 (1) — — 5 Total current portion of long-term debt $ 206 $ — $ — $ 206 Long-term debt: Variable rate (2.08% at December 31, 2021) 2018 revolving credit facility, due April 2024 $ 460 $ — (2) $ — $ 460 4.95% Senior Notes due January 2025 (3) 389 (1) — 388 Variable rate (3.0% at December 31, 2021) Term Loan B due June 2027 545 (7) (1) 537 7.75% Senior Notes due October 2027 440 (4) — 436 8.375% Senior Notes due September 2028 350 (5) — 345 5.375% Senior Notes due September 2029 700 (6) 25 719 5.375% Senior Notes due March 2030 1,200 (17) — 1,183 4.75% Senior Notes due February 2032 1,150 (17) — 1,133 Total long-term debt $ 5,234 $ (57) $ 24 $ 5,201 Total debt $ 5,440 $ (57) $ 24 $ 5,407 (1) The Term Loan requires quarterly principal repayments of $1.375 million, subject to adjustment for voluntary prepayments, beginning in March 2022. (2) At March 31, 2022 and December 31, 2021, unamortized issuance expense of $9 million and $10 million, respectively, associated with the 2018 credit facility (as defined below) was classified as other long-term assets on the consolidated balance sheets. (3) Effective in July 2018, the interest rate was 6.20% for the 2025 Notes, reflecting a net downgrade in the Company’s bond ratings since the initial offering. On April 7, 2020, S&P downgraded the Company’s bond rating to BB-, which had the effect of increasing the interest rate on the 2025 Notes to 6.45% following the July 23, 2020 interest payment date. The first coupon payment to the bondholders at the higher interest rate was paid in January 2021. On September 1, 2021, S&P upgraded the Company’s bond rating to BB, and on January 6, 2022, S&P further upgraded the Company’s bond rating to BB+, which decreased the interest rate on the 2025 Notes to 5.95% beginning with coupon payments paid after January 2022. The following is a summary of scheduled debt maturities by year as of March 31, 2022 and includes the quarterly Term Loan principal repayments of $1.375 million, subject to adjustment for voluntary prepayments, beginning in March 2022: (in millions) 2022 $ 4 2023 6 2024 (1) 179 2025 395 2026 5 Thereafter 4,343 $ 4,932 (1) As of March 31, 2022, the Company’s 2018 credit facility matures in 2024. In April 2022, the 2018 credit facility was amended and restated resulting in the extension of the maturity date to 2027. Credit Facilities 2018 Credit Facility In April 2018, the Company entered into a revolving credit facility (the “2018 credit facility”) with a group of banks that, as amended, has a maturity date of April 2024. The 2018 credit facility has an aggregate maximum revolving credit amount of $3.5 billion, and in October 2021, the banks participating in the 2018 credit facility reaffirmed the elected borrowing base and aggregate commitments to be $2.0 billion. The borrowing base is subject to redetermination at least twice a year, which typically occurs in April and October, and is secured by substantially all of the assets owned by the Company and its subsidiaries. The permitted lien provisions in the senior notes indentures currently limit liens securing indebtedness to the greater of $2.0 billion and 25% of adjusted consolidated net tangible assets. The Company may utilize the 2018 credit facility in the form of loans and letters of credit. 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, as amended, ranges from 1.75% to 2.75% based on the Company’s utilization of 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, as amended, ranges from 0.75% to 1.75% based on the Company’s utilization of the 2018 credit facility. The 2018 credit facility contains customary representations and warranties and 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 ended 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, 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. For purposes of calculating consolidated EBITDAX, the Company can include the Indigo and GEPH consolidated EBITDAX prior to the respective Mergers for the same twelve-month rolling period. 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 March 31, 2022, the Company was in compliance with all of the covenants of the credit agreement in all material respects. Each United States domestic subsidiary of the Company for which the Company owns 100% of its equity 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. As of March 31, 2022, the Company had $147 million in letters of credit and $174 million in borrowings outstanding under the 2018 credit facility. The Company currently does not anticipate being required to supply a materially greater amount of letters of credit under its existing contracts. 2022 Credit Facility On April 8, 2022, the Company entered into an Amended and Restated Credit Agreement that replaces the 2018 credit facility (the “2022 credit facility”) with a group of banks, that as amended, has a maturity date of April 2027. The 2022 credit facility has an aggregate maximum revolving credit amount and borrowing base of $3.5 billion, and elected commitments of $2.0 billion. The borrowing base is subject to redetermination at least twice a year, which typically occurs in April and October, and is secured by substantially all of the assets owned by the Company and its subsidiaries. The 2022 credit facility has a term of five years from the effective date of April 8, 2022. The Company may utilize the 2022 credit facility in the form of loans and letters of credit. Loans under the 2022 credit facility are subject to varying rates of interest based on whether the loan is a Secured Overnight Financing Rate (“SOFR”) loan or an alternate base rate loan. Term SOFR loans bear interest at term SOFR plus an applicable rate ranging from 1.75% to 2.75% based on the Company’s utilization of the 2022 credit facility, plus a 0.10% credit spread adjustment. Base rate loans bear interest at a base rate per year equal to the greatest of: (i) the prime rate; (ii) the federal funds effective rate plus 0.50%; and (iii) the adjusted term SOFR rate for a one-month interest period plus 1.00%, plus an applicable margin ranging from 0.75% to 1.75%, depending on the percentage of the commitments utilized. Commitment fees on unused commitment amounts under the 2022 credit facility range between 0.375% to 0.50%, depending on the percentage of the commitments utilized. The 2022 credit facility contains customary representations and warranties and 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, declaring dividends, repurchasing junior debt, transactions with affiliates, or change of principal business; and • maintenance of the following financial covenants, commencing with the fiscal quarter ended March 31, 2022: 1. Minimum current ratio of not 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 not greater than, with respect to the prior four fiscal quarters ending on or after March 31, 2022, 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 credit agreement governing the Company’s 2018 credit facility, 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. Certain features of the facility depend on whether Southwestern has obtained any of the following ratings: • An unsecured long-term debt credit rating rating (an “Index Debt Rating”) of BBB- or higher with S&P; • An Index Debt Rating of Baa3 or higher with Moody’s; or • An Index Debt Rating of BBB- or higher with Fitch (each of the foregoing an “Investment Grade Rating”). Upon receiving one Investment Grade Rating from either S&P or Moody’s, repayment in full of the term loan obligations under Southwestern’s Term Loan Agreement dated December 22, 2021, and delivering a certification to the administrative agent (the period beginning at such time, an “Interim Investment Grade Period”), amongst other changes, the following occurs: • The Guarantors may be released from their guarantees, • The collateral under the facility will be released, • The facility will no longer be subject to a borrowing base, and • Certain title and collateral-related covenants will no longer be applicable. During the Interim Investment Grade Period, the Company will be required to maintain compliance with the existing financial covenants as well as a PV-9 coverage ratio of the net present value, discounted at 9% per annum, of the estimated future net revenues expected in the proved reserves to the Company’s total indebtedness as of such date of not less than 1.50 to 1.00 (“PV-9 Coverage Ratio”). In addition, during an Interim Investment Grade Period or Investment Grade Period (as defined below), term SOFR loans will bear interest at term SOFR plus an applicable rate ranging from 1.25% to 1.875%, depending on the Company’s Index Debt Rating (as defined in the 2022 credit facility), plus an additional 0.10% credit spread adjustment. Base rate loans will bear interest at the base rate described above plus an applicable rate ranging from 0.25% to 0.875%, depending on the Company’s Index Debt Rating. During an Interim Investment Grade Period or Investment Grade Period (defined below), the commitment fee on unused commitment amounts under the facility will range from 0.15% to 0.275%, depending on the Company’s Index Debt Rating. The Interim Investment Grade Period will end, and the facility will revert to its characteristics prior to the Interim Investment Grade Period, including being guaranteed by the Guarantors, being secured by collateral and being subject to a borrowing base, having applicable margins and commitment fee determined based on percentage of commitments utilized, as well as limited to compliance with the leverage ratio and current ratio financial covenants but not the PV-9 Coverage Ratio if both of the following are achieved during the Interim Investment Grade Period: • An Index Debt Rating from Moody’s that is Ba2 or lower; and • An Index Debt Rating from S&P that is BB or lower. Upon receiving two Investment Grade Ratings from S&P, Moody’s, or Fitch (such period following, an “Investment Grade Period”), certain restrictive covenants fall away or become more permissive. Upon Investment Grade Period, the leverage ratio and current ratio financial covenants and PV-9 Coverage Ratio will no longer be effective, and the Company will be required to maintain compliance with a total indebtedness to capitalization ratio, which is the ratio of the Company’s total indebtedness to the sum of total indebtedness plus stockholders’ equity, not to exceed 65%. Term Loan Credit Agreement In December 2021, the Company entered into a term loan credit agreement with a group of lenders that provided for a $550 million secured term loan facility which matures in June 2027 (the “Term Loan”). As of March 31, 2022, the Company had borrowings under this Term Loan of $549 million. The net proceeds from the initial loans of $542 million were used to fund a portion of the GEPH Merger on December 31, 2021. Beginning on March 31, 2022, the Term Loan requires minimum quarterly payments of $1.375 million, subject to adjustment for voluntary prepayments and mandatory prepayments as applicable. The Term Loan is subject to varying rates of interest based on whether the term loan is a term benchmark loan or an alternate base rate loan. Term benchmark loans bear interest at the adjusted term SOFR (which includes a credit spread adjustment and is subject to a floor that is 0.50%) plus an applicable margin equal to 2.50%. Alternate base rate loans bear interest at the alternate base rate plus an applicable margin equal to 1.50%. The current borrowings are considered benchmark loans and are carried at an interest rate of 3.30% as of March 31, 2022 (0.80% credit spread adjustment plus 2.50% margin). The Term Loan is subject to a quarterly collateral coverage ratio test in which the Company’s PDP PV-10 value, net of derivative mark-to-market value, must be greater than 2.0x its secured debt commitments or all secured debt becomes callable. If necessary, outstanding secured debt principal can be paid down within 45 days of the end of such fiscal quarter to come into compliance with this ratio, either by (i) prepaying the loans, (ii) prepaying the loans under the 2018 (2022 as amended) credit facility, (iii) prepaying any other secured indebtedness that is secured by a lien, or some combination thereof. As of March 31, 2022, the Company was in compliance with the quarterly coverage ratio test. The Company’s obligations under the Term Loan are guaranteed by each of the Company’s subsidiaries that guarantee the obligations under the 2018 (2022 as amended) credit facility and are secured by liens on substantially all the assets of the Company and the Company’s subsidiaries on an equal basis with the liens securing the obligations under the 2018 (2022 as amended) credit facility. Senior Notes In January 2015, the Company completed a public offering of $1.0 billion aggregate principal amount of its 4.95% Senior Notes due 2025 (the “2025 Notes”). The interest rate on the 2025 Notes is determined based upon the public bond ratings from Moody’s and S&P. Downgrades on the 2025 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. Effective in July 2018, the interest rate for the 2025 Notes was 6.20%, reflecting a net downgrade in the Company’s bond ratings since their issuance. On April 7, 2020, S&P downgraded the Company’s bond rating to BB-, which had the effect of increasing the interest rate on the 2025 Notes to 6.45% following the July 23, 2020 interest payment due date. The first coupon payment to the 2025 Notes bondholders at the higher interest rate was paid in January 2021. On September 1, 2021, S&P upgraded the Company’s bond rating to BB, and on January 6, 2022, S&P further upgraded the Company’s bond rating to BB+, which decreased the interest rate on the 2025 Notes to 5.95% beginning with coupon payments paid after January 2022. In August 2020, the Company completed a public offering of $350 million aggregate principal amount of its 8.375% Senior Notes due 2028 (the “2028 Notes”), with net proceeds from the offering totaling approximately $345 million after underwriting discounts and offering expenses. The 2028 Notes were sold to the public at 100% of their face value. The net proceeds from the notes, in conjunction with the net proceeds from the August 2020 common stock offering and borrowings under the 2018 credit facility, were utilized to fund a redemption of $510 million of Montage’s Notes in connection with the closing of the Montage Merger. On August 30, 2021, Southwestern closed its public offering of $1,200 million aggregate principal amount of its 5.375% Senior Notes due 2030 (the “2030 Notes”), with net proceeds from the offering totaling $1,183 million after underwriting discounts and offering expenses. The proceeds were used to repurchase the remaining $618 million of the Company’s 7.50% Senior Notes due 2026, $167 million of the Company’s 4.95% Senior Notes due 2025 and $6 million of the Company’s 4.10% Senior Notes due 2022 for $845 million, and the Company recognized a $60 million loss on the extinguishment of debt, which included the write-off of $6 million in related unamortized debt discounts and debt issuance costs. The remaining proceeds were used to pay borrowings under its 2018 credit facility and for general corporate purposes. Upon the close of the Indigo Merger on September 1, 2021, and pursuant to the terms of the Indigo Merger Agreement, Southwestern assumed $700 million in aggregate principal amount of Indigo’s 5.375% Senior Notes due 2029 (“Indigo Notes”). As part of purchase accounting, the assumption of the Indigo Notes resulted in a non-cash fair value adjustment of $26 million, based on the market price of 103.766% on September 1, 2021, the date that the Indigo Merger closed. Subsequent to the Indigo Merger, the Company exchanged the Indigo Notes for approximately $700 million of newly issued 5.375% Senior Notes due 2029, the offering of which was registered with the SEC in November 2021. On December 22, 2021, Southwestern closed its public offering of $1,150 million aggregate principal amount of its 4.75% Senior Notes due 2032 (the “2032 Notes”), with net proceeds from the offering totaling $1,133 million after underwriting discounts and offering expenses. The net proceeds of this offering, along with the net proceeds from the Term Loan, were used to fund the cash consideration portion of the GEPH Merger, which closed on December 31, 2021, and to pay $332 million to fund tender offers for $300 million of the Company’s 2025 Notes for which the Company recorded an additional loss on extinguishment of debt of $33 million, which included the write-off of $1 million in related unamortized debt discounts and debt issuance costs. The remaining proceeds were used for general corporate purposes.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Operating Commitments and Contingencies As of March 31, 2022, 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 $10.2 billion, $857 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 $877 million of that total amount. As of March 31, 2022, future payments under non-cancelable firm transportation and gathering agreements were as follows: Payments Due by Period (in millions) Total Less than 1 1 to 3 Years 3 to 5 Years 5 to 8 Years More than 8 Infrastructure currently in service $ 9,301 $ 1,066 $ 1,943 $ 1,729 $ 2,085 $ 2,478 Pending regulatory approval and/or construction (1) 857 3 124 161 247 322 Total transportation charges $ 10,158 $ 1,069 $ 2,067 $ 1,890 $ 2,332 $ 2,800 (1) Based on estimated in-service dates as of March 31, 2022. Prior to the Indigo Merger, in May 2021, Indigo closed on an agreement to divest its Cotton Valley natural gas and oil properties. Indigo retained certain contractual commitments related to volume commitments associated with natural gas gathering, for which Southwestern assumed the obligation to pay the gathering provider for any unused portion of the volume commitment under the agreement through 2027, depending on the buyer’s actual use. As of March 31, 2022, up to approximately $34 million of these contractual commitments remain (included in the table above), and the Company has recorded a $17 million liability for its portion of the estimated future payments. Excluding the Cotton Valley gathering agreement (discussed above), the Company has recorded additional liabilities totaling $35 million as of March 31, 2022, primarily related to purchase or volume commitments associated with gathering, fresh water and sand. These amounts are reflected above and will be recognized as payments are made over the next two 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, most of which 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 litigation, claims and proceedings when a liability is both probable and the amount can be reasonably estimated. As of March 31, 2022, the Company does not currently have any material amounts accrued related to litigation matters, including the cases discussed below. 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. Bryant Litigation As further discussed in Note 2 , on September 1, 2021, the Company completed its merger with Indigo, resulting in the assumption of Indigo’s existing litigation. On June 12, 2018, a collection of 51 individuals and entities filed a lawsuit against fifteen oil and gas company defendants, including Indigo, in Louisiana state court claiming damages arising out of current and historical development and production activity on certain acreage located in DeSoto Parish, Louisiana. The plaintiffs, who claim to own the properties at issue, assert that Indigo’s actions and the actions of other current operators conducting development and production activity, combined with the improper plugging and abandoning of legacy wells by former operators, have caused environmental contamination to their properties. Among other things, the plaintiffs contend that the defendants’ conduct resulted in the migration of natural gas, along with oilfield contaminants, into the Carrizo-Wilcox aquifer system underlying certain portions of DeSoto Parish. The plaintiffs assert claims based in tort, breach of contract and for violations of the Louisiana Civil and Mineral Codes, and they seek injunctive relief and monetary damages in an unspecified amount, including punitive damages. On September 13, 2018, Indigo filed a variety of exceptions in response to the plaintiffs’ petition in this matter. Since the initial filing, supplemental petitions have been filed joining additional individuals and entities as plaintiffs in the matter. On September 29, 2020, plaintiffs filed their fourth supplemental and amending petition in response to the court’s order ruling that plaintiffs’ claims were improperly vague and failed to identify with reasonable specificity the defendants’ allegedly wrongful conduct. Indigo and the majority of the other defendants filed several exceptions to plaintiffs’ fourth amended petition challenging the sufficiency of plaintiffs’ allegations and seeking dismissal of certain claims. On February 18, 2021, plaintiffs filed a fifth supplemental and amending petition, which seeks to augment the claims of select plaintiffs. On October 11, 2021, a sixth supplemental petition was filed which seeks to add the Company as a party to the litigation. The presence of natural gas in a localized area of the Carrizo-Wilcox aquifer system in DeSoto Parish is currently the subject of a regulatory investigation by the Louisiana Office of Conservation (“Conservation”), and the Company is cooperating and coordinating with Conservation in that investigation. The Conservation matter number is EMER18-003. The Company does not currently expect this matter to have a material impact on its financial position, results of operations, cash flows or liquidity. 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.

