Expand Energy (EXE) 10-Q 6 Aug 19 2019 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2019	Jul. 31, 2019
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	1-13726
Entity Registrant Name	CHESAPEAKE ENERGY CORPORATION
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-1395733
Entity Address, Address Line One	6100 North Western Avenue,
Entity Address, City or Town	Oklahoma City,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	73118
City Area Code	(405)
Local Phone Number	848-8000
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		1,634,513,223
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Entity Central Index Key	0000895126
Current Fiscal Year End Date	--12-31
Common Stock, par value $0.01
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, par value $0.01
Trading Symbol	CHK
Security Exchange Name	NYSE
6.625% Senior Notes due 2020
Entity Information [Line Items]
Title of 12(b) Security	6.625% Senior Notes due 2020
Trading Symbol	CHK20A
Security Exchange Name	NYSE
6.875% Senior Notes due 2020
Entity Information [Line Items]
Title of 12(b) Security	6.875% Senior Notes due 2020
Trading Symbol	CHK20
Security Exchange Name	NYSE
6.125% Senior Notes due 2021
Entity Information [Line Items]
Title of 12(b) Security	6.125% Senior Notes due 2021
Trading Symbol	CHK21
Security Exchange Name	NYSE
5.375% Senior Notes due 2021
Entity Information [Line Items]
Title of 12(b) Security	5.375% Senior Notes due 2021
Trading Symbol	CHK21A
Security Exchange Name	NYSE
4.875% Senior Notes due 2022
Entity Information [Line Items]
Title of 12(b) Security	4.875% Senior Notes due 2022
Trading Symbol	CHK22
Security Exchange Name	NYSE
5.75% Senior Notes due 2023
Entity Information [Line Items]
Title of 12(b) Security	5.75% Senior Notes due 2023
Trading Symbol	CHK23
Security Exchange Name	NYSE
4.50% Cumulative Convertible Preferred Stock
Entity Information [Line Items]
Title of 12(b) Security	4.5% Cumulative Convertible Preferred Stock
Trading Symbol	CHK Pr D
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
CURRENT ASSETS:
Cash and cash equivalents ($2 and $1 attributable to our VIE)	$ 4	$ 4
Accounts receivable, net	1,021	1,247
Short-term derivative assets	224	209
Other current assets	135	138
Total Current Assets	1,384	1,598
Oil and natural gas properties, at cost based on successful efforts accounting:
Proved oil and natural gas properties ($755 and $755 attributable to our VIE)	29,675	25,407
Unproved properties	2,210	1,561
Other property and equipment	1,808	1,721
Total Property and Equipment, at Cost	33,693	28,689
Less: accumulated depreciation, depletion and amortization (($710) and ($707) attributable to our VIE)	(18,860)	(17,886)
Property and equipment held for sale, net	12	15
Total Property and Equipment, Net	14,845	10,818
LONG-TERM ASSETS:
Long-term derivative assets	63	76
Other long-term assets	248	243
TOTAL ASSETS	16,540	12,735
CURRENT LIABILITIES:
Accounts payable	611	763
Current maturities of long-term debt, net	0	381
Accrued interest	157	141
Short-term derivative liabilities	22	3
Other current liabilities ($1 and $2 attributable to our VIE)	1,430	1,599
Total Current Liabilities	2,220	2,887
LONG-TERM LIABILITIES:
Long-term debt, net	9,701	7,341
Long-term derivative liabilities	3	0
Asset retirement obligations, net of current portion	181	155
Other long-term liabilities	205	219
Total Long-Term Liabilities	10,090	7,715
CONTINGENCIES AND COMMITMENTS (Note 7)
Chesapeake Stockholders’ Equity:
Preferred stock, $0.01 par value, 20,000,000 shares authorized: 5,603,458 shares outstanding	1,671	1,671
Common stock, $0.01 par value, 3,000,000,000 and 2,000,000,000 shares authorized: 1,634,486,189 and 913,715,512 shares issued	16	9
Additional paid-in capital	16,380	14,378
Accumulated deficit	(13,835)	(13,912)
Accumulated other comprehensive loss	(5)	(23)
Less: treasury stock, at cost; 5,607,556 and 3,246,553 common shares	(36)	(31)
Total Chesapeake Stockholders’ Equity	4,191	2,092
Noncontrolling interests	39	41
Total Equity	4,230	2,133
TOTAL LIABILITIES AND EQUITY	$ 16,540	$ 12,735

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Preferred stock, par value (usd per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (shares)	20,000,000	20,000,000
Preferred stock, shares outstanding (shares)	5,603,458	5,603,458
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (shares)	3,000,000,000	2,000,000,000
Common stock, shares issued (shares)	1,634,486,189	913,715,512
Treasury stock, common shares (shares)	5,607,556	3,246,553
VIE, cash and cash equivalents	$ 4	$ 4
VIE, proved oil and natural gas properties	29,675	25,407
VIE, accumulated depreciation, depletion and amortization	(18,860)	(17,886)
VIE, other current liabilities	1,430	1,599
Variable Interest Entities, Primary Beneficiary [Member]
VIE, cash and cash equivalents	2	1
VIE, proved oil and natural gas properties	755	755
VIE, accumulated depreciation, depletion and amortization	(710)	(707)
VIE, other current liabilities	$ 1	$ 2

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
REVENUES AND OTHER:
Revenues	$ 2,386	$ 2,289	[1]	$ 4,582		$ 4,813	[1]
Gains on sales of assets	1	18	[1]	20		37	[1],[2]
OPERATING EXPENSES:
Production taxes	40	26	[1]	74		57	[1]
General and administrative	89	105	[1]	192		192	[1]
Restructuring and other termination costs	0	0	[1]	0		38	[1]
Provision for legal contingencies, net	3	4	[1]	3		9	[1]
Depreciation, depletion and amortization	580	471	[1]	1,099		930	[1],[2]
Impairments	1	54	[1]	2		64	[1],[2]
Other operating (income) expense	3	(1)	[1]	64		(1)	[1]
Total Operating Expenses	2,108	2,449	[1]	4,486		4,931	[1]
INCOME (LOSS) FROM OPERATIONS	278	(160)	[1]	96		(118)	[1]
OTHER INCOME (EXPENSE):
Interest expense	(175)	(155)	[1]	(336)	[1]	(317)	[1]
Gains (losses) on investments	(23)	0	[1]	(24)		139	[1]
Other income	18	57	[1]	27	[1]	56	[1]
Total Other Expense	(180)	(98)	[1]	(333)	[1]	(122)	[1]
INCOME (LOSS) BEFORE INCOME TAXES	98	(258)	[1]	(237)	[1]	(240)	[1]
Income tax benefit	0	(9)	[1]	(314)	[1]	(9)	[1]
NET INCOME (LOSS)	98	(249)	[3]	77	[2],[3]	(231)	[2],[3]
Net income attributable to noncontrolling interests	0	0	[3]	0	[3]	(1)	[3]
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98	(249)	[1]	77	[1]	(232)	[1]
Preferred stock dividends	(23)	(23)	[1]	(46)		(46)	[1]
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ 75	$ (272)	[1]	$ 31		$ (278)	[1]
EARNINGS (LOSS) PER COMMON SHARE:
Basic (in dollars per share)	$ 0.05	$ (0.30)	[1]	$ 0.02		$ (0.31)	[1]
Diluted (in dollars per share)	$ 0.05	$ (0.30)	[1]	$ 0.02		$ (0.31)	[1]
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Basic (in shares)	1,628	909	[1]	1,505		908	[1]
Diluted (in shares)	1,628	909	[1]	1,505		908	[1]
Oil, natural gas and NGL
REVENUES AND OTHER:
Revenues	$ 1,454	$ 982	[1]	$ 2,383		$ 2,225	[1]
Marketing
REVENUES AND OTHER:
Revenues	916	1,273	[1]	2,149		2,519	[1]
OPERATING EXPENSES:
Expense	940	1,292	[1]	2,170		2,560	[1]
Oil, natural gas and NGL and Marketing
REVENUES AND OTHER:
Revenues	2,370	2,255	[1]	4,532		4,744	[1]
Other
REVENUES AND OTHER:
Revenues	15	16	[1]	30		32	[1]
Oil, natural gas and NGL production
OPERATING EXPENSES:
Expense	166	138	[1]	298		285	[1]
Oil, natural gas and NGL gathering, processing and transportation
OPERATING EXPENSES:
Expense	271	340	[1]	545		696	[1]
Exploration
OPERATING EXPENSES:
Expense	$ 15	$ 20	[1]	$ 39		$ 101	[1]
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
NET INCOME (LOSS)		$ 98	$ (249)	[1]	$ 77	[1],[2]	$ (231)	[1],[2]
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Unrealized gains on derivative instruments	[3]	0			0
Unrealized gains on derivative instruments	[1],[3]		0				0
Reclassification of losses on settled derivative instruments	[3]	8			18
Reclassification of losses on settled derivative instruments	[1],[3]		7				17
Other Comprehensive Income		8	7	[1]	18		17	[1]
COMPREHENSIVE INCOME (LOSS)		106	(242)	[1]	95		(214)	[1]