INCOME TAXES

INCOME TAXES	3 Months Ended
	Mar. 31, 2022
Income Tax Expense (Benefit), Continuing Operations [Abstract]
INCOME TAXES	INCOME TAXES The Company’s effective tax rate was approximately 0% for the three months ended March 31, 2022. The effective tax rate for the three months ended March 31, 2022 related to the effects of a valuation allowance against the Company’s U.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 current and forecasted business economics of the oil and gas industry. As of the first quarter of 2022, the Company still maintains a full valuation allowance. The Company also retained a valuation allowance of $59 million related to net operating losses in jurisdictions in which it no longer operates. Management will continue to assess available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. The amount of the deferred tax asset considered realizable, however, could be adjusted based on changes in subjective estimates of future taxable income or if objective negative evidence is no longer present. The Company intends to continue a full valuation allowance on its deferred tax assets until there is sufficient evidence to support the reversal of all or some portion of the allowance. However, if current commodity prices are sustained and absent any additional objective negative evidence, it is reasonably possible that sufficient positive evidence will exist within the next 12 months to adjust the current valuation allowance position. Exact timing and amount of the adjustment to the valuation allowance is unknown at this time. The Company’s effective tax rate was approximately 0% for the three months ended March 31, 2021. The effective tax rate for the three months ended March 31, 2021 related to the effects of the valuation allowance against the Company’s U.S. deferred tax assets. Due to the issuance of common stock associated with the Indigo Merger, as discussed in Note 2 , the Company incurred a cumulative ownership change and as such, the Company’s net operating losses (“NOLs”) prior to the acquisition are subject to an annual limitation under Internal Revenue Code Section 382 of approximately $48 million. The ownership changes and resulting annual limitation will result in the expiration of NOLs or other tax attributes otherwise available, with a corresponding decrease in the Company’s valuation allowance. At March 31, 2022, the Company had approximately $4 billion of federal NOL carryovers, of which approximately $3 billion expire between 2035 and 2037 and $1 billion have an indefinite carryforward life. The Company currently estimates that approximately $2 billion of these federal NOLs will expire before they are able to be used. The non-expiring NOLs remain subject to a full valuation allowance. If a subsequent ownership change were to occur as a result of future transactions in the Company’s common stock, the Company’s use of remaining U.S. tax attributes may be further limited. For three months ended March 31, 2022, the Company recorded current income tax expense of approximately $4 million as it expects to pay cash income taxes for the year ended December 31, 2022.

PENSION PLAN AND OTHER POSTRETI

PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS	3 Months Ended
	Mar. 31, 2022
Retirement Benefits [Abstract]
PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS	PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS Prior to January 1, 2021, substantially all of the Company’s employees were covered by the defined benefit pension, a cash balance plan that provided benefits based upon a fixed percentage of an employee’s annual compensation. As part of an ongoing effort to reduce costs, the Company elected to freeze its pension plan effective January 1, 2021. Employees that were participants in the pension plan prior to January 1, 2021 continued to receive the interest component of the plan but no longer received the service component. On September 13, 2021, the Compensation Committee of the Board of Directors approved terminating the Company’s pension plan, effective December 31, 2021, subject to approval by the Internal Revenue Service. This decision, among other benefits, will provide plan participants quicker access to, and greater flexibility in, the management of participants’ respective benefits due under the plan. The Company has commenced the pension plan termination process, but the specific date for the completion of the process is unknown at this time and will depend on certain legal and regulatory requirements or approvals. As part of the termination process, the Company expects to distribute lump sum payments to or purchase annuities for the benefit of plan participants, which is dependent on the participants’ elections. The postretirement benefit plan provides contributory health care and life insurance benefits. Employees become eligible for these benefits if they meet age and service requirements. Generally, the benefits paid are a stated percentage of medical expenses reduced by deductibles and other coverages. Substantially all of the Company’s employees continue to be covered by the postretirement benefit plans. The Company accounts for its defined benefit pension and other postretirement plans by recognizing the funded status of each defined pension benefit plan and other postretirement benefit plan on the Company’s balance sheet. In the event a plan is overfunded, the Company recognizes an asset. Conversely, if a plan is underfunded, the Company recognizes a liability. Net periodic pension costs include the following components for the three months ended March 31, 2022 and 2021: Consolidated Statements of For the three months ended March 31, (in millions) 2022 2021 Service cost General and administrative expenses $ — $ — Interest cost Other Income (Loss), Net 1 1 Expected return on plan assets Other Income (Loss), Net — (1) Amortization of net loss Other Income (Loss), Net — — Settlement loss Other Income (Loss), Net — — Net periodic benefit cost $ 1 $ — The Company recognized an immaterial non-cash settlement loss in the first quarter of 2022. The Company’s other postretirement benefit plan had a net periodic benefit cost of less than $1 million for each of the three months ended March 31, 2022 and 2021. The Company does not expect to make any additional contributions to its pension plan during 2022 or thereafter until the plan termination is completed. The Company recognized liabilities of $12 million and $13 million related to its pension and other postretirement benefits as of both March 31, 2022 and December 31, 2021. 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 1,745 shares at March 31, 2022 and 2,035 shares at December 31, 2021.

LONG-TERM INCENTIVE COMPENSATIO

LONG-TERM INCENTIVE COMPENSATION	3 Months Ended
	Mar. 31, 2022
Share-based Payment Arrangement, Noncash Expense [Abstract]
LONG-TERM INCENTIVE COMPENSATION	LONG-TERM INCENTIVE COMPENSATION The Company’s long-term incentive compensation plans consist of a combination of stock-based awards that derive their value directly or indirectly from the Company’s common stock price, and cash-based awards that are fixed in amount but subject to meeting annual performance thresholds. Stock-Based Compensation 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 on a straight-line basis 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. 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 and capitalized expense over the vesting period of the award. 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. However, the Company has not granted stock options since February 2017. The Company issues shares of restricted stock, restricted stock units or performance cash awards to employees and directors which generally vest over three 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. The performance units granted in 2019, 2020 and 2021 cliff-vest at the end of three years. In February of 2021, the Company notified employees of a workforce reduction plan as a result of strategic realignments of the Company’s organizational structure. The reduction was substantially complete by the end of the first quarter of 2021. Affected employees were offered a severance package which, if applicable, included the current value of unvested long-term incentive 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 three months ended March 31, 2021. The Company recognized the following amounts in total related to long-term incentive compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Long-term incentive compensation – expensed $ 11 $ 13 Long-term incentive compensation – capitalized $ 7 $ 5 Equity-Classified Awards The Company recognized the following amounts in employee equity-classified stock-based compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Equity-classified awards – expensed $ 1 $ — Equity-classified awards – capitalized $ — $ — Equity-Classified Stock Options The following table summarizes equity-classified stock option activity for the three months ended March 31, 2022 and provides information for options outstanding and options exercisable as of March 31, 2022: Number Weighted Average (in thousands) Outstanding at December 31, 2021 3,006 $ 8.98 Granted — $ — Exercised — $ — Forfeited or expired (152) $ 26.35 Outstanding at March 31, 2022 2,854 $ 8.06 Exercisable at March 31, 2022 2,854 $ 8.06 Equity-Classified Restricted Stock The following table summarizes equity-classified restricted stock activity for the three months ended March 31, 2022 and provides information for unvested shares as of March 31, 2022: Number Weighted Average (in thousands) Unvested shares at December 31, 2021 242 $ 5.12 Granted — $ — Vested (43) $ 4.90 Forfeited — $ — Unvested shares at March 31, 2022 199 $ 5.17 As of March 31, 2022, there was less than $1 million of total unrecognized compensation cost related to the Company’s unvested equity-classified restricted stock grants. This cost is expected to be recognized over a weighted-average period of 1.6 years. Equity-Classified Restricted Stock Units As of March 31, 2022, there was $7 million of total unrecognized compensation cost related to the Company’s unvested equity-classified restricted stock units. This cost is expected to be recognized over a weighted-average period of 2.6 years. The following table summarizes equity-classified restricted stock units for the three months ended March 31, 2022 and provides information for unvested units as of March 31, 2022. Number Weighted Average (in thousands) Unvested units at December 31, 2021 37 $ 3.05 Granted 1,699 $ 4.45 Vested — $ — Forfeited (2) $ 3.05 Unvested units at March 31, 2022 1,734 $ 4.42 Equity-Classified Performance Units In each year beginning with 2018, the Company granted performance units that vest at the end of, or over, a three $5 million of total unrecognized compensation costs related to the Company’s unvested equity-classified performance units. This cost is expected to be recognized over a weighted-average period of 2.9 years. Number Weighted Average (in thousands) Unvested units at December 31, 2021 — $ — Granted 850 $ 6.04 Vested — $ — Forfeited — $ — Unvested units at March 31, 2022 850 $ 6.04 Liability-Classified Awards The Company recognized the following amounts in employee liability-classified stock-based compensation costs for the three months ended March 31, 2022: For the three months ended March 31, (in millions) 2022 2021 Liability-classified stock-based compensation cost – expensed $ 8 $ 13 Liability-classified stock-based compensation cost – capitalized $ 6 $ 5 Liability-Classified Restricted Stock Units In the first quarter of each year beginning with 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 liability classified awards granted in 2021 vest over a period of three years. 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 March 31, 2022, there was $23 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 1.6 years. The amount of unrecognized compensation cost for liability-classified awards will fluctuate over time as they are marked to market. Number Weighted Average (in thousands) Unvested units at December 31, 2021 7,937 $ 4.08 Granted — $ — Vested (3,806) $ 4.47 Forfeited (12) $ 7.01 Unvested units at March 31, 2022 4,119 $ 5.83 Liability-Classified Performance Units In each year beginning with 2018, the Company granted performance units that vest at the end of, or over, a three 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 (in thousands) Unvested units at December 31, 2021 9,515 $ 2.88 Granted 3,798 $ 1.00 Vested (1) (1,910) $ 6.45 Forfeited — $ — Unvested units at March 31, 2022 11,403 $ 3.51 (1) The 2019 Performance Unit Awards were treated as liability classified awards given the ability to settle in cash or stock. Upon vesting in February 2022, the determination was made to settle in stock. Cash-Based Compensation The Company recognized the following amounts in performance cash award compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Performance cash awards – expensed $ 2 $ — Performance cash awards – capitalized $ 1 $ — Performance Cash Awards In 2021 and 2020, the Company granted performance cash awards that vest over a 4-year period and are payable in cash on an annual basis. The value of each unit of the award equals one dollar. The Company recognizes the cost of these awards as general and administrative expense and capitalized expense over the vesting period of the awards. The performance cash awards granted in 2021 and 2020 include a performance condition determined annually by the Company. For both years, the performance measure is a targeted discretionary cash flow amount. If the Company, in its sole discretion, determines that the threshold was not met, the amount for that vesting period will not vest and will be cancelled. As of March 31, 2022, there was $42 million of total unrecognized compensation cost related to performance cash awards. This cost is expected to be recognized over a weighted-average period of 3.2 years. The final value of the performance cash awards is contingent upon the Company’s actual performance against these performance measures. Number Weighted Average Fair Value (in thousands) Unvested units at December 31, 2021 28,272 $ 1.00 Granted 24,416 $ 1.00 Vested (8,483) $ 1.00 Forfeited (675) $ 1.00 Unvested units at March 31, 2022 43,530 $ 1.00