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	0	[1]	0		(1)
Net Income (Loss) Attributable to Noncontrolling Interest		0	0	[1]	0	[1]	1	[1]
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		$ 106	$ (242)	[1]	$ 95		$ (215)	[1]
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018
CASH FLOWS FROM OPERATING ACTIVITIES:
NET INCOME (LOSS)	[1],[2]	$ 77	$ (231)
ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH PROVIDED BY OPERATING ACTIVITIES:
Depreciation, depletion and amortization		1,099	930	[2],[3]
Deferred income tax benefit		(314)	(9)	[2]
Derivative losses, net		30	368	[2]
Cash payments on derivative settlements, net		15	(55)	[2]
Stock-based compensation		17	18	[2]
Gains on sales of assets		(20)	(37)	[2],[3]
Impairments		2	64	[2],[3]
Exploration		25	73	[2]
(Gains) losses on investments		18	(139)	[2]
Other		41	(93)	[2]
Changes in assets and liabilities		(137)	62	[2]
Net Cash Provided By Operating Activities		853	951	[2]
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs		(1,070)	(928)	[2]
Business combination, net		(353)	0	[2]
Acquisitions of proved and unproved properties		(17)	(102)	[2]
Proceeds from divestitures of proved and unproved properties		82	384	[2]
Additions to other property and equipment		(18)	(5)	[2]
Proceeds from sales of other property and equipment		4	74	[2]
Proceeds from sales of investments		0	74	[2]
Net Cash Used In Investing Activities		(1,372)	(503)	[2]
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings		6,416	6,118	[2]
Payments on revolving credit facility borrowings		(5,452)	(6,393)	[2]
Cash paid to purchase debt		(381)	0	[2]
Extinguishment of other financing		0	(122)	[2]
Cash paid for preferred stock dividends		(46)	(46)	[2]
Distributions to noncontrolling interest owners		(2)	(3)	[2]
Other		(16)	(4)	[2]
Net Cash Provided By (Used In) Financing Activities		519	(450)	[2]
Net decrease in cash and cash equivalents		0	(2)	[2]
Cash and cash equivalents, beginning of period		4	5	[2]
Cash and cash equivalents, end of period		4	3	[2]
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid, net of capitalized interest		296	316	[2]
Income taxes paid, net of refunds received		(5)	(7)	[2]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Common stock issued for business combination		2,037	0	[2]
Change in senior notes exchanged		35	0	[2]
Change in accrued drilling and completion costs
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in non-cash investing and financing activities		17	109	[2]
Change in divested proved and unproved properties
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in non-cash investing and financing activities		$ (125)	$ 0	[2]
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) - USD ($) $ in Millions		Total		PREFERRED STOCK		COMMON STOCK		ADDITIONAL PAID-IN CAPITAL	ACCUMULATED DEFICIT		ACCUMULATED OTHER COMPREHENSIVE LOSS:	TREASURY STOCK – COMMON:	TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY	NONCONTROLLING INTERESTS:
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2017	[1]			$ 1,671		$ 9		$ 14,437	$ (14,130)		$ (57)	$ (31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares issued for WildHorse Merger	[1]					0		0
Stock-based compensation	[1]							17
Dividends on preferred stock	[1]							(46)
Net income (loss) attributable to Chesapeake		$ (232)	[2]						(232)	[1]
Hedging activity	[1]										17
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans	[1]											(4)
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans	[1]											4
Chesapeake stockholders’ equity, end of period at Jun. 30, 2018	[1]			1,671		9		14,408	(14,370)		(40)	(31)	$ 1,647
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2017	[1]													$ 44
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests		(1)	[3]											1	[1]
Distributions to noncontrolling interest owners	[1]													(3)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2018	[1]													42
Chesapeake stockholders’ equity, beginning of period at Mar. 31, 2018	[1]			1,671		9		14,419	(14,121)		(47)	(32)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares issued for WildHorse Merger	[1]					0		0
Stock-based compensation	[1]							12
Dividends on preferred stock	[1]							(23)
Net income (loss) attributable to Chesapeake		(249)	[2]						(249)	[1]
Hedging activity	[1]										7
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans	[1]											0
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans	[1]											1
Chesapeake stockholders’ equity, end of period at Jun. 30, 2018	[1]			1,671		9		14,408	(14,370)		(40)	(31)	1,647
Stockholders' equity attributable to noncontrolling interest, beginning of period at Mar. 31, 2018	[1]													43
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests		0	[3]											0	[1]
Distributions to noncontrolling interest owners	[1]													(1)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2018	[1]													42
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Total Equity	[1]	1,689
Total Equity		2,133
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2018		2,092		1,671	[1]	9		14,378	(13,912)		(23)	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares issued for WildHorse Merger						7		2,030
Stock-based compensation								18
Dividends on preferred stock								(46)
Net income (loss) attributable to Chesapeake		77	[2]						77
Hedging activity											18
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans												(7)
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans												2
Chesapeake stockholders’ equity, end of period at Jun. 30, 2019		4,191		1,671		16	[1]	16,380	(13,835)	[1]	(5)	(36)	4,191
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2018		41												41
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests		0	[3]											0
Distributions to noncontrolling interest owners														(2)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2019		39												39
Chesapeake stockholders’ equity, beginning of period at Mar. 31, 2019				1,671	[1]	16		16,392	(13,933)		(13)	(36)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares issued for WildHorse Merger						0		0
Stock-based compensation								11
Dividends on preferred stock								(23)
Net income (loss) attributable to Chesapeake		98							98
Hedging activity											8
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans												(1)
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans												1
Chesapeake stockholders’ equity, end of period at Jun. 30, 2019		4,191		$ 1,671		$ 16	[1]	$ 16,380	$ (13,835)	[1]	$ (5)	$ (36)	$ 4,191
Stockholders' equity attributable to noncontrolling interest, beginning of period at Mar. 31, 2019														41
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests		0												0
Distributions to noncontrolling interest owners														(2)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2019		39												$ 39
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Total Equity		$ 4,230
[1]	Financial information for prior periods has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

CONSOLIDATED STATEMENTS OF ST_2

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) (Parenthetical) - TREASURY STOCK – COMMON: - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Purchase of shares for company benefit plans (in shares)	81,093	17,046	2,620,566	1,468,524
Release of shares from company benefit plans (in shares)	148,767	114,450	259,563	389,857

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Basis of Presentation and Summary of Significant Accounting Policies	Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation The accompanying condensed consolidated financial statements of Chesapeake were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures have been condensed or omitted. This Form 10-Q relates to the three and six months ended June 30, 2019 (the “Current Quarter” and the “Current Period”, respectively) and the three and six months ended June 30, 2018 (the “Prior Quarter” and the “Prior Period”, respectively). Our Form 8-K dated May 9, 2019 should be read in conjunction with this Form 10-Q. The accompanying condensed consolidated financial statements reflect all normal recurring adjustments which, in the opinion of management, are necessary for a fair statement of our condensed consolidated financial statements and accompanying notes and include the accounts of our direct and indirect wholly owned subsidiaries and entities in which we have a controlling financial interest. Intercompany accounts and balances have been eliminated . Recast Financial Information for Change in Accounting Principle In the first quarter of 2019, we voluntarily changed our method of accounting for oil and natural gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. Although the full cost method of accounting for oil and natural gas exploration and development activities continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the SEC and, because it is more widely used in the industry, we expect the change to improve the comparability of our financial statements to our peers. We also believe the successful efforts method provides a more representational depiction of assets and operating results and provides for our investments in oil and natural gas properties to be assessed for impairment in accordance with Accounting Standards Codification (ASC) Topic 360, Property Plant and Equipment, rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. For detailed information regarding the effects of the change to the successful efforts method, see Note 2 . Oil and Natural Gas Properties We follow the successful efforts method of accounting for our oil and natural gas properties. Under this method, exploration costs, such as exploratory geological and geophysical costs, expiration of unproved leasehold, delay rentals and exploration overhead are expensed as incurred. All costs related to production, general corporate overhead and similar activities are also expensed as incurred. All property acquisition costs and development costs are capitalized when incurred. Exploratory drilling costs are initially capitalized, or suspended, pending the determination of proved reserves. If proved reserves are found, drilling costs remain capitalized and are classified as proved properties. Costs of unsuccessful wells are charged to exploration expense. For exploratory wells that find reserves that cannot be classified as proved when drilling is completed, costs continue to be capitalized as suspended exploratory drilling costs if there have been sufficient reserves found to justify completion as a producing well and sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If we determine that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed. In some instances, this determination may take longer than one year. We review the status of all suspended exploratory drilling costs quarterly. Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of oil and natural gas, are capitalized. Costs of drilling and equipping successful wells, costs to construct or acquire facilities, and associated asset retirement costs are depreciated using the unit-of-production (UOP) method based on total estimated proved developed oil and gas reserves. Costs of acquiring proved properties, including leasehold acquisition costs transferred from unproved properties, are depleted using the UOP method based on total estimated proved developed and undeveloped reserves. Proceeds from the sales of individual oil and natural gas properties and the capitalized costs of individual properties sold or abandoned are credited and charged, respectively, to accumulated depreciation, depletion and amortization, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recognized until an entire amortization base is sold. However, a gain or loss is recognized from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base. When circumstances indicate that the carrying value of proved oil and gas properties may not be recoverable, we compare unamortized capitalized costs to the expected undiscounted pre-tax future cash flows for the associated assets grouped at the lowest level for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows, based on our estimate of future crude oil and natural gas prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized costs, the capitalized costs are reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820, Fair Value Measurements . If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production volumes, commodity prices, operating costs, and capital investment plans, considering all available information at the date of review. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. We have classified these fair value measurements as Level 3 in the fair value hierarchy. Capitalized Interest Interest from external borrowings is capitalized on significant investments in major development projects until the asset is ready for service using the weighted average borrowing rate of outstanding borrowings. Capitalized interest is determined by multiplying our weighted average borrowing cost on debt by the average amount of qualifying costs incurred. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying asset. Recently Issued Accounting Standards In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (“ASC 842”) , which requires lessees to recognize a lease liability and a right-of-use (ROU) asset on the balance sheet for all leases, including operating leases, with terms in excess of 12 months. As the implicit rate of the lease is not always readily determinable, the company uses its incremental borrowing rate to calculate the present value of lease payments based on information available at the commencement date. Operating ROU assets are included in other long-term assets while operating lease liabilities are included in other current and other long-term liabilities on the condensed consolidated balance sheet. Finance ROU assets are reflected in total property and equipment, net, while finance lease liabilities are included in other current and other long-term liabilities on the condensed consolidated balance sheet. ASC 842 does not apply to our leases of mineral rights to explore for or use oil and natural gas resources, including the intangible rights to explore for those natural resources and rights to use the land in which those natural resources are contained. We adopted the new standard on January 1, 2019 and as permitted by ASU 2018-11, Leases (Topic 842): Targeted Improvements , we will not adjust comparative-period financial statements and will continue to apply the guidance in Topic 840, including its disclosure requirements, in the comparative periods presented prior to adoption. No cumulative-effect adjustment to retained earnings was required as a result of the modified retrospective approach. Upon adoption of ASC 842, we made certain elections permitting us to not reassess: (1) whether any expired or existing contracts contained leases (2) the lease classification for any expired or existing leases, and (3) initial direct costs for any existing leases. Upon adoption of ASC 842, we also made an election permitting us to continue applying our current policy for land easements. The adoption of ASC 842 did not result in a material impact on our balance sheet, results of operations or cash flows. Short-term leases will not be recognized on the balance sheet as an asset or a liability, and the related rental expense will be expensed as incurred. We have short-term lease agreements related to most of our drilling rig arrangements and hydraulic fracturing arrangements and some of our compressor rental arrangements. See Note 9 for further information regarding leases.