SEGMENT INFORMATION

SEGMENT INFORMATION	3 Months Ended
	Mar. 31, 2022
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. The Company’s E&P segment is comprised of gas and oil properties which are managed as a whole rather than through discrete operating segments. Operational information for the Company’s E&P segment is tracked by geographic area; however, financial performance and allocation of resources are assessed at the segment level without regard to geographic area. Revenues for the E&P segment are derived from the production and sale of natural gas and liquids. The Marketing segment generates revenue through the marketing of both Company and third-party produced natural gas and liquids volumes. 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 2021 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, gain on early extinguishment of debt and other income (loss). The “Other” column includes items not related to the Company’s reportable segments, including real estate and corporate items. Corporate general and administrative costs, depreciation expense and taxes, other than income taxes, are allocated to the segments. Exploration and Production Marketing Other Total Three months ended March 31, 2022 (in millions) Revenues from external customers $ 2,077 $ 866 $ — $ 2,943 Intersegment revenues (3) 1,889 — 1,886 Depreciation, depletion and amortization expense 274 1 — 275 Impairments — — — — Operating income 1,278 (1) 21 — 1,299 Interest expense (2) 41 — — 41 Loss on derivatives (3,925) — (2) (3,927) Loss on extinguishment of debt — — (2) (2) Other income, net — — — — Provision for income taxes (2) 4 — — 4 Assets 10,766 (3) 969 112 11,847 Capital investments (4) 544 — — 544 Three months ended March 31, 2021 Revenues from external customers $ 719 $ 353 $ — $ 1,072 Intersegment revenues (14) 644 — 630 Depreciation, depletion and amortization expense 94 2 — 96 Operating income 295 (1) 6 — 301 Interest expense (2) 31 — — 31 Loss on derivatives (191) — — (191) Other income, net 1 — — 1 Assets 4,741 (3) 396 110 5,247 Capital investments (4) 266 — — 266 (1) Operating income (loss) for the E&P segment includes $6 million of restructuring charges for the three months ended 2021. The E&P segment operating income (loss) also includes $25 million and $1 million of merger-related expenses for the three months ended March 31, 2022 and 2021, 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. (4) Capital investments include increases of $43 million and $38 million for the three months ended March 31, 2022 and 2021, respectively, relating to the change in accrued expenditures between periods. The following table presents the breakout of other assets, which represent corporate assets not allocated to segments and assets for non-reportable segments at March 31, 2022 and 2021: As of March 31, (in millions) 2022 2021 Cash and cash equivalents $ 21 $ 4 Accounts receivable 1 — Prepayments 6 6 Property, plant and equipment 10 15 Unamortized debt expense 9 11 Right-of-use lease assets 63 70 Non-qualified retirement plan 2 4 $ 112 $ 110

NEW ACCOUNTING PRONOUNCEMENTS

NEW ACCOUNTING PRONOUNCEMENTS	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
NEW ACCOUNTING PRONOUNCEMENTS	NEW ACCOUNTING PRONOUNCEMENTS New Accounting Standards Implemented in this Report In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform, as a new ASC Topic, ASC 848. The purpose of ASC 848 is to provide optional guidance to ease the potential effects on financial reporting of the market-wide migration away from Interbank Offered Rates, such as LIBOR, to alternative reference rates. ASC 848 applies only to contracts, hedging relationships, debt arrangements and other transactions that reference a benchmark reference rate expected to be discontinued because of reference rate reform. ASC 848 contains optional expedients and exceptions for applying U.S. GAAP to transactions affected by this reform. The amendments in the ASU are effective for all entities as of March 12, 2020 through December 31, 2022. As discussed in Note 11 , the Company amended and extended its credit facility which is subject to SOFR interest rates beginning in the second quarter of 2022. The change from LIBOR to SOFR rates will not have a material impact on the Company’s consolidated financial statements. New Accounting Standards Not Yet Adopted in this Report

New Accounting Pronouncements (

New Accounting Pronouncements (Policies)	3 Months Ended
	Mar. 31, 2022
Accounting Policies [Abstract]
New Accounting Standards Implemented in this Report and New Accounting Standards Not Yet Adopted in this Report	New Accounting Standards Implemented in this Report In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform, as a new ASC Topic, ASC 848. The purpose of ASC 848 is to provide optional guidance to ease the potential effects on financial reporting of the market-wide migration away from Interbank Offered Rates, such as LIBOR, to alternative reference rates. ASC 848 applies only to contracts, hedging relationships, debt arrangements and other transactions that reference a benchmark reference rate expected to be discontinued because of reference rate reform. ASC 848 contains optional expedients and exceptions for applying U.S. GAAP to transactions affected by this reform. The amendments in the ASU are effective for all entities as of March 12, 2020 through December 31, 2022. As discussed in Note 11 , the Company amended and extended its credit facility which is subject to SOFR interest rates beginning in the second quarter of 2022. The change from LIBOR to SOFR rates will not have a material impact on the Company’s consolidated financial statements. New Accounting Standards Not Yet Adopted in this Report

Acquisitions (Tables)

Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2022
Business Combination and Asset Acquisition [Abstract]
Schedule of Business Acquisitions by Acquisition, Equity Interest Issued or Issuable	The following table presents the fair value of consideration transferred to GEPH equity holders as a result of the GEPH Merger: (in millions, except share, per share amounts) As of December 31, 2021 Shares of Southwestern common stock issued 99,337,748 NYSE closing price per share of Southwestern common shares on December 31, 2021 $ 4.66 $ 463 Cash consideration 1,269 Total consideration $ 1,732 (in millions, except share, per share amounts) As of September 1, 2021 Shares of Southwestern common stock issued 337,827,171 NYSE closing price per share of Southwestern common shares on September 1, 2021 $ 4.70 $ 1,588 Cash consideration 373 Total consideration $ 1,961
Schedule of Business Acquisitions, by Acquisition	The following table sets forth the preliminary fair value of the assets acquired and liabilities assumed as of the acquisition date. Certain data necessary to complete the purchase price allocation is still under evaluation, including, but not limited to, the final actualization of accrued liabilities and receivable balances as well as the valuation of natural gas and oil properties. The Company will finalize the purchase price allocation during the twelve-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. (in millions) As of December 31, 2021 Consideration: Total consideration $ 1,732 Fair Value of Assets Acquired: Cash and cash equivalents 11 Accounts receivable 171 Other current assets 3 Commodity derivative assets 56 Evaluated oil and gas properties 1,783 Unevaluated oil and gas properties (1) 58 Other property, plant and equipment 2 Other long-term assets 3 Total assets acquired 2,087 Fair Value of Liabilities Assumed: Accounts payable (2) 164 Other current liabilities 1 Derivative liabilities 75 Revolving credit facility 81 Asset retirement obligations 24 Other noncurrent liabilities (2) 10 Total liabilities assumed 355 Net Assets Acquired and Liabilities Assumed $ 1,732 (1) Reflects $1 million purchase price adjustment during the three months ended March 31, 2022. (2) Reflects purchase price adjustments reflecting a decrease of $6 million to accounts payable and a $5 million increase to other noncurrent liabilities during the three months ended March 31, 2022. (in millions) As of September 1, 2021 Consideration: Total consideration $ 1,961 Fair Value of Assets Acquired: Cash and cash equivalents 55 Accounts receivable 192 Other current assets 2 Commodity derivative assets 2 Evaluated oil and gas properties 2,724 Unevaluated oil and gas properties (1) 693 Other property, plant and equipment 4 Other long-term assets 27 Total assets acquired 3,699 Fair Value of Liabilities Assumed: Accounts payable (1) 283 Other current liabilities 55 Derivative liabilities 501 Revolving credit facility 95 Senior unsecured notes 726 Asset retirement obligations 8 Other noncurrent liabilities 70 Total liabilities assumed 1,738 Net Assets Acquired and Liabilities Assumed $ 1,961 (1) Reflects $9 million purchase price adjustment during the three months ended March 31, 2022.
Schedule of Acquisition Related Costs	The following table summarizes the merger-related expenses incurred: For the three months ended March 31, 2022 2021 (in millions) Indigo Merger GEPH Merger Total Montage Merger Transition services $ — $ 18 $ 18 $ — Professional fees (bank, legal, consulting) — 1 1 — Contract buyouts, terminations and transfers — 2 2 — Due diligence and environmental 1 — 1 — Employee-related — 1 1 1 Other — 2 2 — Total merger-related expenses $ 1 $ 24 $ 25 $ 1
Business Acquisition, Pro Forma Information	The following table summarizes the unaudited pro forma condensed financial information for the three months ended March 31, 2021 as if the Indigo Merger and the GEPH Merger each had occurred on January 1, 2020: (in millions) For the three months ended Revenues $ 1,471 Net income attributable to common stock $ 30 Net income attributable to common stock per share - basic $ 0.03 Net income attributable to common stock per share - diluted $ 0.03

Restructuring Charges (Tables)

Restructuring Charges (Tables)	3 Months Ended
	Mar. 31, 2022
Restructuring and Related Activities [Abstract]
Summary of Restructuring Charges	The following table presents a summary of the restructuring charges included in Operating Income for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Severance (including payroll taxes) (1) $ — $ 6

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue by Segment	The following table reconciles operating revenues as presented on the consolidated statements of operations to the operating revenues by segment: (in millions) E&P Marketing Intersegment Total Three months ended March 31, 2022 Gas sales $ 1,690 $ — $ 2 $ 1,692 Oil sales 110 — 1 111 NGL sales 272 — — 272 Marketing — 2,755 (1,889) 866 Other (1) 2 — — 2 Total $ 2,074 $ 2,755 $ (1,886) $ 2,943 Three months ended March 31, 2021 Gas sales $ 451 $ — $ 13 $ 464 Oil sales 80 — 1 81 NGL sales 173 — — 173 Marketing — 996 (644) 352 Other (2) 1 1 — 2 Total $ 705 $ 997 $ (630) $ 1,072 (1) For the three months ended March 31, 2022, other E&P revenues consists primarily of gains on purchaser imbalances associated with natural gas and certain NGLs. (2) For the three months ended March 31, 2021, other E&P revenues consists primarily of gains on purchaser imbalances associated with certain NGLs and other Marketing revenues consists primarily of sales of gas from storage.
Disaggregation of Revenue on Geographic Basis	Associated E&P revenues are also disaggregated for analysis on a geographic basis by the core areas in which the Company operates, which are primarily Appalachia and Haynesville. For the three months (in millions) 2022 2021 Appalachia $ 1,321 $ 704 Haynesville 753 — Other — 1 Total $ 2,074 $ 705
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) March 31, 2022 December 31, 2021 Receivables from contracts with customers $ 972 $ 1,085 Other accounts receivable 99 75 Total accounts receivable $ 1,071 $ 1,160

Cash and Cash Equivalents (Tabl

Cash and Cash Equivalents (Tables)	3 Months Ended
	Mar. 31, 2022
Cash and Cash Equivalents [Abstract]
Summary of Cash and Cash Equivalents	The following table presents a summary of cash and cash equivalents as of March 31, 2022 and December 31, 2021: (in millions) March 31, 2022 December 31, 2021 Cash $ 21 $ 28 Marketable securities (1) — — Total $ 21 $ 28 (1) Typically consists of government stable value money market funds.

Natural Gas and Oil Properties

Natural Gas and Oil Properties (Tables)	3 Months Ended
	Mar. 31, 2022
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and Gas Exploration and Production Industries Disclosures	Prices used to calculate the ceiling value of reserves were as follows: March 31, 2022 March 31, 2021 Natural gas (per MMBtu) $ 4.09 $ 2.16 Oil (per Bbl) $ 75.39 $ 40.01 NGLs (per Bbl) $ 32.75 $ 13.57

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2022
Earnings Per Share [Abstract]
Schedule of Earnings Per Share	The following table presents the computation of earnings per share for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions, except share/per share amounts) 2022 2021 Net income (loss) $ (2,675) $ 80 Number of common shares: Weighted average outstanding 1,114,610,964 675,385,145 Issued upon assumed exercise of outstanding stock options — — Effect of issuance of non-vested restricted common stock — 870,541 Effect of issuance of non-vested restricted units — 804,944 Effect of issuance of non-vested performance units — 2,807,195 Weighted average and potential dilutive outstanding 1,114,610,964 679,867,825 Earnings (loss) per common share Basic $ (2.40) $ 0.12 Diluted $ (2.40) $ 0.12
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following table presents the common stock shares equivalent excluded from the calculation of diluted earnings per share for the three months ended March 31, 2022 and 2021, as they would have had an antidilutive effect: For the three months ended March 31, 2022 2021 Unexercised stock options 2,948,488 3,795,091 Stock-based compensation 1,436,920 — Restricted stock units 2,528,005 3,987,291 Performance units 1,917,579 — Total 8,830,992 7,782,382