Change in Accounting Principle

Change in Accounting Principle	6 Months Ended
	Jun. 30, 2019
Accounting Changes and Error Corrections [Abstract]
Change in Accounting Principle	Change in Accounting Principle In the first quarter of 2019, we voluntarily changed our method of accounting for oil and natural gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. In general, under successful efforts, exploration costs such as exploratory dry holes, exploratory geophysical and geological costs, delay rentals, unproved leasehold impairments and exploration overhead are charged against earnings as incurred, versus being capitalized under the full cost method of accounting. The successful efforts method also provides for the assessment of potential property impairments by comparing the net carrying value of oil and natural gas properties to associated projected undiscounted pre-tax future net cash flows. If the expected undiscounted pre-tax future net cash flows are lower than the unamortized capitalized costs, the capitalized costs are reduced to fair value. Under the full cost method of accounting, a write-down would be required if the net carrying value of oil and natural gas properties exceeds a full cost ceiling using an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months. In addition, gains or losses, if applicable, are generally recognized on the disposition of oil and natural gas property and equipment under the successful efforts method, as opposed to an adjustment to the net carrying value of the assets remaining under the full cost method. Our condensed consolidated financial statements have been recast to reflect these differences. Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 1,454 $ — $ 1,454 Marketing 916 — 916 Total Revenues 2,370 — 2,370 Other — 15 15 Gains on sales of assets — 1 1 Total Revenues and Other 2,370 16 2,386 OPERATING EXPENSES: Oil, natural gas and NGL production 166 — 166 Oil, natural gas and NGL gathering, processing and transportation 271 — 271 Production taxes 40 — 40 Exploration — 15 15 Marketing 940 — 940 General and administrative 76 13 89 Provisions for legal contingencies, net 3 — 3 Depreciation, depletion and amortization 419 161 580 Impairments 1 — 1 Gain on sale of oil and natural gas properties (1 ) 1 — Other operating expense 4 (1 ) 3 Total Operating Expenses 1,919 189 2,108 INCOME FROM OPERATIONS 451 (173 ) 278 OTHER INCOME (EXPENSE): Interest expense (131 ) (44 ) (175 ) Losses on investments (23 ) — (23 ) Other income 13 5 18 Total Other Expense (141 ) (39 ) (180 ) INCOME BEFORE INCOME TAXES 310 (212 ) 98 Income tax benefit — — — NET INCOME 310 (212 ) 98 Net income attributable to noncontrolling interests — — — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 310 (212 ) 98 Preferred stock dividends (23 ) — (23 ) Earnings allocated to participating securities (1 ) 1 — NET INCOME AVAILABLE TO COMMON STOCKHOLDERS $ 286 $ (211 ) $ 75 EARNINGS PER COMMON SHARE: Basic $ 0.18 $ (0.13 ) $ 0.05 Diluted $ 0.18 $ (0.13 ) $ 0.05 WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 1,628 — 1,628 Diluted 1,628 — 1,628 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Full Cost Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 982 $ — $ 982 Marketing 1,273 — 1,273 Total Revenues 2,255 — 2,255 Other — 16 16 Gains on sales of assets — 18 18 Total Revenues and Other 2,255 34 2,289 OPERATING EXPENSES: Oil, natural gas and NGL production 138 — 138 Oil, natural gas and NGL gathering, processing and transportation 340 — 340 Production taxes 26 — 26 Exploration — 20 20 Marketing 1,292 — 1,292 General and administrative 91 14 105 Provision for legal contingencies, net 4 — 4 Depreciation, depletion and amortization 290 181 471 Impairments 46 8 54 Other operating income (2 ) 1 (1 ) Total Operating Expenses 2,225 224 2,449 INCOME (LOSS) FROM OPERATIONS 30 (190 ) (160 ) OTHER INCOME (EXPENSE): Interest expense (117 ) (38 ) (155 ) Other income (expense) 62 (5 ) 57 Total Other Expense (55 ) (43 ) (98 ) LOSS BEFORE INCOME TAXES (25 ) (233 ) (258 ) Income tax benefit (9 ) — (9 ) NET LOSS (16 ) (233 ) (249 ) Net income attributable to noncontrolling interests (1 ) 1 — NET LOSS ATTRIBUTABLE TO CHESAPEAKE (17 ) (232 ) (249 ) Preferred stock dividends (23 ) — (23 ) NET LOSS AVAILABLE TO COMMON STOCKHOLDERS $ (40 ) $ (232 ) $ (272 ) LOSS PER COMMON SHARE: Basic $ (0.04 ) $ (0.26 ) $ (0.30 ) Diluted $ (0.04 ) $ (0.26 ) $ (0.30 ) WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 909 — 909 Diluted 909 — 909 Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 2,383 $ — $ 2,383 Marketing 2,149 — 2,149 Total Revenues 4,532 — 4,532 Other — 30 30 Gains on sales of assets — 20 20 Total Revenues and Other 4,532 50 4,582 OPERATING EXPENSES: Oil, natural gas and NGL production 298 — 298 Oil, natural gas and NGL gathering, processing and transportation 545 — 545 Production taxes 74 — 74 Exploration — 39 39 Marketing 2,170 — 2,170 General and administrative 164 28 192 Provision for legal contingencies 3 — 3 Depreciation, depletion and amortization 776 323 1,099 Gain on sale of oil and natural gas properties (10 ) 10 — Impairments 2 — 2 Other operating expense 64 — 64 Total Operating Expenses 4,086 400 4,486 INCOME FROM OPERATIONS 446 (350 ) 96 OTHER INCOME (EXPENSE): Interest expense (266 ) (70 ) (336 ) Losses on investments (24 ) — (24 ) Other income 20 7 27 Total Other Expense (270 ) (63 ) (333 ) INCOME (LOSS) BEFORE INCOME TAXES 176 (413 ) (237 ) Income tax benefit (314 ) — (314 ) NET INCOME 490 (413 ) 77 Net income attributable to noncontrolling interests (1 ) 1 — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 489 (412 ) 77 Preferred stock dividends (46 ) — (46 ) Earnings allocated to participating securities (3 ) 3 — NET INCOME AVAILABLE TO COMMON STOCKHOLDERS $ 440 $ (409 ) $ 31 EARNINGS PER COMMON SHARE: Basic $ 0.29 $ (0.27 ) $ 0.02 Diluted $ 0.29 $ (0.27 ) $ 0.02 WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 1,505 — 1,505 Diluted 1,505 — 1,505 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Full Cost Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 2,225 $ — $ 2,225 Marketing 2,519 — 2,519 Total Revenues 4,744 — 4,744 Other — 32 32 Gains on sales of assets — 37 37 Total Revenues and Other 4,744 69 4,813 OPERATING EXPENSES: Oil, natural gas and NGL production 285 — 285 Oil, natural gas and NGL gathering, processing and transportation 696 — 696 Production taxes 57 — 57 Exploration — 101 101 Marketing 2,560 — 2,560 General and administrative 163 29 192 Restructuring and other termination costs 38 — 38 Provision for legal contingencies, net 9 — 9 Depreciation, depletion and amortization 576 354 930 Impairments 46 18 64 Other operating (income) expense 6 (7 ) (1 ) Total Operating Expenses 4,436 495 4,931 INCOME (LOSS) FROM OPERATIONS 308 (426 ) (118 ) OTHER INCOME (EXPENSE): Interest expense (240 ) (77 ) (317 ) Gains on investments 139 — 139 Other income 62 (6 ) 56 Total Other Expense (39 ) (83 ) (122 ) INCOME (LOSS) BEFORE INCOME TAXES 269 (509 ) (240 ) Income tax benefit (9 ) — (9 ) NET INCOME (LOSS) 278 (509 ) (231 ) Net income attributable to noncontrolling interests (2 ) 1 (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE 276 (508 ) (232 ) Preferred stock dividends (46 ) — (46 ) Earnings allocated to participating securities (2 ) 2 — NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS $ 228 $ (506 ) $ (278 ) EARNINGS (LOSS) PER COMMON SHARE: Basic $ 0.25 $ (0.56 ) $ (0.31 ) Diluted $ 0.25 $ (0.56 ) $ (0.31 ) WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 908 — 908 Diluted 908 — 908 Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME $ 310 $ (212 ) $ 98 OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 8 — 8 Other Comprehensive Income 8 — 8 COMPREHENSIVE INCOME 318 (212 ) 106 COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS — — — COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 318 $ (212 ) $ 106 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET LOSS $ (16 ) $ (233 ) $ (249 ) OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 7 — 7 Other Comprehensive Income 7 — 7 COMPREHENSIVE LOSS (9 ) (233 ) (242 ) COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (1 ) 1 — COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (10 ) $ (232 ) $ (242 ) Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME (LOSS) $ 490 $ (413 ) $ 77 OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 18 — 18 Other Comprehensive Income 18 — 18 COMPREHENSIVE INCOME 508 (413 ) 95 COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (1 ) 1 — COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 507 $ (412 ) $ 95 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME (LOSS) $ 278 $ (509 ) $ (231 ) OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 17 — 17 Other Comprehensive Income 17 — 17 COMPREHENSIVE INCOME (LOSS) 295 (509 ) (214 ) COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (2 ) 1 (1 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ 293 $ (508 ) $ (215 ) Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Under Full Cost Successful Under Successful Efforts ($ in millions) CASH FLOWS FROM OPERATING ACTIVITIES: NET INCOME $ 490 $ (413 ) $ 77 ADJUSTMENTS TO RECONCILE NET INCOME TO CASH PROVIDED BY OPERATING ACTIVITIES: Depreciation, depletion and amortization 776 323 1,099 Deferred income tax benefit (314 ) — (314 ) Derivative losses, net 30 — 30 Cash receipts on derivative settlements, net 15 — 15 Stock-based compensation 17 — 17 Gains on sales of assets — (20 ) (20 ) Impairments 2 — 2 Exploration — 25 25 Losses on investments 18 — 18 Other 31 10 41 Changes in assets and liabilities (107 ) (30 ) (137 ) Net Cash Provided By Operating Activities 958 (105 ) 853 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs (1,104 ) 34 (1,070 ) Business combination, net (353 ) — (353 ) Acquisitions of proved and unproved properties (88 ) 71 (17 ) Proceeds from divestitures of proved and unproved properties 82 — 82 Additions to other property and equipment (18 ) — (18 ) Proceeds from sales of other property and equipment 4 — 4 Net Cash Used In Investing Activities (1,477 ) 105 (1,372 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,416 — 6,416 Payments on revolving credit facility borrowings (5,452 ) — (5,452 ) Cash paid to purchase debt (381 ) — (381 ) Cash paid for preferred stock dividends (46 ) — (46 ) Distributions to noncontrolling interest owners (2 ) — (2 ) Other (16 ) — (16 ) Net Cash Provided By Financing Activities 519 — 519 Net increase in cash and cash equivalents — — — Cash and cash equivalents, beginning of period 4 — 4 Cash and cash equivalents, end of period $ 4 $ — $ 4 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Under Full Cost Successful Under Successful Efforts ($ in millions) CASH FLOWS FROM OPERATING ACTIVITIES: NET INCOME (LOSS) $ 278 $ (509 ) $ (231 ) ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH PROVIDED BY OPERATING ACTIVITIES: Depreciation, depletion and amortization 576 354 930 Deferred income tax benefit (9 ) — (9 ) Derivative losses, net 368 — 368 Cash payments on derivative settlements, net (55 ) — (55 ) Stock-based compensation 18 — 18 Gains on sales of assets — (37 ) (37 ) Impairments 46 18 64 Exploration — 73 73 Gains on investments (139 ) — (139 ) Other (86 ) (7 ) (93 ) Changes in assets and liabilities 94 (32 ) 62 Net Cash Provided By Operating Activities 1,091 (140 ) 951 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs (979 ) 51 (928 ) Acquisitions of proved and unproved properties (191 ) 89 (102 ) Proceeds from divestitures of proved and unproved properties 384 — 384 Additions to other property and equipment (5 ) — (5 ) Proceeds from sales of other property and equipment 74 — 74 Proceeds from sales of investments 74 — 74 Net Cash Used In Investing Activities (643 ) 140 (503 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — 6,118 Payments on revolving credit facility borrowings (6,393 ) — (6,393 ) Extinguishment of other financing (122 ) — (122 ) Cash paid for preferred stock dividends (46 ) — (46 ) Distributions to noncontrolling interest owners (3 ) — (3 ) Other (4 ) — (4 ) Net Cash Used In Financing Activities (450 ) — (450 ) Net decrease in cash and cash equivalents (2 ) — (2 ) Cash and cash equivalents, beginning of period 5 — 5 Cash and cash equivalents, end of period $ 3 $ — $ 3 Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning and end of period 16 — 16 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 16,392 — 16,392 Stock-based compensation 11 — 11 Dividends on preferred stock (23 ) — (23 ) Balance, end of period 16,380 — 16,380 ACCUMULATED DEFICIT: Balance, beginning of period (15,481 ) 1,548 (13,933 ) Net income attributable to Chesapeake 310 (212 ) 98 Balance, end of period (15,171 ) 1,336 (13,835 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (13 ) — (13 ) Hedging activity 8 — 8 Balance, end of period (5 ) — (5 ) TREASURY STOCK – COMMON: Balance, beginning of period (36 ) — (36 ) Purchase of 81,093 shares for company benefit plans (1 ) — (1 ) Release of 148,767 shares from company benefit plans 1 — 1 Balance, end of period (36 ) — (36 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY 2,855 1,336 4,191 NONCONTROLLING INTERESTS: Balance, beginning of period 122 (81 ) 41 Net income attributable to noncontrolling interests — — — Distributions to noncontrolling interest owners (2 ) — (2 ) Balance, end of period 120 (81 ) 39 TOTAL EQUITY $ 2,975 $ 1,255 $ 4,230 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning of period 9 — 9 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,419 — 14,419 Stock-based compensation 12 — 12 Dividends on preferred stock (23 ) — (23 ) Balance, end of period 14,408 — 14,408 ACCUMULATED DEFICIT: Balance, beginning of period (16,240 ) 2,119 (14,121 ) Net loss attributable to Chesapeake (17 ) (232 ) (249 ) Balance, end of period (16,257 ) 1,887 (14,370 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (47 ) — (47 ) Hedging activity 7 — 7 Balance, end of period (40 ) — (40 ) TREASURY STOCK – COMMON: Balance, beginning of period (32 ) — (32 ) Purchase of 17,046 shares for company benefit plans — — — Release of 114,450 shares from company benefit plans 1 — 1 Balance, end of period (31 ) — (31 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY (DEFICIT) (240 ) 1,887 1,647 NONCONTROLLING INTERESTS: Balance, beginning of period 123 (80 ) 43 Net income attributable to noncontrolling interests 1 (1 ) — Distributions to noncontrolling interest owners (1 ) — (1 ) Balance, end of period 123 (81 ) 42 TOTAL EQUITY (DEFICIT) $ (117 ) $ 1,806 $ 1,689 Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning of period 9 — 9 Common