Derivatives and Risk Manageme_2

Derivatives and Risk Management (Tables)	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments Notional Amount, Weighted Average Contract Prices and Fair Value	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 March 31, 2022: Financial Protection on Production Weighted Average Price per MMBtu Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential Fair Value at March 31, 2022 (in millions) Natural Gas 2022 Fixed price swaps 627 $ 3.04 $ — $ — $ — $ — $ (1,672) Two-way costless collars 78 — — 2.53 2.92 — (216) Three-way costless collars 277 — 2.03 2.48 2.88 — (784) Total 982 $ (2,672) 2023 Fixed price swaps 504 $ 3.08 $ — $ — $ — $ — $ (675) Two-way costless collars 219 — — 3.03 3.55 — (217) Three-way costless collars 215 — 2.09 2.54 3.00 — (355) Total 938 $ (1,247) 2024 Fixed price swaps 224 $ 2.96 $ — $ — $ — $ — $ (174) Two-way costless collars 44 — — 3.07 3.53 — (19) Three-way costless collars 11 — 2.25 2.80 3.54 — (12) Total 279 $ (205) Basis Swaps 2022 277 $ — $ — $ — $ — $ (0.53) $ 72 2023 250 — — — — (0.47) 20 2024 46 — — — — (0.71) 9 2025 9 — — — — (0.64) 3 Total 582 $ 104 Volume (MBbls) Weighted Average Strike Price per Bbl Fair Value at March 31, 2022 (in millions) Swaps Sold Puts Purchased Puts Sold Calls Oil 2022 Fixed price swaps 2,376 $ 53.32 $ — $ — $ — $ (94) Three-way costless collars 1,037 — 39.83 50.17 57.01 (38) Total 3,413 $ (132) 2023 Fixed price swaps 846 $ 55.98 $ — $ — $ — $ (23) Three-way costless collars 1,268 — 33.97 45.51 56.12 (36) Total 2,114 $ (59) 2024 Fixed price swaps 603 $ 68.68 $ — $ — $ — $ (5) Ethane 2022 Fixed price swaps 4,142 $ 11.27 $ — $ — $ — $ (26) 2023 Fixed price swaps 1,308 $ 11.91 $ — $ — $ — $ (3) Propane 2022 Fixed price swaps 4,643 $ 31.09 $ — $ — $ — $ (118) Three-way costless collars 230 — 16.80 21.00 31.92 (6) Total 4,873 $ (124) 2023 Fixed price swaps 1,066 $ 37.15 $ — $ — $ — $ (8) Normal Butane 2022 Fixed price swaps 1,388 $ 36.22 $ — $ — $ — $ (43) 2023 Fixed price swaps 329 $ 40.64 $ — $ — $ — $ (3) Natural Gasoline 2022 Fixed price swaps 1,497 $ 55.78 $ — $ — $ — $ (57) 2023 Fixed price swaps 359 $ 66.00 $ — $ — $ — $ (5) Other Derivative Contracts Volume (Bcf) Weighted Average Strike Price per MMBtu Fair Value at March 31, 2022 (in millions) Call Options – Natural Gas (Net) 2022 63 $ 3.01 $ (171) 2023 46 2.94 (74) 2024 9 3.00 (13) Total 118 $ (258) Volume (Bcf) Weighted Average Strike Price per MMBtu Fair Value at March 31, 2022 (in millions) Swaps Basis Differential Storage (1) 2022 Purchased fixed price swaps — $ 2.14 $ — $ 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 and sold at a later date.
Balance Sheet Classification of Derivative Financial Instruments	The balance sheet classification of the assets and liabilities related to derivative financial instruments are summarized below as of March 31, 2022 and December 31, 2021: Derivative Assets Fair Value (in millions) Balance Sheet Classification March 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments: Fixed price swaps – natural gas Derivative assets $ — $ 79 Fixed price swaps – ethane Derivative assets — 2 Fixed price swaps – propane Derivative assets — 2 Fixed price swaps – normal butane Derivative assets — 1 Two-way costless collars – natural gas Derivative assets 10 9 Three-way costless collars – natural gas Derivative assets 9 12 Three-way costless collars – oil Derivative assets 1 1 Basis swaps – natural gas Derivative assets 82 77 Purchased fixed price swaps – natural gas storage Derivative assets 1 — Fixed price swaps – natural gas Other long-term assets — 64 Two-way costless collars – natural gas Other long-term assets 44 100 Three-way costless collars – natural gas Other long-term assets 12 37 Three-way costless collars – oil Other long-term assets 1 3 Basis swaps – natural gas Other long-term assets 70 22 Interest rate swaps Other long-term assets — 2 Total derivative assets $ 230 $ 411 Derivative Liabilities Fair Value (in millions) Balance Sheet Classification March 31, 2022 December 31, 2021 Derivatives not designated as hedging instruments: Fixed price swaps – natural gas storage Derivative liabilities $ — $ 1 Fixed price swaps – natural gas Derivative liabilities 1,999 565 Fixed price swaps – oil Derivative liabilities 101 60 Fixed price swaps – ethane Derivative liabilities 28 10 Fixed price swaps – propane Derivative liabilities 122 78 Fixed price swaps – normal butane Derivative liabilities 44 27 Fixed price swaps – natural gasoline Derivative liabilities 59 33 Two-way costless collars – natural gas Derivative liabilities 316 104 Two-way costless collars – ethane Derivative liabilities — 1 Three-way costless collars – natural gas Derivative liabilities 977 298 Three-way costless collars – oil Derivative liabilities 49 24 Three-way costless collars – propane Derivative liabilities 6 4 Basis swaps – natural gas Derivative liabilities 43 9 Call options – natural gas Derivative liabilities 201 67 Fixed price swaps – natural gas Long-term derivative liabilities 522 246 Fixed price swaps – oil Long-term derivative liabilities 21 9 Fixed price swaps – ethane Long-term derivative liabilities 1 — Fixed price swaps – propane Long-term derivative liabilities 4 1 Fixed price swaps – normal butane Long-term derivative liabilities 2 — Fixed price swaps – natural gasoline Long-term derivative liabilities 3 1 Two-way costless collars – natural gas Long-term derivative liabilities 190 115 Three-way costless collars – natural gas Long-term derivative liabilities 195 178 Three-way costless collars – oil Long-term derivative liabilities 27 21 Basis swap – natural gas Long-term derivative liabilities 5 22 Call options – natural gas Long-term derivative liabilities 57 42 Total derivative liabilities $ 4,972 $ 1,916 Net Derivative Position March 31, 2022 December 31, 2021 (in millions) Net current derivative liabilities $ (3,842) $ (1,098) Net long-term derivative liabilities (900) (407) Non-performance risk adjustment 8 3 Net total derivative liabilities $ (4,734) $ (1,502)
Summary of Before Tax Effect of Fair Value Hedges not Designated for Hedge Accounting	The following tables summarize the before-tax effect of the Company’s derivative instruments on the consolidated statements of operations for the three months ended March 31, 2022 and 2021: Unsettled Gain (Loss) on Derivatives Recognized in Earnings Consolidated Statement of Operations Classification of Gain (Loss) on Derivatives, Unsettled For the three months ended March 31, Derivative Instrument 2022 2021 (in millions) Fixed price swaps – natural gas Gain (Loss) on Derivatives $ (1,853) $ (22) Fixed price swaps – oil Gain (Loss) on Derivatives (53) (40) Fixed price swaps – ethane Gain (Loss) on Derivatives (21) (2) Fixed price swaps – propane Gain (Loss) on Derivatives (49) (45) Fixed price swaps – normal butane Gain (Loss) on Derivatives (20) (15) Fixed price swaps – natural gasoline Gain (Loss) on Derivatives (28) (20) Two-way costless collars – natural gas Gain (Loss) on Derivatives (342) (12) Two-way costless collars – oil Gain (Loss) on Derivatives — (1) Two-way costless collars – ethane Gain (Loss) on Derivatives 1 — Three-way costless collars – natural gas Gain (Loss) on Derivatives (724) — Three-way costless collars – oil Gain (Loss) on Derivatives (33) (18) Three-way costless collars – propane Gain (Loss) on Derivatives (2) (1) Basis swaps – natural gas Gain (Loss) on Derivatives 36 3 Call options – natural gas Gain (Loss) on Derivatives (149) 3 Call options – oil Gain (Loss) on Derivatives — (1) Swaptions – natural gas Gain (Loss) on Derivatives — 1 Purchased fixed price swap – natural gas storage Gain (Loss) on Derivatives 1 — Fixed price swap – natural gas storage Gain (Loss) on Derivatives 1 — Interest rate swaps Gain (Loss) on Derivatives (2) 1 Total loss on unsettled derivatives $ (3,237) $ (169) Settled Gain (Loss) on Derivatives Recognized in Earnings (1) Consolidated Statement of Operations Classification of Gain (Loss) on Derivatives, Settled For the three months ended March 31, Derivative Instrument 2022 2021 (in millions) Fixed price swaps – natural gas Gain (Loss) on Derivatives $ (297) $ 5 Fixed price swaps – oil Gain (Loss) on Derivatives (33) (17) Fixed price swaps – ethane Gain (Loss) on Derivatives (8) (4) Fixed price swaps – propane Gain (Loss) on Derivatives (41) (30) Fixed price swaps – normal butane Gain (Loss) on Derivatives (14) (7) Fixed price swaps – natural gasoline Gain (Loss) on Derivatives (19) (9) Two-way costless collars – natural gas Gain (Loss) on Derivatives (104) 2 Two-way costless collars – oil Gain (Loss) on Derivatives — (1) Two-way costless collars – ethane Gain (Loss) on Derivatives (1) — Three-way costless collars – natural gas Gain (Loss) on Derivatives (121) 1 Three-way costless collars – oil Gain (Loss) on Derivatives (13) (1) Three-way costless collars – propane Gain (Loss) on Derivatives (2) — Basis swaps – natural gas Gain (Loss) on Derivatives 1 41 Index swaps – natural gas Gain (Loss) on Derivatives (1) — Call options – natural gas Gain (Loss) on Derivatives (39) — Put options – natural gas Gain (Loss) on Derivatives — (2) (2) Fixed price swaps – natural gas storage Gain (Loss) on Derivatives (3) — Total loss on settled derivatives $ (695) $ (22) (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 $2 million in amortization of premiums paid related to certain natural gas put options for the three months ended March 31, 2021, which is included in gain (loss) on derivatives on the consolidated statements of operations. Total Gain (Loss) on Derivatives Recognized in Earnings For the three months ended March 31, 2022 2021 (in millions) Total loss on unsettled derivatives $ (3,237) $ (169) Total loss on settled derivatives (695) (22) Non-performance risk adjustment 5 — Total loss on derivatives $ (3,927) $ (191)

Reclassifications from Accumu_2

Reclassifications from Accumulated Other Comprehensive Income (Loss) (Tables)	3 Months Ended
	Mar. 31, 2022
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Components of Accumulated Other Comprehensive Income (Loss)	The following tables detail the components of accumulated other comprehensive income and the related tax effects for the three months ended March 31, 2022: (in millions) Pension and Other Postretirement Foreign Currency Total Beginning balance December 31, 2021 $ (11) $ (14) $ (25) Other comprehensive income before reclassifications — — — Amounts reclassified from other comprehensive income (1) — — — Net current-period other comprehensive income — — — Ending balance March 31, 2022 $ (11) $ (14) $ (25) (1) For the three months ended March 31, 2022, the amounts reclassified from accumulated other comprehensive income was less than $1 million. See Note 14 for additional details regarding the Company’s pension and other postretirement benefit plans.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2022
Fair Value Disclosures [Abstract]
Carrying Amount and Estimated Fair Values of Financial Instruments	The carrying amounts and estimated fair values of the Company’s financial instruments as of March 31, 2022 and December 31, 2021 were as follows: March 31, 2022 December 31, 2021 (in millions) Carrying Fair Carrying Fair Cash and cash equivalents $ 21 $ 21 $ 28 $ 28 2018 revolving credit facility due April 2024 174 174 460 460 Term Loan B due 2027 549 549 550 550 Senior notes (1) 4,209 4,318 4,430 4,745 Derivative instruments, net (4,734) (4,734) (1,502) (1,502) (1) Excludes unamortized debt issuance costs and debt discounts.
Summary of Assets and Liabilities Measured at Fair Value on Recurring Basis	Assets and liabilities measured at fair value on a recurring basis are summarized below: March 31, 2022 Fair Value Measurements Using: (in millions) Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets (Liabilities) at Fair Value Assets Two-way costless collars $ — $ 54 $ — $ 54 Three-way costless collars — 23 — 23 Basis swaps — 152 — 152 Purchased fixed price swaps – storage — 1 — 1 Liabilities Fixed price swaps — (2,906) — (2,906) Two-way costless collars — (506) — (506) Three-way costless collars — (1,254) — (1,254) Basis swaps — (48) — (48) Call options — (258) — (258) Total (1) $ — $ (4,742) $ — $ (4,742) (1) Excludes a net reduction to the liability fair value of $8 million related to estimated non-performance risk. December 31, 2021 Fair Value Measurements Using: (in millions) Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets (Liabilities) at Fair Value Assets Fixed price swaps $ — $ 148 $ — $ 148 Two-way costless collars — 109 — 109 Three-way costless collars — 53 — 53 Basis swaps — 99 — 99 Interest rate swaps — 2 — 2 Liabilities Fixed price swaps — (1,031) — (1,031) Two-way costless collars — (220) — (220) Three-way costless collars — (525) — (525) Basis swaps — (31) — (31) Call options — (109) — (109) Total (1) $ — $ (1,505) $ — $ (1,505) (1) Excludes a net reduction to the liability fair value of $3 million related to estimated non-performance risk.

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Components of Debt	The components of debt as of March 31, 2022 and December 31, 2021 consisted of the following: March 31, 2022 (in millions) Debt Instrument Unamortized Issuance Expense Unamortized Debt Premium/Discount Total Current portion of long-term debt: Variable rate (3.3% at March 31, 2022) Term Loan B due June 2027 $ 5 (1) $ — $ — $ 5 Total current portion of long-term debt $ 5 $ — $ — $ 5 Long-term debt: Variable rate (2.10% at March 31, 2022) 2018 revolving credit facility due April 2024 $ 174 $ — (2) $ — $ 174 4.95% Senior Notes due January 2025 (3) 389 (1) — 388 Variable rate (3.3% at March 31, 2022) Term Loan B due June 2027 544 (7) (1) 536 7.75% Senior Notes due October 2027 425 (4) — 421 8.375% Senior Notes due September 2028 345 (5) — 340 5.375% Senior Notes due February 2029 700 (6) 24 718 5.375% Senior Notes due September 2030 1,200 (16) — 1,184 4.75% Senior Notes due February 2032 1,150 (16) — 1,134 Total long-term debt $ 4,927 $ (55) $ 23 $ 4,895 Total debt $ 4,932 $ (55) $ 23 $ 4,900 December 31, 2021 (in millions) Debt Instrument Unamortized Issuance Expense Unamortized Debt Premium/Discount Total Current portion of long-term debt: 4.10% Senior Notes due March 2022 $ 201 $ — $ — $ 201 Variable rate (3.0% at December 31, 2021) Term Loan B due June 2027 5 (1) — — 5 Total current portion of long-term debt $ 206 $ — $ — $ 206 Long-term debt: Variable rate (2.08% at December 31, 2021) 2018 revolving credit facility, due April 2024 $ 460 $ — (2) $ — $ 460 4.95% Senior Notes due January 2025 (3) 389 (1) — 388 Variable rate (3.0% at December 31, 2021) Term Loan B due June 2027 545 (7) (1) 537 7.75% Senior Notes due October 2027 440 (4) — 436 8.375% Senior Notes due September 2028 350 (5) — 345 5.375% Senior Notes due September 2029 700 (6) 25 719 5.375% Senior Notes due March 2030 1,200 (17) — 1,183 4.75% Senior Notes due February 2032 1,150 (17) — 1,133 Total long-term debt $ 5,234 $ (57) $ 24 $ 5,201 Total debt $ 5,440 $ (57) $ 24 $ 5,407 (1) The Term Loan requires quarterly principal repayments of $1.375 million, subject to adjustment for voluntary prepayments, beginning in March 2022. (2) At March 31, 2022 and December 31, 2021, unamortized issuance expense of $9 million and $10 million, respectively, associated with the 2018 credit facility (as defined below) was classified as other long-term assets on the consolidated balance sheets. (3) Effective in July 2018, the interest rate was 6.20% for the 2025 Notes, reflecting a net downgrade in the Company’s bond ratings since the initial offering. On April 7, 2020, S&P downgraded the Company’s bond rating to BB-, which had the effect of increasing the interest rate on the 2025 Notes to 6.45% following the July 23, 2020 interest payment date. The first coupon payment to the bondholders at the higher interest rate was paid in January 2021. On
Schedule of Maturities of Long-term Debt	The following is a summary of scheduled debt maturities by year as of March 31, 2022 and includes the quarterly Term Loan principal repayments of $1.375 million, subject to adjustment for voluntary prepayments, beginning in March 2022: (in millions) 2022 $ 4 2023 6 2024 (1) 179 2025 395 2026 5 Thereafter 4,343 $ 4,932

Commitments and Contingencies (

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Obligation under Transportation Agreements	As of March 31, 2022, future payments under non-cancelable firm transportation and gathering agreements were as follows: Payments Due by Period (in millions) Total Less than 1 1 to 3 Years 3 to 5 Years 5 to 8 Years More than 8 Infrastructure currently in service $ 9,301 $ 1,066 $ 1,943 $ 1,729 $ 2,085 $ 2,478 Pending regulatory approval and/or construction (1) 857 3 124 161 247 322 Total transportation charges $ 10,158 $ 1,069 $ 2,067 $ 1,890 $ 2,332 $ 2,800 (1) Based on estimated in-service dates as of March 31, 2022.

Pension Plan and Other Postre_2

Pension Plan and Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2022
Retirement Benefits [Abstract]
Pension and Other Postretirement Benefit Costs	Net periodic pension costs include the following components for the three months ended March 31, 2022 and 2021: Consolidated Statements of For the three months ended March 31, (in millions) 2022 2021 Service cost General and administrative expenses $ — $ — Interest cost Other Income (Loss), Net 1 1 Expected return on plan assets Other Income (Loss), Net — (1) Amortization of net loss Other Income (Loss), Net — — Settlement loss Other Income (Loss), Net — — Net periodic benefit cost $ 1 $ —

Long-term Incentive Compensat_2

Long-term Incentive Compensation (Tables)	3 Months Ended
	Mar. 31, 2022
Share-based Payment Arrangement, Noncash Expense [Abstract]
Schedule of Stock-Based Compensation Costs	The Company recognized the following amounts in total related to long-term incentive compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Long-term incentive compensation – expensed $ 11 $ 13 Long-term incentive compensation – capitalized $ 7 $ 5
Schedule of Equity-Classified Stock-Based Compensation Costs	The Company recognized the following amounts in employee equity-classified stock-based compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Equity-classified awards – expensed $ 1 $ — Equity-classified awards – capitalized $ — $ —
Summary of Equity-Classified Stock Option Activity	The following table summarizes equity-classified stock option activity for the three months ended March 31, 2022 and provides information for options outstanding and options exercisable as of March 31, 2022: Number Weighted Average (in thousands) Outstanding at December 31, 2021 3,006 $ 8.98 Granted — $ — Exercised — $ — Forfeited or expired (152) $ 26.35 Outstanding at March 31, 2022 2,854 $ 8.06 Exercisable at March 31, 2022 2,854 $ 8.06
Summary of Equity-Classified Restricted Stock Activity	The following table summarizes equity-classified restricted stock activity for the three months ended March 31, 2022 and provides information for unvested shares as of March 31, 2022: Number Weighted Average (in thousands) Unvested shares at December 31, 2021 242 $ 5.12 Granted — $ — Vested (43) $ 4.90 Forfeited — $ — Unvested shares at March 31, 2022 199 $ 5.17
Summary of Equity-Classified Restricted and Performance Stock Units Activity	The following table summarizes equity-classified restricted stock units for the three months ended March 31, 2022 and provides information for unvested units as of March 31, 2022. Number Weighted Average (in thousands) Unvested units at December 31, 2021 37 $ 3.05 Granted 1,699 $ 4.45 Vested — $ — Forfeited (2) $ 3.05 Unvested units at March 31, 2022 1,734 $ 4.42 Number Weighted Average (in thousands) Unvested units at December 31, 2021 — $ — Granted 850 $ 6.04 Vested — $ — Forfeited — $ — Unvested units at March 31, 2022 850 $ 6.04
Schedule of Liability-Classified Stock-Based Compensation Costs	The Company recognized the following amounts in employee liability-classified stock-based compensation costs for the three months ended March 31, 2022: For the three months ended March 31, (in millions) 2022 2021 Liability-classified stock-based compensation cost – expensed $ 8 $ 13 Liability-classified stock-based compensation cost – capitalized $ 6 $ 5
Summary of Liability-Classified Restricted Stock Unit Activity	Number Weighted Average (in thousands) Unvested units at December 31, 2021 7,937 $ 4.08 Granted — $ — Vested (3,806) $ 4.47 Forfeited (12) $ 7.01 Unvested units at March 31, 2022 4,119 $ 5.83
Summary of Liability-Classified Performance Unit Activity	Number Weighted Average (in thousands) Unvested units at December 31, 2021 9,515 $ 2.88 Granted 3,798 $ 1.00 Vested (1) (1,910) $ 6.45 Forfeited — $ — Unvested units at March 31, 2022 11,403 $ 3.51 (1) The 2019 Performance Unit Awards were treated as liability classified awards given the ability to settle in cash or stock. Upon vesting in February 2022, the determination was made to settle in stock.
Schedule of Performance Cash Award Compensation Costs	The Company recognized the following amounts in performance cash award compensation costs for the three months ended March 31, 2022 and 2021: For the three months ended March 31, (in millions) 2022 2021 Performance cash awards – expensed $ 2 $ — Performance cash awards – capitalized $ 1 $ —
Summary of Performance Cash Awards Activity	Number Weighted Average Fair Value (in thousands) Unvested units at December 31, 2021 28,272 $ 1.00 Granted 24,416 $ 1.00 Vested (8,483) $ 1.00 Forfeited (675) $ 1.00 Unvested units at March 31, 2022 43,530 $ 1.00

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2022
Segment Reporting [Abstract]
Summary of Financial Information for Company's Reportable Segments	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 2021 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, gain on early extinguishment of debt and other income (loss). The “Other” column includes items not related to the Company’s reportable segments, including real estate and corporate items. Corporate general and administrative costs, depreciation expense and taxes, other than income taxes, are allocated to the segments. Exploration and Production Marketing Other Total Three months ended March 31, 2022 (in millions) Revenues from external customers $ 2,077 $ 866 $ — $ 2,943 Intersegment revenues (3) 1,889 — 1,886 Depreciation, depletion and amortization expense 274 1 — 275 Impairments — — — — Operating income 1,278 (1) 21 — 1,299 Interest expense (2) 41 — — 41 Loss on derivatives (3,925) — (2) (3,927) Loss on extinguishment of debt — — (2) (2) Other income, net — — — — Provision for income taxes (2) 4 — — 4 Assets 10,766 (3) 969 112 11,847 Capital investments (4) 544 — — 544 Three months ended March 31, 2021 Revenues from external customers $ 719 $ 353 $ — $ 1,072 Intersegment revenues (14) 644 — 630 Depreciation, depletion and amortization expense 94 2 — 96 Operating income 295 (1) 6 — 301 Interest expense (2) 31 — — 31 Loss on derivatives (191) — — (191) Other income, net 1 — — 1 Assets 4,741 (3) 396 110 5,247 Capital investments (4) 266 — — 266 (1) Operating income (loss) for the E&P segment includes $6 million of restructuring charges for the three months ended 2021. The E&P segment operating income (loss) also includes $25 million and $1 million of merger-related expenses for the three months ended March 31, 2022 and 2021, 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. (4) Capital investments include increases of $43 million and $38 million for the three months ended March 31, 2022 and 2021, respectively, relating to the change in accrued expenditures between periods. The following table presents the breakout of other assets, which represent corporate assets not allocated to segments and assets for non-reportable segments at March 31, 2022 and 2021: As of March 31, (in millions) 2022 2021 Cash and cash equivalents $ 21 $ 4 Accounts receivable 1 — Prepayments 6 6 Property, plant and equipment 10 15 Unamortized debt expense 9 11 Right-of-use lease assets 63 70 Non-qualified retirement plan 2 4 $ 112 $ 110

Basis of Presentation (Narrativ

Basis of Presentation (Narrative) (Details)	3 Months Ended
	Mar. 31, 2022segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of segments	2

Acquisitions (Narrative) (Detai

Acquisitions (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2021	Sep. 01, 2021	Sep. 30, 2021	Mar. 31, 2022	Mar. 31, 2021	Nov. 30, 2021
Business Acquisition [Line Items]
Total operating revenues				$ 2,943	$ 1,072
Operating income				1,299	$ 301
Long-term debt	$ 5,407			4,900
Obligation under transportation agreements				$ 10,158
Contractual commitments payments, term (in years)				2 years
Maximum
Business Acquisition [Line Items]
Contractual commitments payments, term (in years)				2 years
5.375% Senior Notes due February 2029 | Senior Notes
Business Acquisition [Line Items]
Stated interest rate		5.375%		5.375%		5.375%
Long-term debt		$ 700				$ 700
Indigo Agreement
Business Acquisition [Line Items]
Obligation under transportation agreements				$ 34
Liability for the estimated future payments				17
Purchase or volume commitments with gathering fresh water and sand
Business Acquisition [Line Items]
Obligation under transportation agreements				35
Haynesville
Business Acquisition [Line Items]
Total operating revenues				753
Operating income				$ 482
GEPH Merger
Business Acquisition [Line Items]
Cash consideration	$ 1,269
Shares of Southwestern common stock issued (in shares)	99,337,748
Value of Southwestern's stock issued as consideration	$ 463
NYSE closing price per share of Southwestern common shares (in dollars per share)	$ 4.66
Revolving credit facility	$ 81
Evaluated oil and gas properties	1,783
Unevaluated oil and gas properties (1)	58
Other property, plant and equipment	$ 2
Indigo Natural Resources, LLC
Business Acquisition [Line Items]
Cash consideration		$ 373
Shares of Southwestern common stock issued (in shares)		337,827,171	337,827,171
Value of Southwestern's stock issued as consideration		$ 1,588
NYSE closing price per share of Southwestern common shares (in dollars per share)		$ 4.70
Revolving credit facility		$ 95
Evaluated oil and gas properties		2,724
Unevaluated oil and gas properties (1)		693
Other property, plant and equipment		4
Senior unsecured notes		726
Indigo Natural Resources, LLC | 5.375% Senior Notes due February 2029 | Senior Notes
Business Acquisition [Line Items]
Senior note assumed in merger agreement		$ 700
Stated interest rate		5.375%

Acquisitions (Schedule of Consi

Acquisitions (Schedule of Consideration Paid to Equity Holders of GEPH) (Details) - GEPH Merger $ / shares in Units, $ in Millions	Dec. 31, 2021USD ($)$ / sharesshares
Business Acquisition, Equity Interests Issued or Issuable [Line Items]
Shares of Southwestern common stock issued (in shares) | shares	99,337,748
NYSE closing price per share of Southwestern common shares (in dollars per share) | $ / shares	$ 4.66
Value of Southwestern's stock issued as consideration	$ 463
Cash consideration	1,269
Total consideration	$ 1,732

Acquisitions (Schedule of the A

Acquisitions (Schedule of the Allocation of Purchase Price of GEPH) (Details) - GEPH Merger - USD ($) $ in Millions	Dec. 31, 2021	Mar. 31, 2022
Consideration:
Total consideration	$ 1,732
Fair Value of Assets Acquired:
Cash and cash equivalents	11
Accounts receivable	171
Other current assets	3
Commodity derivative assets	56
Evaluated oil and gas properties	1,783
Unevaluated oil and gas properties (1)	58
Other property, plant and equipment	2
Other long-term assets	3
Total assets acquired	2,087
Fair Value of Liabilities Assumed:
Accounts payable (1)	164
Other current liabilities	1
Derivative liabilities	75
Revolving credit facility	81
Asset retirement obligations	24
Other noncurrent liabilities	10
Total liabilities assumed	355
Net Assets Acquired and Liabilities Assumed	$ 1,732
Purchase price adjustment		$ 1
Accounts Payable
Fair Value of Liabilities Assumed:
Purchase price adjustment		6
Other Noncurrent Liabilities
Fair Value of Liabilities Assumed:
Purchase price adjustment		$ 5

Acquisitions (Schedule of Con_2

Acquisitions (Schedule of Consideration Paid to Equity Holders of Indigo) (Details) - Indigo Natural Resources, LLC - USD ($) $ / shares in Units, $ in Millions	Sep. 01, 2021	Sep. 30, 2021
Business Acquisition, Equity Interests Issued or Issuable [Line Items]
Shares of Southwestern common stock issued (in shares)	337,827,171	337,827,171
NYSE closing price per share of Southwestern common shares (in dollars per share)	$ 4.70
Value of Southwestern's stock issued as consideration	$ 1,588
Cash consideration	373
Total consideration	$ 1,961

Acquisitions (Schedule of the_2

Acquisitions (Schedule of the Allocation of Purchase Price of Indigo) (Details) - Indigo Natural Resources, LLC - USD ($) $ in Millions	Sep. 01, 2021	Mar. 31, 2022
Consideration:
Total consideration	$ 1,961
Fair Value of Assets Acquired:
Cash and cash equivalents	55
Accounts receivable	192
Other current assets	2
Commodity derivative assets	2
Evaluated oil and gas properties	2,724
Unevaluated oil and gas properties (1)	693
Other property, plant and equipment	4
Other long-term assets	27
Total assets acquired	3,699
Fair Value of Liabilities Assumed:
Accounts payable (1)	283
Other current liabilities	55
Derivative liabilities	501
Revolving credit facility	95
Senior unsecured notes	726
Asset retirement obligations	8
Other noncurrent liabilities	70
Total liabilities assumed	1,738
Net Assets Acquired and Liabilities Assumed	$ 1,961
Purchase price adjustment		$ 9

Acquisitions (Schedule of Merge

Acquisitions (Schedule of Merger Related Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Business Acquisition [Line Items]
Transition services	$ 18
Professional fees (bank, legal, consulting)	1
Contract buyouts, terminations and transfers	2
Due diligence and environmental	1
Employee-related	1
Other	2
Merger-related expenses	25	$ 1
Indigo Natural Resources, LLC
Business Acquisition [Line Items]
Transition services	0
Professional fees (bank, legal, consulting)	0
Contract buyouts, terminations and transfers	0
Due diligence and environmental	1
Employee-related	0
Other	0
Merger-related expenses	1
GEPH Merger
Business Acquisition [Line Items]
Transition services	18
Professional fees (bank, legal, consulting)	1
Contract buyouts, terminations and transfers	2
Due diligence and environmental	0
Employee-related	1
Other	2
Merger-related expenses	$ 24
Montage Resources Corporation
Business Acquisition [Line Items]
Transition services		0
Professional fees (bank, legal, consulting)		0
Contract buyouts, terminations and transfers		0
Due diligence and environmental		0
Employee-related		1
Other		0
Merger-related expenses		$ 1

Acquisitions (Schedule of Pro F

Acquisitions (Schedule of Pro Forma) (Details) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2021USD ($)$ / shares
Business Acquisition [Line Items]
Net income (loss) attributable to common stock per share – basic (in dollars per share) | $ / shares	$ 0.03
Net income (loss) attributable to common stock per share – diluted (in dollars per share) | $ / shares	$ 0.03
Montage Resources Corporation and Indigo Natural Resources, LLC
Business Acquisition [Line Items]
Revenues | $	$ 1,471
Net income attributable to common stock | $	$ 30

Restructuring Charges (Summary

Restructuring Charges (Summary of Restructuring Charges) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Restructuring Cost and Reserve [Line Items]
Severance (including payroll taxes)	$ 1
Workforce Reduction
Restructuring Cost and Reserve [Line Items]
Severance (including payroll taxes)	$ 0	$ 6

Revenue Recognition (Narrative)

Revenue Recognition (Narrative) (Details)	3 Months Ended
	Mar. 31, 2022USD ($)
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
Maximum | NGL sales
Disaggregation of Revenue [Line Items]
Payment terms	60 days
Maximum | Marketing
Disaggregation of Revenue [Line Items]
Payment terms	60 days