shares issued for WildHorse Merger 7 — 7 Balance, end of period 16 — 16 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,378 — 14,378 Common shares issued for WildHorse Merger 2,030 — 2,030 Stock-based compensation 18 — 18 Dividends on preferred stock (46 ) — (46 ) Balance, end of period 16,380 — 16,380 ACCUMULATED DEFICIT: Balance, beginning of period (15,660 ) 1,748 (13,912 ) Net income attributable to Chesapeake 489 (412 ) 77 Balance, end of period (15,171 ) 1,336 (13,835 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (23 ) — (23 ) Hedging activity 18 — 18 Balance, end of period (5 ) — (5 ) TREASURY STOCK – COMMON: Balance, beginning of period (31 ) — (31 ) Purchase of 2,620,566 shares for company benefit plans (7 ) — (7 ) Release of 259,563 shares from company benefit plans 2 — 2 Balance, end of period (36 ) — (36 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY 2,855 1,336 4,191 NONCONTROLLING INTERESTS: Balance, beginning of period 123 (82 ) 41 Net income attributable to noncontrolling interests (1 ) 1 — Distributions to noncontrolling interest owners (2 ) — (2 ) Balance, end of period 120 (81 ) 39 TOTAL EQUITY $ 2,975 $ 1,255 $ 4,230 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning and end of period 9 — 9 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,437 — 14,437 Stock-based compensation 17 — 17 Dividends on preferred stock (46 ) — (46 ) Balance, end of period 14,408 — 14,408 ACCUMULATED DEFICIT: Balance, beginning of period (16,525 ) 2,395 (14,130 ) Net income (loss) attributable to Chesapeake 276 (508 ) (232 ) Cumulative effect of accounting change (8 ) — (8 ) Balance, end of period (16,257 ) 1,887 (14,370 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (57 ) — (57 ) Hedging activity 17 — 17 Balance, end of period (40 ) — (40 ) TREASURY STOCK – COMMON: Balance, beginning of period (31 ) — (31 ) Purchase of 1,468,524 shares for company benefit plans (4 ) — (4 ) Release of 389,857 shares from company benefit plans 4 — 4 Balance, end of period (31 ) — (31 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY (DEFICIT) (240 ) 1,887 1,647 NONCONTROLLING INTERESTS: Balance, beginning of period 124 (80 ) 44 Net income attributable to noncontrolling interests 2 (1 ) 1 Distributions to noncontrolling interest owners (3 ) — (3 ) Balance, end of period 123 (81 ) 42 TOTAL EQUITY (DEFICIT) $ (117 ) $ 1,806 $ 1,689

Oil and Natural Gas Property Tr

Oil and Natural Gas Property Transactions	6 Months Ended
	Jun. 30, 2019
Business Combinations [Abstract]
Oil and Natural Gas Property Transactions	Oil and Natural Gas Property Transactions WildHorse Acquisition On February 1, 2019, we acquired WildHorse Resource Development Corporation (“WildHorse”), an oil and gas company with operations in the Eagle Ford Shale and Austin Chalk formations in southeast Texas for approximately 717.4 million shares of our common stock and $381 million in cash. We funded the cash portion of the consideration through borrowings under the Chesapeake revolving credit facility. In connection with the closing, we acquired all of WildHorse’s debt. See Note 6 for additional information on the acquired debt. Purchase Price Allocation The acquisition of WildHorse and its corresponding merger (the “Merger”) with and into our wholly owned subsidiary, Brazos Valley Longhorn, L.L.C. (“Brazos Valley Longhorn” or “BVL”) has been accounted for as a business combination, using the acquisition method. The following table represents the preliminary allocation of the total purchase price of WildHorse to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date. Certain data necessary to complete the purchase price allocation is not yet available, and includes, but is not limited to, valuation of pre-acquisition contingencies, final tax returns that provide the underlying tax basis of WildHorse’s assets and liabilities and final appraisals of assets acquired and liabilities assumed. We expect to complete the purchase price allocation during the 12-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. Preliminary Purchase Price Allocation ($ in millions) Consideration: Cash $ 381 Fair value of Chesapeake’s common stock issued in the Merger (a) 2,037 Total consideration $ 2,418 Fair Value of Liabilities Assumed: Current liabilities $ 166 Long-term debt 1,379 Deferred tax liabilities 314 Other long-term liabilities 36 Amounts attributable to liabilities assumed $ 1,895 Fair Value of Assets Acquired: Cash and cash equivalents $ 28 Other current assets 128 Proved oil and natural gas properties 3,264 Unproved properties 756 Other property and equipment 77 Other long-term assets 60 Amounts attributable to assets acquired $ 4,313 Total identifiable net assets $ 2,418 ___________________________________________ (a) Based on 717,376,170 Chesapeake common shares issued at closing at $2.84 per share (closing price as of February 1, 2019). We included in our condensed consolidated statements of operations revenues of $308 million , direct operating expenses of $369 million and other expenses of $54 million related to the WildHorse business for the period from February 1, 2019 to June 30, 2019. Pro Forma Financial Information The following unaudited pro forma financial information for the six months ended June 30, 2019 and three and six months ended 2018, respectively, is based on our historical consolidated financial statements adjusted to reflect as if the WildHorse acquisition had occurred on January 1, 2018. The information below reflects pro forma adjustments based on available information and certain assumptions that we believe are reasonable, including adjustments to conform the classification of expenses in WildHorse’s statements of operations to our classification for similar expenses and the estimated tax impact of pro forma adjustments. Three Months Ended June 30, Six Months Ended June 30, 2018 2019 2018 ($ in millions except per share data) Revenues $ 2,403 $ 4,574 $ 5,085 Net income (loss) available to common stockholders $ (332 ) $ 16 $ (360 ) Earnings per common share: Basic $ (0.20 ) $ 0.01 $ (0.22 ) Diluted $ (0.20 ) $ 0.01 $ (0.22 ) This unaudited pro forma information has been derived from historical information. The unaudited pro forma financial information is not necessarily indicative of what actually would have occurred if the acquisition had been completed as of the beginning of the periods presented, nor is it necessarily indicative of future results. Divestitures In the Prior Period, we sold portions of our acreage, producing properties and other related property and equipment in the Mid-Continent, including our Mississippian Lime assets, for approximately $491 million , subject to certain customary closing adjustments. Included in the sales were approximately 238,500 net acres and interests in approximately 3,200 wells. Also, in the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, we received proceeds of approximately $56 million , $5 million , $82 million and $23 million

Capitalized Exploratory Well Co

Capitalized Exploratory Well Costs	6 Months Ended
	Jun. 30, 2019
Extractive Industries [Abstract]
Capitalized Exploratory Well Costs	Capitalized Exploratory Well Costs A summary of the changes in our capitalized well costs for the Current Period is detailed below. Additions pending the determination of proved reserves excludes amounts capitalized and subsequently charged to expense within the same year. 2019 ($ in millions) Balance as of January 1 $ 36 Additions pending the determination of proved reserves 9 Divestitures and other — Reclassifications to proved properties (18 ) Charges to exploration expense — Balance as of June 30 $ 27 As of June 30, 2019, approximately $1 million

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2019
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share (EPS) is calculated using the weighted average number of common shares outstanding during the period and includes the effect of any participating securities as appropriate. Participating securities consist of unvested restricted stock issued to our employees and non-employee directors that provide dividend rights. Diluted EPS is calculated assuming the issuance of common shares for all potentially dilutive securities, provided the effect is not antidilutive. For all periods presented, our convertible senior notes did not have a dilutive effect and, therefore, were excluded from the calculation of diluted EPS. Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive: Three Months Ended Six Months Ended 2019 2018 2019 2018 (in millions) Common stock equivalent of our preferred stock outstanding 60 60 60 60 Common stock equivalent of our convertible senior notes outstanding 146 146 146 146 Participating securities 1 1 1 1

Debt

Debt	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Debt	Debt Our long-term debt consisted of the following as of June 30, 2019 and December 31, 2018: June 30, 2019 December 31, 2018 Principal Amount Carrying Principal Carrying ($ in millions) Floating rate senior notes due 2019 — — 380 380 6.625% senior notes due 2020 208 208 437 437 6.875% senior notes due 2020 93 93 227 227 6.125% senior notes due 2021 167 167 548 548 5.375% senior notes due 2021 127 127 267 267 4.875% senior notes due 2022 451 451 451 451 5.75% senior notes due 2023 338 338 338 338 7.00% senior notes due 2024 850 850 850 850 6.875% senior notes due 2025 (a) 700 704 — — 8.00% senior notes due 2025 1,300 1,292 1,300 1,291 5.5% convertible senior notes due 2026 (b) 1,250 882 1,250 866 7.5% senior notes due 2026 400 400 400 400 8.00% senior notes due 2026 919 884 — — 8.00% senior notes due 2027 1,300 1,299 1,300 1,299 2.25% contingent convertible senior notes due 2038 — — 1 1 Chesapeake revolving credit facility 1,372 1,372 419 419 BVL revolving credit facility (a) 686 686 — — Debt issuance costs — (53 ) — (53 ) Interest rate derivatives — 1 — 1 Total debt, net 10,161 9,701 8,168 7,722 Less current maturities of long-term debt, net — — (381 ) (381 ) Total long-term debt, net $ 10,161 $ 9,701 $ 7,787 $ 7,341 ___________________________________________ (a) On February 1, 2019, we acquired the debt of WildHorse which consisted of 6.875% Senior Notes due 2025 and a revolving credit facility. We now refer to this debt as our BVL Senior Notes and our BVL revolving credit facility, respectively. See further discussion below. (b) We are required to account for the liability and equity components of our convertible debt instrument separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rate for our 5.5% Convertible Senior Notes due 2026 is 11.5% . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. During the Current Quarter, the price of our common stock was below the threshold level for conversion and, as a result, the holders do not have the option to convert their notes in the third quarter of 2019. Chesapeake Revolving Credit Facility Our Chesapeake revolving credit facility matures in September 2023 and the current aggregate commitment of the lenders and borrowing base under the facility is $3.0 billion . The revolving credit facility provides for an accordion feature, pursuant to which the aggregate commitments thereunder may be increased to up to $4.0 billion from time to time, subject to agreement of the participating lenders and certain other customary conditions. Scheduled borrowing base redeterminations will continue to occur semiannually. Our borrowing base was reaffirmed in the Current Quarter, and our next borrowing base redetermination is scheduled for the fourth quarter of 2019. As of June 30, 2019 , we had outstanding borrowings of $1.372 billion under the Chesapeake revolving credit facility and had used $54 million of the Chesapeake revolving credit facility for various letters of credit. On February 1, 2019, we entered into a first amendment to our Chesapeake credit agreement. Among other things, the amendment (i) designated our subsidiary, Brazos Valley Longhorn, and its subsidiaries as unrestricted subsidiaries under the Chesapeake revolving credit facility and (ii) expressly permitted our initial investment in WildHorse under the limitations on investments covenant. As a result of BVL and its subsidiaries being designated as unrestricted subsidiaries under the Chesapeake revolving credit facility, transactions between BVL and its subsidiaries, on the one hand, and Chesapeake and its subsidiaries (other than BVL and its subsidiaries), on the other hand, are required to be on an arm’s-length basis, subject to certain exceptions, and Chesapeake is limited in the amount of investments it can make in BVL and its subsidiaries. Borrowings under the Chesapeake revolving credit facility bear interest at an alternative base rate (ABR) or LIBOR, at our election, plus an applicable margin ranging from 0.50% - 2.00% per annum for ABR loans and 1.50% - 3.00% per annum for LIBOR loans, depending on the percentage of the borrowing base then being utilized and whether our leverage ratio exceeds 4.00 to 1.00. The Chesapeake revolving credit facility is subject to various financial and other covenants. The terms of the Chesapeake credit agreement include covenants limiting, among other things, our ability to incur additional indebtedness, make investments or loans, incur liens, consummate mergers and similar fundamental changes, make restricted payments, make investments in unrestricted subsidiaries and enter into transactions with affiliates. The Chesapeake credit agreement contains financial covenants that require us to maintain (i) a leverage ratio of not more than 5.50 to 1 through the fiscal quarter ending September 30, 2019, which threshold decreases over time to 4.00 to 1.00 for the fiscal quarter ending March 31, 2021 thereafter, (ii) a secured leverage ratio of not more than 2.50 to 1.00 until the later of (x) the fiscal quarter ending March 31, 2021 or (y) the first fiscal quarter in which the Company’s leverage ratio does not exceed 4.00 to 1.00 and (iii) a fixed charge coverage ratio of not less than 2.00 to 1.00 through the fiscal quarter ending December 31, 2019; not less than 2.25 to 1.00 through the fiscal quarter ending June 30, 2020; and not less than 2.50 to 1.00 for the fiscal quarter ended September 30, 2020 and thereafter. As of June 30, 2019 , we were in compliance with all applicable financial covenants under the credit agreement and we were able to borrow up to the full availability under the Chesapeake revolving credit facility. BVL Revolving Credit Facility In connection with the acquisition of WildHorse, our subsidiary, BVL, became the borrower under the WildHorse revolving credit facility (as amended, the “BVL revolving