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue by Segment) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 2,943	$ 1,072
E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	2,077	719
Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	866	353
Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	2,074	705
Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	2,755	997
Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,886	630
Intersegment Revenues | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	(3)	(14)
Intersegment Revenues | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	1,889	644
Gas sales
Disaggregation of Revenue [Line Items]
Total operating revenues	1,692	464
Gas sales | Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	1,690	451
Gas sales | Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0
Gas sales | Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	2	13
Oil sales
Disaggregation of Revenue [Line Items]
Total operating revenues	111	81
Oil sales | Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	110	80
Oil sales | Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0
Oil sales | Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1	1
NGL sales
Disaggregation of Revenue [Line Items]
Total operating revenues	272	173
NGL sales | Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	272	173
NGL sales | Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0
NGL sales | Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0
Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	866	352
Marketing | Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	0	0
Marketing | Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	2,755	996
Marketing | Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,889	644
Other
Disaggregation of Revenue [Line Items]
Total operating revenues	2	2
Other | Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	2	1
Other | Operating Segments | Marketing
Disaggregation of Revenue [Line Items]
Total operating revenues	0	1
Other | Intersegment Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 0	$ 0

Revenue Recognition (Disaggre_2

Revenue Recognition (Disaggregation of Revenue on Geographic Basis) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 2,943	$ 1,072
E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	2,077	719
Operating Segments | E&P
Disaggregation of Revenue [Line Items]
Total operating revenues	2,074	705
Operating Segments | E&P | Appalachia
Disaggregation of Revenue [Line Items]
Total operating revenues	1,321	704
Operating Segments | E&P | Haynesville
Disaggregation of Revenue [Line Items]
Total operating revenues	753	0
Operating Segments | E&P | Other
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 0	$ 1

Revenue Recognition (Reconcilia

Revenue Recognition (Reconciliation of Accounts Receivable) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Receivables from contracts with customers	$ 972	$ 1,085
Other accounts receivable	99	75
Total accounts receivable	$ 1,071	$ 1,160

Cash and Cash Equivalents (Summ

Cash and Cash Equivalents (Summary of Cash and Cash Equivalents) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Cash and Cash Equivalents [Abstract]
Cash	$ 21	$ 28
Marketable securities	0	0
Total	$ 21	$ 28

Natural Gas and Oil Propertie_2

Natural Gas and Oil Properties (Narrative) (Details)	3 Months Ended
	Mar. 31, 2022derivative_position$ / bbl$ / MMBTU	Mar. 31, 2021$ / bbl$ / 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 | derivative_position	0
Natural Gas
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price per MMBtu (in dollars per MMBtu) | $ / MMBTU	4.09	2.16
Oil
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price per barrel (in dollars per bbl)	75.39	40.01
NGL
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price per barrel (in dollars per bbl)	32.75	13.57

Earnings Per Share (Narrative)

Earnings Per Share (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2021	Sep. 01, 2021	Sep. 30, 2021
GEPH Merger
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares of Southwestern common stock issued (in shares)	99,337,748
Value of Southwestern's stock issued as consideration	$ 463
NYSE closing price per share of Southwestern common shares (in dollars per share)	$ 4.66
Indigo Natural Resources, LLC
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares of Southwestern common stock issued (in shares)		337,827,171	337,827,171
Value of Southwestern's stock issued as consideration			$ 1,588
NYSE closing price per share of Southwestern common shares (in dollars per share)		$ 4.70

Earnings Per Share (Schedule of

Earnings Per Share (Schedule of Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income (loss)	$ (2,675)	$ 80
Number of common shares:
Weighted average outstanding (in shares)	1,114,610,964	675,385,145
Weighted average and potential dilutive outstanding (in shares)	1,114,610,964	679,867,825
Earnings (loss) per common share
Basic (in dollars per share)	$ (2.40)	$ 0.12
Diluted (in dollars per share)	$ (2.40)	$ 0.12
Stock options
Number of common shares:
Issued upon assumed exercise of outstanding stock options (in shares)	0	0
Restricted Common Stock
Number of common shares:
Effect of issuance of non-vested restricted common stock (in shares)	0	870,541
Restricted stock units
Number of common shares:
Effect of issuance of non-vested restricted common stock (in shares)	0	804,944
Performance units
Number of common shares:
Effect of issuance of non-vested performance units (in shares)	0	2,807,195

Earnings Per Share (Schedule _2

Earnings Per Share (Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share) (Details) - shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	8,830,992	7,782,382
Unexercised stock options
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	2,948,488	3,795,091
Stock-based compensation
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	1,436,920	0
Restricted stock units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	2,528,005	3,987,291
Performance units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share (in shares)	1,917,579	0

Derivatives and Risk Manageme_3

Derivatives and Risk Management (Schedule of Derivative Instruments Notional Amount, Weighted Average Contract Prices and Fair Value) (Details) - Not Designated as Hedging Instrument bbl in Thousands, Mcf in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)$ / MMBTU$ / bblMcfbbl
Financial protection on production - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	982
Fair value	$ (2,672)
Financial protection on production - 2022 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	3,413
Fair value	$ (132)
Financial protection on production - 2022 | Propane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	4,873
Fair value	$ (124)
Fixed Price Swaps - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	627
Weighted average price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.04
Fair value	$ (1,672)
Fixed Price Swaps - 2022 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	2,376
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	53.32
Fair value	$ (94)
Fixed Price Swaps - 2022 | Ethane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	4,142
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	11.27
Fair value	$ (26)
Fixed Price Swaps - 2022 | Propane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	4,643
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	31.09
Fair value	$ (118)
Fixed Price Swaps - 2022 | Normal Butane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,388
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	36.22
Fair value	$ (43)
Fixed Price Swaps - 2022 | Natural Gasoline
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,497
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	55.78
Fair value	$ (57)
Two Way Costless Collars - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	78
Fair value	$ (216)
Two Way Costless Collars - 2022 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.92
Three-Way Costless Collars - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	277
Fair value	$ (784)
Three-Way Costless Collars - 2022 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,037
Fair value	$ (38)
Three-Way Costless Collars - 2022 | Propane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	230
Fair value	$ (6)
Three-way Costless Collars - 2022 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.88
Three-way Costless Collars - 2022 Sold Calls | Oil
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / bbl	57.01
Three-way Costless Collars - 2022 Sold Calls | Propane
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / bbl	31.92
Financial protection on production- 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	938
Fair value	$ (1,247)
Financial protection on production- 2023 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	2,114
Fair value	$ (59)
Fixed Price Swaps - 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	504
Weighted average price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.08
Fair value	$ (675)
Fixed Price Swaps - 2023 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	846
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	55.98
Fair value	$ (23)
Fixed Price Swaps - 2023 | Ethane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,308
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	11.91
Fair value	$ (3)
Fixed Price Swaps - 2023 | Propane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,066
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	37.15
Fair value	$ (8)
Fixed Price Swaps - 2023 | Normal Butane
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	329
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	40.64
Fair value	$ (3)
Fixed Price Swaps - 2023 | Natural Gasoline
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	359
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	66
Fair value	$ (5)
Two Way Costless Collars - 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	219
Fair value	$ (217)
Two Way Costless Collars - 2023 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.55
Three Way Costless Collars - 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	215
Fair value	$ (355)
Three Way Costless Collars - 2023 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	1,268
Fair value	$ (36)
Three Way Costless Collars - 2023 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3
Three Way Costless Collars - 2023 Sold Calls | Oil
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / bbl	56.12
Financial protection on production - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	279
Fair value	$ (205)
Fixed Price Swaps - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	224
Weighted average price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.96
Fair value	$ (174)
Fixed Price Swaps - 2024 | Oil
Derivative [Line Items]
Volume (Bcf, MBbls) | bbl	603
Weighted average price (in dollars per MMBtu, Bbl) | $ / bbl	68.68
Fair value	$ (5)
Two Way Costless Collars - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	44
Fair value	$ (19)
Two Way Costless Collars - 2024 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.53
Three Way Costless Collars - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	11
Fair value	$ (12)
Three Way Costless Collars - 2024 Sold Calls | Natural Gas
Derivative [Line Items]
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.54
Basis Swaps | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	582
Fair value	$ 104
Basis Swaps - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	277
Basis differential per MMBtu | $ / MMBTU	(0.53)
Fair value	$ 72
Basis Swap - 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	250
Basis differential per MMBtu | $ / MMBTU	(0.47)
Fair value	$ 20
Basis Swap - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	46
Basis differential per MMBtu | $ / MMBTU	(0.71)
Fair value	$ 9
Basis Swap - 2025 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	9
Basis differential per MMBtu | $ / MMBTU	(0.64)
Fair value	$ 3
Call options | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	118
Fair value	$ (258)
Call Options - 2022 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	63
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.01
Fair value	$ (171)
Call Options - 2023 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	46
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.94
Fair value	$ (74)
Call Options - 2024 | Natural Gas
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	9
Cap price (in dollars per MMBtu, Bbl) | $ / MMBTU	3
Fair value	$ (13)
Purchased Fixed Price Swaps, Storage - 2022
Derivative [Line Items]
Volume (Bcf, MBbls) | Mcf	0
Weighted average price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.14
Basis differential per MMBtu | $ / MMBTU	0
Fair value	$ 1
Sold Puts | Three-Way Costless Collars - 2022 Sold Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.03
Sold Puts | Three-Way Costless Collars - 2022 Sold Puts | Oil
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	39.83
Sold Puts | Three-Way Costless Collars - 2022 Sold Puts | Propane
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	16.80
Sold Puts | Three Way Costless Collars - 2023 Sold Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.09
Sold Puts | Three Way Costless Collars - 2023 Sold Puts | Oil
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	33.97
Sold Puts | Three Way Costless Collars - 2024 Sold Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.25
Purchased Puts | Two Way Costless Collars - 2022 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.53
Purchased Puts | Three Way Costless Collars - 2022 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.48
Purchased Puts | Three Way Costless Collars - 2022 Purchased Puts | Oil
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	50.17
Purchased Puts | Three Way Costless Collars - 2022 Purchased Puts | Propane
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	21
Purchased Puts | Two Way Costless Collars - 2023 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.03
Purchased Puts | Three Way Costless Collars - 2023 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.54
Purchased Puts | Three Way Costless Collars - 2023 Purchased Puts | Oil
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / bbl	45.51
Purchased Puts | Two Way Costless Collars - 2024 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	3.07
Purchased Puts | Three Way Costless Collars - 2024 Purchased Puts | Natural Gas
Derivative [Line Items]
Floor price (in dollars per MMBtu, Bbl) | $ / MMBTU	2.80

Derivatives and Risk Manageme_4

Derivatives and Risk Management (Narrative) (Details) - Not Designated as Hedging Instrument - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Fair value of net derivative liability position decrease	$ 8	$ 3
Commodities
Derivative [Line Items]
Derivative liability	$ 4,734

Derivatives and Risk Manageme_5

Derivatives and Risk Management (Balance Sheet Classification of Derivative Financial Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Net current derivative liabilities	$ (3,842)	$ (1,098)
Net long-term derivative liabilities	(900)	(407)
Non-performance risk adjustment	8	3
Derivative instruments, net	(4,734)	(1,502)
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative assets	230	411
Derivative liabilities	4,972	1,916
Not Designated as Hedging Instrument | Interest rate swaps | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	2
Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	79
Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	64
Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	1,999	565
Natural Gas | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	522	246
Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	10	9
Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	44	100
Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	316	104
Natural Gas | Not Designated as Hedging Instrument | Two-way costless collars | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	190	115
Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	9	12
Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	12	37
Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	977	298
Natural Gas | Not Designated as Hedging Instrument | Three-way costless collars | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	195	178
Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	82	77
Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	70	22
Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	43	9
Natural Gas | Not Designated as Hedging Instrument | Basis swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	5	22
Natural Gas | Not Designated as Hedging Instrument | Call options | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	201	67
Natural Gas | Not Designated as Hedging Instrument | Call options | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	57	42
Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	2
Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	28	10
Ethane | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	1	0
Ethane | Not Designated as Hedging Instrument | Two-way costless collars | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	0	1
Propane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	2
Propane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	122	78
Propane | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	4	1
Propane | Not Designated as Hedging Instrument | Three-way costless collars | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	6	4
Normal Butane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	1
Normal Butane | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	44	27
Normal Butane | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	2	0
Oil | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	101	60
Oil | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	21	9
Oil | Not Designated as Hedging Instrument | Three-way costless collars | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	1	1
Oil | Not Designated as Hedging Instrument | Three-way costless collars | Other long-term assets
Derivatives, Fair Value [Line Items]
Derivative assets	1	3
Oil | Not Designated as Hedging Instrument | Three-way costless collars | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	49	24
Oil | Not Designated as Hedging Instrument | Three-way costless collars | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	27	21
Natural Gas Storage | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	0	1
Natural Gas Storage | Not Designated as Hedging Instrument | Purchased fixed price swaps | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	1	0
Natural Gasoline | Not Designated as Hedging Instrument | Fixed price swaps | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	59	33
Natural Gasoline | Not Designated as Hedging Instrument | Fixed price swaps | Long-term derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ 3	$ 1

Derivatives and Risk Manageme_6

Derivatives and Risk Management (Summary of Before Tax Effect of Fair Value Hedges not Designated for Hedge Accounting) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	$ (3,237)	$ (169)
Total loss on settled derivatives	(695)	(22)
Non-performance risk adjustment	5	0
Total loss on derivatives	(3,927)	(191)
Fixed price swaps | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(1,853)	(22)
Total loss on settled derivatives	(297)	5
Fixed price swaps | Oil
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(53)	(40)
Total loss on settled derivatives	(33)	(17)
Fixed price swaps | Ethane
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(21)	(2)
Total loss on settled derivatives	(8)	(4)
Fixed price swaps | Propane
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(49)	(45)
Total loss on settled derivatives	(41)	(30)
Fixed price swaps | Normal Butane
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(20)	(15)
Total loss on settled derivatives	(14)	(7)
Fixed price swaps | Natural Gasoline
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(28)	(20)
Total loss on settled derivatives	(19)	(9)
Two-way costless collars | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(342)	(12)
Total loss on settled derivatives	(104)	2
Two-way costless collars | Oil
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	0	(1)
Total loss on settled derivatives	0	(1)
Two-way costless collars | Ethane
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	1	0
Total loss on settled derivatives	(1)	0
Three-way costless collars | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(724)	0
Total loss on settled derivatives	(121)	1
Three-way costless collars | Oil
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(33)	(18)
Total loss on settled derivatives	(13)	(1)
Three-way costless collars | Propane
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(2)	(1)
Total loss on settled derivatives	(2)	0
Basis swaps | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	36	3
Total loss on settled derivatives	1	41
Call options | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(149)	3
Total loss on settled derivatives	(39)	0
Call options | Oil
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	0	(1)
Put options | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on settled derivatives	0	(2)
Amortization of premium paid		2
Swaptions | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	0	1
Purchased fixed price swaps | Natural Gas Storage
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	1	0
Fixed price swaps – storage | Natural Gas Storage
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	1	0
Total loss on settled derivatives	(3)	0
Interest rate swaps
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on unsettled derivatives	(2)	1
Index swap | Natural Gas
Derivative Instruments, Gain (Loss) [Line Items]
Total loss on settled derivatives	$ (1)	$ 0

Reclassifications from Accumu_3

Reclassifications from Accumulated Other Comprehensive Income (Loss) (Components of Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance beginning		$ 2,547	$ 497
Other comprehensive income	[1]	0	0
Balance ending		(119)	586
Accumulated other comprehensive income		(2,675)	80
Total
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance beginning		(25)	(38)
Other comprehensive income before reclassifications		0
Amounts reclassified from other comprehensive income		0
Other comprehensive income		0
Balance ending		(25)	$ (38)
Pension and Other Postretirement
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance beginning		(11)
Other comprehensive income before reclassifications		0
Amounts reclassified from other comprehensive income		0
Other comprehensive income		0
Balance ending		(11)
Pension and Other Postretirement | Reclassification out of Accumulated Other Comprehensive Income
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated other comprehensive income		1
Foreign Currency
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balance beginning		(14)
Other comprehensive income before reclassifications		0
Amounts reclassified from other comprehensive income		0
Other comprehensive income		0
Balance ending		$ (14)
[1]	Settlement adjustment was less than $1 million for the three months ended March 31, 2022.

Fair Value Measurements (Carryi

Fair Value Measurements (Carrying Amount and Estimated Fair Values of Financial Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, net	$ (4,734)	$ (1,502)
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	21	28
Derivative instruments, net	(4,734)	(1,502)
Carrying Amount | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior notes	4,209	4,430
Carrying Amount | Term Loan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Term Loan B due 2027	549	550
Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	21	28
Derivative instruments, net	(4,734)	(1,502)
Fair Value | Senior Notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior notes	4,318	4,745
Fair Value | Term Loan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Term Loan B due 2027	549	550
2018 revolving credit facility due April 2024 | Carrying Amount | Long-term debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
2018 revolving credit facility due April 2024	174	460
2018 revolving credit facility due April 2024 | Fair Value | Long-term debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
2018 revolving credit facility due April 2024	$ 174	$ 460

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Not Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of net derivative liability position decrease	$ 8	$ 3

Fair Value Measurements (Summar

Fair Value Measurements (Summary of Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total (1)	$ (4,742)	$ (1,505)
Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total (1)	0	0
Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total (1)	(4,742)	(1,505)
Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total (1)	0	0
Fixed price swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		148
Derivative liabilities	(2,906)	(1,031)
Fixed price swaps | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		0
Derivative liabilities	0	0
Fixed price swaps | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		148
Derivative liabilities	(2,906)	(1,031)
Fixed price swaps | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		0
Derivative liabilities	0	0
Two-way costless collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	54	109
Derivative liabilities	(506)	(220)
Two-way costless collars | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Two-way costless collars | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	54	109
Derivative liabilities	(506)	(220)
Two-way costless collars | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Three-way costless collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	23	53
Derivative liabilities	(1,254)	(525)
Three-way costless collars | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Three-way costless collars | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	23	53
Derivative liabilities	(1,254)	(525)
Three-way costless collars | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Basis swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	152	99
Derivative liabilities	(48)	(31)
Basis swaps | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Basis swaps | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	152	99
Derivative liabilities	(48)	(31)
Basis swaps | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0
Derivative liabilities	0	0
Purchased fixed price swaps – storage
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	1
Purchased fixed price swaps – storage | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0
Purchased fixed price swaps – storage | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	1
Purchased fixed price swaps – storage | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0
Interest rate swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		2
Interest rate swaps | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		0
Interest rate swaps | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		2
Interest rate swaps | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset		0
Call options
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	(258)	(109)
Call options | Quoted Prices in Active Markets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Call options | Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	(258)	(109)
Call options | Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	$ 0	$ 0

Debt (Components of Debt) (Deta

Debt (Components of Debt) (Details) - USD ($) $ in Thousands	1 Months Ended
	Mar. 31, 2022	Jan. 06, 2022	Dec. 31, 2021	Dec. 22, 2021	Nov. 30, 2021	Sep. 01, 2021	Aug. 30, 2021	Aug. 31, 2020	Apr. 07, 2020	Jul. 31, 2018	Jan. 31, 2015
Debt Instrument [Line Items]
Current portion of long-term debt	$ 5,000		$ 206,000
Debt instrument, excluding current maturities, gross			5,234,000
Total debt	4,932,000		5,440,000
Unamortized Issuance Expense	(55,000)		(57,000)
Unamortized Debt Premium/Discount	23,000		24,000
Total long-term debt	4,895,000		5,201,000
Total debt	4,900,000		5,407,000
Long-term debt
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	4,927,000
Unamortized Issuance Expense	(55,000)
Unamortized Debt Premium/Discount	23,000
Total long-term debt	4,895,000
Senior Notes
Debt Instrument [Line Items]
Current portion of long-term debt	5,000
Unamortized Issuance Expense	0
Unamortized Debt Premium/Discount	$ 0
Senior Notes | 4.10% Senior Notes due March 2022
Debt Instrument [Line Items]
Current portion of long-term debt			$ 201,000
Stated interest rate	4.10%		4.10%				4.10%
Senior Notes | Term Loan Due June 2027
Debt Instrument [Line Items]
Credit facility, variable interest rate			3.00%
Stated interest rate	3.30%		3.00%
Senior Notes | 4.95% Senior Notes due January 2025 (3)
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 389,000		$ 389,000
Unamortized Issuance Expense	(1,000)		(1,000)
Unamortized Debt Premium/Discount	0		0
Total long-term debt	$ 388,000		$ 388,000
Stated interest rate	4.95%	5.95%	4.95%				4.95%		6.45%	6.20%	4.95%
Senior Notes | 7.75% Senior Notes due October 2027
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 425,000		$ 440,000
Unamortized Issuance Expense	(4,000)		(4,000)
Unamortized Debt Premium/Discount	0		0
Total long-term debt	$ 421,000		$ 436,000
Stated interest rate	7.75%		7.75%
Senior Notes | 8.375% Senior Notes due September 2028
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 345,000		$ 350,000
Unamortized Issuance Expense	(5,000)		(5,000)
Unamortized Debt Premium/Discount	0		0
Total long-term debt	$ 340,000		$ 345,000
Stated interest rate	8.375%		8.375%					8.375%
Senior Notes | 5.375% Senior Notes due February 2029
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 700,000
Unamortized Issuance Expense	(6,000)
Unamortized Debt Premium/Discount	24,000
Total long-term debt	$ 718,000
Total debt					$ 700,000	$ 700,000
Stated interest rate	5.375%				5.375%	5.375%
Senior Notes | 5.375% Senior Notes due September 2029
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross			$ 700,000
Unamortized Issuance Expense			(6,000)
Unamortized Debt Premium/Discount			25,000
Total long-term debt			$ 719,000
Stated interest rate			5.375%
Senior Notes | 5.375% Senior Notes due September 2030
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 1,200,000
Unamortized Issuance Expense	(16,000)
Unamortized Debt Premium/Discount	0
Total long-term debt	$ 1,184,000
Stated interest rate	5.375%						5.375%
Senior Notes | 5.375% Senior Notes due March 2030
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross			$ 1,200,000
Unamortized Issuance Expense			(17,000)
Unamortized Debt Premium/Discount			0
Total long-term debt			$ 1,183,000
Stated interest rate			5.375%
Senior Notes | 4.75% Senior Notes due February 2032
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 1,150,000		$ 1,150,000
Unamortized Issuance Expense	(16,000)		(17,000)
Unamortized Debt Premium/Discount	0		0
Total long-term debt	$ 1,134,000		$ 1,133,000
Stated interest rate	4.75%		4.75%	4.75%
Line of Credit | 2018 Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility, variable interest rate	2.10%		2.08%
Line of Credit | 2018 Revolving Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross	$ 174,000		$ 460,000
Unamortized Issuance Expense	0		0
Unamortized Debt Premium/Discount	0		0
Total long-term debt	174,000		460,000
Term Loan | Term Loan Due June 2027
Debt Instrument [Line Items]
Current portion of long-term debt	5,000		5,000
Debt instrument, excluding current maturities, gross	544,000		545,000
Unamortized Issuance Expense	(7,000)		(7,000)
Unamortized Debt Premium/Discount	(1,000)		(1,000)
Total long-term debt	$ 536,000		537,000
Credit facility, variable interest rate	3.30%
Repayments of secured debt	$ 1,375
Other long-term assets | Line of Credit | 2018 Revolving Credit Facility
Debt Instrument [Line Items]
Unamortized Issuance Expense	$ (9,000)		$ (10,000)

Debt (Schedule of Debt Maturiti

Debt (Schedule of Debt Maturities) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	$ 4
2023	6
2024 (1)	179
2025	395
2026	5
Thereafter	4,343
Total debt	$ 4,932	$ 5,440

Debt (2018 Revolving Credit Fac

Debt (2018 Revolving Credit Facility - Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended
	Apr. 30, 2018	Mar. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Subsidiary ownership		100.00%
Letters of credit		$ 147,000,000
Debt instrument, excluding current maturities, gross			$ 5,234,000,000
Long-term debt
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross		4,927,000,000
Long-term debt | 2018 revolving credit facility due April 2024
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 3,500,000,000
Current borrowing base		2,000,000,000
Aggregate commitment		2,000,000,000
Limit on securing indebtedness	$ 2,000,000,000
Percentage of consolidated net tangible assets	25.00%
Minimum interest coverage ratio	1
Long-term debt | 2018 revolving credit facility due April 2024 | Eurodollar | Minimum
Debt Instrument [Line Items]
Basis points	1.75%
Long-term debt | 2018 revolving credit facility due April 2024 | Eurodollar | Maximum
Debt Instrument [Line Items]
Basis points	2.75%
Long-term debt | 2018 revolving credit facility due April 2024 | Base Rate | Minimum
Debt Instrument [Line Items]
Basis points	0.75%
Long-term debt | 2018 revolving credit facility due April 2024 | Base Rate | Maximum
Debt Instrument [Line Items]
Basis points	1.75%
Line of Credit | Revolving Credit Facility | 2018 Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument, excluding current maturities, gross		$ 174,000,000	$ 460,000,000
After June 30, 2020 | Long-term debt | 2018 revolving credit facility due April 2024 | Maximum
Debt Instrument [Line Items]
Leverage ratio	4

Debt (2022 Revolving Credit Fac

Debt (2022 Revolving Credit Facility - Narrative) (Details)	Apr. 08, 2022USD ($)	Dec. 22, 2021
Subsequent Event
Debt Instrument [Line Items]
Line of credit facility, expiration period	5 years
2022 Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage		0.15%
2022 Revolving Credit Facility | Minimum | Subsequent Event
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage	0.375%
2022 Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage		0.275%
Ratio of indebtedness to net capital		0.65
2022 Revolving Credit Facility | Maximum | Subsequent Event
Debt Instrument [Line Items]
Line of credit facility, unused capacity, commitment fee percentage	0.50%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Subsequent Event
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 3,500,000,000
Current borrowing base	$ 2,000,000,000
Minimum current ratio	1
Leverage ratio, percentage of credit limit	10.00%
Leverage ratio, amount of credit limit	$ 150,000,000
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | On Or After June 30, 2020 | Subsequent Event
Debt Instrument [Line Items]
Leverage ratio	4
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Eurodollar
Debt Instrument [Line Items]
Basis points		0.10%
Debt instrument, discount coverage ratio		9.00%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Eurodollar | Subsequent Event
Debt Instrument [Line Items]
Basis points	0.10%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Fed Funds Effective Rate Overnight Index Swap Rate | Subsequent Event
Debt Instrument [Line Items]
Basis points	0.50%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Base Rate | Subsequent Event
Debt Instrument [Line Items]
Basis points	1.00%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Minimum | Eurodollar
Debt Instrument [Line Items]
Basis points		1.25%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Minimum | Eurodollar | Subsequent Event
Debt Instrument [Line Items]
Basis points	1.75%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Minimum | Base Rate
Debt Instrument [Line Items]
Basis points		0.25%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Minimum | Base Rate | Subsequent Event
Debt Instrument [Line Items]
Basis points	0.75%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Maximum | Eurodollar
Debt Instrument [Line Items]
Basis points		1.875%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Maximum | Eurodollar | Subsequent Event
Debt Instrument [Line Items]
Basis points	2.75%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Maximum | Base Rate
Debt Instrument [Line Items]
Basis points		0.875%
Revolving Credit Facility | 2022 Revolving Credit Facility | Line of Credit | Maximum | Base Rate | Subsequent Event
Debt Instrument [Line Items]
Basis points	1.75%
Revolving Credit Facility | 2022 Revolving Credit Facility | Long-term debt
Debt Instrument [Line Items]
Minimum interest coverage ratio		1.50

Debt (Term Loan Credit Agreemen

Debt (Term Loan Credit Agreement - Narrative) (Details) - Term Loan Due June 2027 - Term Loan - USD ($) $ in Thousands	Mar. 31, 2022	Mar. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Secured term loan facility, amount	$ 549,000	$ 549,000	$ 549,000	$ 550,000
Proceeds from loans			$ 542,000
Repayments of secured debt		$ 1,375
Basis points	1.50%
Credit facility, variable interest rate	3.30%	3.30%	3.30%
Minimum
Debt Instrument [Line Items]
Basis points	0.80%
Minimum | SOFR
Debt Instrument [Line Items]
Basis points	0.50%
Maximum
Debt Instrument [Line Items]
Basis points	2.50%

Debt (Senior Notes - Narrative)

Debt (Senior Notes - Narrative) (Details) - USD ($)	Dec. 22, 2021	Sep. 01, 2021	Aug. 30, 2021	Aug. 31, 2020	Jan. 31, 2015	Mar. 31, 2022	Mar. 31, 2021	Jan. 06, 2022	Dec. 31, 2021	Nov. 30, 2021	Apr. 07, 2020	Jul. 31, 2018
Debt Instrument [Line Items]
Loss on extinguishment of debt						$ (2,000,000)	$ 0
Debt instrument, unamortized discount and debt Issuance costs, net			$ 6,000,000
Long-term debt						4,900,000,000			$ 5,407,000,000
Senior Notes
Debt Instrument [Line Items]
Repurchased amount						223,000,000
Repayments of long-term debt			845,000,000
Loss on extinguishment of debt	$ (33,000,000)		$ (60,000,000)			$ (2,000,000)
Debt instrument, purchase accounting, non-cash fair value adjustment		$ 26,000,000
Senior Notes | LIBOR
Debt Instrument [Line Items]
Incremental increase in basis points resulting from downgrades					0.25%
Incremental decrease in basis points resulting from upgrades					0.25%
4.95% Senior Notes due January 2025 (3) | Senior Notes
Debt Instrument [Line Items]
Senior notes					$ 1,000,000,000
Stated interest rate			4.95%		4.95%	4.95%		5.95%	4.95%		6.45%	6.20%
Repurchased amount			$ 167,000,000
8.375% Senior Notes due September 2028 | Senior Notes
Debt Instrument [Line Items]
Senior notes				$ 350,000,000
Stated interest rate				8.375%		8.375%			8.375%
Proceeds from issuance of long-term debt				$ 345,000,000
Percentage price of face value of the notes sold to the public				100.00%
Repurchased amount						$ 5,000,000
8.375% Senior Notes due September 2028 | Senior Notes | Montage Resources Corporation
Debt Instrument [Line Items]
Senior notes				$ 510,000,000
5.375% Senior Notes due September 2030 | Senior Notes
Debt Instrument [Line Items]
Senior notes			$ 1,200,000,000
Stated interest rate			5.375%			5.375%
Proceeds from issuance of long-term debt			$ 1,183,000,000
7.50% Senior Notes Due April 2026 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate			7.50%
Repurchased amount			$ 618,000,000
4.10% Senior Notes due March 2022 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate			4.10%			4.10%			4.10%
Repurchased amount			$ 6,000,000			$ 201,000,000
5.375% Senior Notes due February 2029 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate		5.375%				5.375%				5.375%
Debt instrument, purchase accounting, non-cash fair value adjustment, percentage		103.766%
Long-term debt		$ 700,000,000								$ 700,000,000
5.375% Senior Notes due February 2029 | Senior Notes | Indigo Natural Resources, LLC
Debt Instrument [Line Items]
Stated interest rate		5.375%
Senior note assumed in merger agreement		$ 700,000,000
4.75% Senior Notes due February 2032 | Senior Notes
Debt Instrument [Line Items]
Senior notes	$ 1,150,000,000
Stated interest rate	4.75%					4.75%			4.75%
Proceeds from issuance of long-term debt	$ 1,133,000,000
Debt instrument, unamortized discount and debt Issuance costs, net	1,000,000
Payment to fund tender offers, amount	332,000,000
Tender offer fund, amount	$ 300,000,000
7.75% Senior Notes due October 2027 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate						7.75%			7.75%
Repurchased amount						$ 15,000,000

Commitments and Contingencies_2

Commitments and Contingencies (Narrative) (Details)	Jun. 12, 2018individualcompany	Mar. 31, 2022USD ($)
Commitments And Contingencies [Line Items]
Obligation under transportation agreements		$ 10,158,000,000
Guarantee obligations relative to the firms transportation agreements and gathering project and services		$ 877,000,000
Contractual commitments payments, term (in years)		2 years
Loss contingency, number of individuals and entities | individual	51
Loss contingency, number of defendants | company	15
Material liabilities recognized		$ 0
Pending regulatory approval and/or construction
Commitments And Contingencies [Line Items]
Obligation under transportation agreements		857,000,000
Indigo Agreement
Commitments And Contingencies [Line Items]
Obligation under transportation agreements		34,000,000
Liability for the estimated future payments		17,000,000
Purchase or volume commitments with gathering fresh water and sand
Commitments And Contingencies [Line Items]
Obligation under transportation agreements		$ 35,000,000

Commitments and Contingencies_3

Commitments and Contingencies (Schedule of Future Obligation under Transportation Agreements) (Details) $ in Millions	Mar. 31, 2022USD ($)
Other Commitments [Line Items]
Total	$ 10,158
Less than 1 Year	1,069
1 to 3 Years	2,067
3 to 5 Years	1,890
5 to 8 Years	2,332
More than 8 Years	2,800
Infrastructure currently in service
Other Commitments [Line Items]
Total	9,301
Less than 1 Year	1,066
1 to 3 Years	1,943
3 to 5 Years	1,729
5 to 8 Years	2,085
More than 8 Years	2,478
Pending regulatory approval and/or construction
Other Commitments [Line Items]
Total	857
Less than 1 Year	3
1 to 3 Years	124
3 to 5 Years	161
5 to 8 Years	247
More than 8 Years	$ 322

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Income Taxes [Line Items]
Effective tax rate	0.00%	0.00%
Valuation allowance related to operating loss	$ 59
Current income tax expense	4	$ 0
Federal
Income Taxes [Line Items]
Operating loss carryforwards subject to a section 382 limitation	2,000
Operating loss carryforwards	4,000
Deferred tax assets, operating loss carryforwards, subject to expiration	3,000
Deferred tax assets, operating loss carryforwards, not subject to expiration	1,000
Indigo Natural Resources, LLC
Income Taxes [Line Items]
Operating loss carryforwards subject to a section 382 limitation	$ 48

Pension Plan and Other Postre_3

Pension Plan and Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$ 1	$ 1
Benefit obligation	13		$ 13
Pension
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	1	$ 0
Benefit obligation	$ 12		$ 12
Non-Qualified Supplemental Employee Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Treasury stock acquired (in shares)	1,745		2,035

Pension Plan and Other Postre_4

Pension Plan and Other Postretirement Benefits (Pension and Other Postretirement Benefit Costs) (Details) - Pension - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 0	$ 0
Interest cost	1	1
Expected return on plan assets	0	(1)
Amortization of net loss	0	0
Settlement loss	0	0
Net periodic benefit cost	$ 1	$ 0

Long-term Incentive Compensat_3

Long-term Incentive Compensation (Narrative) (Details) $ in Millions	3 Months Ended					12 Months Ended		51 Months Ended
	Mar. 31, 2022USD ($)	Mar. 31, 2021	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2021awardType	Dec. 31, 2020	Mar. 31, 2022USD ($)
Stock Based Compensation 2013 Plan
Long-term Incentive Compensation [Line Items]
Service period	3 years
Stock options
Long-term Incentive Compensation [Line Items]
Vesting period	3 years
Expiration period	7 years
Restricted stock
Long-term Incentive Compensation [Line Items]
Vesting period	3 years
Equity-classified awards, unrecognized compensation cost	$ 1							$ 1
Weighted average period over which unrecognized cost is recognized, years	1 year 7 months 6 days
Performance units
Long-term Incentive Compensation [Line Items]
Vesting period	3 years							3 years
Equity-classified awards, unrecognized compensation cost	$ 5							$ 5
Weighted average period over which unrecognized cost is recognized, years	2 years 10 months 24 days
Equity-Classified Restricted Stock Units
Long-term Incentive Compensation [Line Items]
Equity-classified awards, unrecognized compensation cost	$ 7							7
Weighted average period over which unrecognized cost is recognized, years	2 years 7 months 6 days
Liability-Classified Restricted Stock Units
Long-term Incentive Compensation [Line Items]
Vesting period		4 years	4 years	4 years	4 years	3 years
Weighted average period over which unrecognized cost is recognized, years	1 year 7 months 6 days
Liability classified awards, unrecognized compensation costs	$ 23							$ 23
Liability-Classified Performance Units
Long-term Incentive Compensation [Line Items]
Vesting period								3 years
Weighted average period over which unrecognized cost is recognized, years	1 year 9 months 18 days
Liability classified awards, unrecognized compensation costs	$ 18							$ 18
Number of award plans granted | awardType						2
Performance cash awards
Long-term Incentive Compensation [Line Items]
Vesting period						4 years	4 years
Weighted average period over which unrecognized cost is recognized, years	3 years 2 months 12 days
Liability classified awards, unrecognized compensation costs	$ 42							$ 42

Long-term Incentive Compensat_4

Long-term Incentive Compensation (Schedule of Stock-Based Compensation Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Long-term incentive compensation – expensed	$ 11	$ 13
Long-term incentive compensation – capitalized	$ 7	$ 5

Long-term Incentive Compensat_5

Long-term Incentive Compensation (Schedule of Equity-Classified Stock-Based Compensation Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Equity-classified awards – expensed	$ 1	$ 0
Equity-classified awards – capitalized	$ 0	$ 0

Long-term Incentive Compensat_6

Long-term Incentive Compensation (Summary of Equity-Classified Stock Option Activity) (Details) - Stock options shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Number of Options
Beginning balance (in shares) | shares	3,006
Granted (in shares) | shares	0
Exercised (in shares) | shares	0
Forfeited or expired (in shares) | shares	(152)
Ending balance (in shares) | shares	2,854
Exercisable (in shares) | shares	2,854
Weighted Average Exercise Price
Beginning balance (in dollars per share) | $ / shares	$ 8.98
Granted (in dollars per share) | $ / shares	0
Exercised (in dollars per share) | $ / shares	0
Forfeited or expired (in dollars per share) | $ / shares	26.35
Ending balance (in dollars per share) | $ / shares	8.06
Exercisable (in dollars per share) | $ / shares	$ 8.06

Long-term Incentive Compensat_7

Long-term Incentive Compensation (Summary of Equity-Classified Restricted and Performance Stock Units Activity) (Details) shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Equity-Classified Restricted Stock Units
Number of Units
Beginning balance (in shares) | shares	37
Granted (in shares) | shares	1,699
Vested (in shares) | shares	0
Forfeited (in shares) | shares	(2)
Ending balance (in shares) | shares	1,734
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 3.05
Granted (in dollars per share) | $ / shares	4.45
Vested (in dollars per share) | $ / shares	0
Forfeited (in dollars per share) | $ / shares	3.05
Ending balance (in dollars per share) | $ / shares	$ 4.42
Performance units
Number of Units
Beginning balance (in shares) | shares	0
Granted (in shares) | shares	850
Vested (in shares) | shares	0
Forfeited (in shares) | shares	0
Ending balance (in shares) | shares	850
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 0
Granted (in dollars per share) | $ / shares	6.04
Vested (in dollars per share) | $ / shares	0
Forfeited (in dollars per share) | $ / shares	0
Ending balance (in dollars per share) | $ / shares	$ 6.04

Long-term Incentive Compensat_8

Long-term Incentive Compensation (Summary of Equity-Classified Restricted Stock Activity) (Details) - Restricted stock shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Number of Units
Beginning balance (in shares) | shares	242
Granted (in shares) | shares	0
Vested (in shares) | shares	(43)
Forfeited (in shares) | shares	0
Ending balance (in shares) | shares	199
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 5.12
Granted (in dollars per share) | $ / shares	0
Vested (in dollars per share) | $ / shares	4.90
Forfeited (in dollars per share) | $ / shares	0
Ending balance (in dollars per share) | $ / shares	$ 5.17

Long-term Incentive Compensat_9

Long-term Incentive Compensation (Schedule of Liability-Classified Stock-Based Compensation Costs) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Liability-classified stock-based compensation cost – expensed	$ 8	$ 13
Liability-classified stock-based compensation cost – capitalized	$ 6	$ 5

Long-term Incentive Compensa_10

Long-term Incentive Compensation (Summary of Liability-Classified Restricted Stock Unit Activity) (Details) - Liability-Classified Restricted Stock Units shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Number of Units
Beginning balance (in shares) | shares	7,937
Granted (in shares) | shares	0
Vested (in shares) | shares	(3,806)
Forfeited (in shares) | shares	(12)
Ending balance (in shares) | shares	4,119
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 4.08
Granted (in dollars per share) | $ / shares	0
Vested (in dollars per share) | $ / shares	4.47
Forfeited (in dollars per share) | $ / shares	7.01
Ending balance (in dollars per share) | $ / shares	$ 5.83

Long-term Incentive Compensa_11

Long-term Incentive Compensation (Summary of Liability-Classified Performance Units ) (Details) - Liability-Classified Performance Units shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Number of Units
Beginning balance (in shares) | shares	9,515
Granted (in shares) | shares	3,798
Vested (in shares) | shares	(1,910)
Forfeited (in shares) | shares	0
Ending balance (in shares) | shares	11,403
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 2.88
Granted (in dollars per share) | $ / shares	1
Vested (in dollars per share) | $ / shares	6.45
Forfeited (in dollars per share) | $ / shares	0
Ending balance (in dollars per share) | $ / shares	$ 3.51

Long-term Incentive Compensa_12

Long-term Incentive Compensation - Schedule of Performance Cash Award Compensation Costs (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance cash awards – expensed	$ 11	$ 13
Performance cash awards – capitalized	7	5
Performance cash awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance cash awards – expensed	2	0
Performance cash awards – capitalized	$ 1	$ 0

Long-term Incentive Compensa_13

Long-term Incentive Compensation (Summary of Performance Cash Awards) (Details) - Performance cash awards shares in Thousands	3 Months Ended
	Mar. 31, 2022$ / sharesshares
Number of Units
Beginning balance (in shares) | shares	28,272
Granted (in shares) | shares	24,416
Vested (in shares) | shares	(8,483)
Forfeited (in shares) | shares	(675)
Ending balance (in shares) | shares	43,530
Weighted Average Fair Value
Beginning balance (in dollars per share) | $ / shares	$ 1
Granted (in dollars per share) | $ / shares	1
Vested (in dollars per share) | $ / shares	1
Forfeited (in dollars per share) | $ / shares	1
Ending balance (in dollars per share) | $ / shares	$ 1

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Total operating revenues	$ 2,943	$ 1,072
Depreciation, depletion and amortization expense	275	96
Impairments	0
Operating income	1,299	301
Interest expense	41	31
Loss on derivatives	(3,927)	(191)
Loss on extinguishment of debt	(2)	0
Other Income, Net	0	1
Assets	11,847	5,247	$ 11,848
Capital investments	544	266
Restructuring charges	0	6
Merger-related expenses	25	1
Increase (decrease) in accrued expenditures	43	38
Benefit from income taxes	4	0
Intersegment Revenues
Segment Reporting Information [Line Items]
Total operating revenues	1,886	630
E&P
Segment Reporting Information [Line Items]
Total operating revenues	2,077	719
Depreciation, depletion and amortization expense	274	94
Impairments	0
Operating income	1,278	295
Interest expense	41	31
Loss on derivatives	(3,925)	(191)
Loss on extinguishment of debt	0
Other Income, Net	0	1
Assets	10,766	4,741
Capital investments	544	266
Restructuring charges		6
Merger-related expenses	25	1
Benefit from income taxes	4
E&P | Intersegment Revenues
Segment Reporting Information [Line Items]
Total operating revenues	(3)	(14)
Marketing
Segment Reporting Information [Line Items]
Total operating revenues	866	353
Depreciation, depletion and amortization expense	1	2
Impairments	0
Operating income	21	6
Interest expense	0	0
Loss on derivatives	0	0
Loss on extinguishment of debt	0
Other Income, Net	0	0
Assets	969	396
Capital investments	0	0
Benefit from income taxes	0
Marketing | Intersegment Revenues
Segment Reporting Information [Line Items]
Total operating revenues	1,889	644
Other
Segment Reporting Information [Line Items]
Total operating revenues	0	0
Depreciation, depletion and amortization expense	0	0
Impairments	0
Operating income	0	0
Interest expense	0	0
Loss on derivatives	(2)	0
Loss on extinguishment of debt	(2)
Other Income, Net	0	0
Assets	112	110
Capital investments	0	0
Benefit from income taxes	0
Other | Intersegment Revenues
Segment Reporting Information [Line Items]
Total operating revenues	$ 0	$ 0

Segment Information (Schedule o

Segment Information (Schedule of Other Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021
Segment Reporting Information [Line Items]
Cash and cash equivalents	$ 21	$ 28
Accounts receivable	1,071	1,160
Property, plant and equipment	10,215	9,938
Unamortized debt expense	55	57
Right-of-use lease assets	186	187
TOTAL ASSETS	11,847	$ 11,848	$ 5,247
Other
Segment Reporting Information [Line Items]
Cash and cash equivalents	21		4
Accounts receivable	1		0
Prepayments	6		6
Property, plant and equipment	10		15
Unamortized debt expense	9		11
Right-of-use lease assets	63		70
Non-qualified retirement plan	2		4
TOTAL ASSETS	$ 112		$ 110