credit facility”). The BVL revolving credit facility has a maximum credit amount of $2.0 billion , with current aggregate commitments and a borrowing base of $1.3 billion . The BVL revolving credit facility matures in December 2021. Scheduled borrowing base redeterminations occur on at least a semi-annual basis, primarily on the basis of estimated proved reserves. The borrowing base was reaffirmed in the Current Quarter of 2019 and the next scheduled redetermination is in the fourth quarter of 2019. As of June 30, 2019, we had outstanding borrowings of $686 million . The BVL revolving credit facility is guaranteed by certain of BVL’s subsidiaries (the “BVL Guarantors”) and is required to be secured by substantially all of the assets of BVL and BVL Guarantors, including mortgages on not less than 85% of the proved reserves of their oil and gas properties. On February 1, 2019, BVL, as successor by merger to WildHorse, entered into a sixth amendment to the BVL credit agreement. Among other things, the amendment (i) amended the merger covenant and the definition of change of control to permit our acquisition of WildHorse and (ii) permits borrowings under the BVL revolving credit facility to be used to redeem or repurchase the BVL senior notes so long as certain conditions are met. The obligations under the BVL revolving credit facility are the senior secured obligations of BVL and the BVL Guarantors. The obligations under the BVL revolving credit facility are not obligations of Chesapeake or any of its other subsidiaries. The obligations under the BVL revolving credit facility rank equally in right of payment with all other senior secured indebtedness of Brazos Valley Longhorn and the other BVL Guarantors, and are effectively senior to the BVL and the BVL Guarantors’ senior unsecured indebtedness, including their obligations under the BVL Senior Notes, to the extent of the value of the collateral securing the BVL revolving credit facility. The BVL revolving credit facility is used for the liquidity and expenses of BVL and its subsidiaries and not Chesapeake and its other subsidiaries. Revolving loans under the BVL revolving credit facility bear interest at an ABR, Eurodollar rate or LIBOR at BVL’s election, plus an applicable margin (ranging from 0.50% - 1.50% per annum for ABR loans, 1.50% - 2.50% per annum for Eurodollar loans and 1.50% - 2.50% per annum for LIBOR loans), depending on Brazos Valley Longhorn’s total commitment usage. The unused portion of the total commitments are subject to a commitment fee that varies from 0.375% to 0.500% , depending on BVL’s total commitment usage. The terms of the BVL credit agreement include covenants limiting, among other things, the ability of BVL and its restricted subsidiaries (as defined in the BVL credit agreement) to incur additional indebtedness, make investments or loans, incur liens, consummate mergers or similar fundamental changes, make restricted payments, including distributions to Chesapeake, and enter into transactions with affiliates, including Chesapeake and its other subsidiaries. The BVL credit agreement also contains financial covenants that require BVL to maintain (i)(x) if there are no loans outstanding thereunder, a ratio of net debt to EBITDAX (as defined in the BVL credit agreement) of not more than 4.00 to 1.00 as of the last day of each fiscal quarter or (y) if there are such loans outstanding, a ratio of total funded debt to EBITDAX of not more than 4.00 to 1.00 as of the last day of each fiscal quarter and (ii) a ratio of current assets (including availability under the BVL revolving credit facility) to current liabilities of not less than 1.00 to 1.00 as of the last day of each fiscal quarter. As of June 30, 2019, we were in compliance with all applicable financial covenants under the BVL credit agreement and we were able to borrow up to the full availability under the BVL revolving credit facility. Chesapeake Senior Notes In the Current Quarter, we issued at par approximately $919 million of 8.00% Senior Notes due 2026 (“2026 notes”) pursuant to a private exchange offer for the following outstanding senior unsecured notes: Notes Exchanged ($ in millions) 6.625% senior notes due 2020 $ 229 6.875% senior notes due 2020 134 6.125% senior notes due 2021 381 5.375% senior notes due 2021 140 Total $ 884 We may redeem some or all of the 2026 notes at any time prior to March 15, 2022 at a price equal to 100% of the principal amount of the notes to be redeemed plus a “make-whole” premium. At any time prior to March 15, 2022, we also may redeem up to 35% of the aggregate principal amount of each series of notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a specified redemption price. In addition, we may redeem some or all of the 2026 notes at any time on or after March 15, 2022 at the redemption prices in accordance with the terms of the notes, the indenture and supplemental indenture governing the notes. These senior notes are unsecured obligations of Chesapeake and rank equally in right of payment with all of our other existing and future senior unsecured indebtedness and rank senior in right of payment to all of our future subordinated indebtedness. Our obligations under the senior notes are jointly and severally, fully and unconditionally guaranteed by all of our wholly owned subsidiaries that guarantee the Chesapeake revolving credit facility and certain other unsecured senior notes. We accounted for the exchange as a modification to existing debt and no gain or loss was recognized. In the Current Quarter, we repaid upon maturity $380 million principal amount of our Floating Rate Senior Notes due April 2019 with borrowings from our Chesapeake revolving credit facility. BVL Senior Notes As a result of the completion of the acquisition of WildHorse, BVL assumed the obligations under WildHorse’s $700 million aggregate principal amount of 6.875% Senior Notes due 2025 (the “BVL Senior Notes”) and Brazos Valley Longhorn Finance Corp. (“BVL Finance Corp.”), a wholly owned subsidiary of BVL, became a co-issuer of the BVL Senior Notes. On February 1, 2019, BVL, as successor by merger to WildHorse, and BVL Finance Corp. entered into a fourth supplemental indenture (the “BVL supplemental indenture”) to the indenture governing the BVL Senior Notes (as supplemented, the “BVL indenture”). Pursuant to the BVL supplemental indenture, (i) BVL assumed the rights and obligations of WildHorse as issuer under the BVL indenture and (ii) BVL Finance Corp. was named as a co-issuer of the BVL senior notes under the BVL indenture. The BVL Senior Notes are the senior unsecured obligations of BVL, BVL Finance Corp. and the other BVL Guarantors. The BVL Senior Notes are not obligations of Chesapeake or any of its other subsidiaries. The BVL Senior Notes rank equally in right of payment with all other senior unsecured indebtedness of BVL, BVL Finance Corp. and the other BVL Guarantors, and will be effectively subordinated to BVL’s, BVL Finance Corp.’s and the other BVL Guarantors’ senior secured indebtedness, including their obligations under the BVL revolving credit facility, to the extent of the value of the collateral securing such indebtedness. The BVL indenture contains customary reporting covenants (including furnishing quarterly and annual reports to the holders of the BVL Senior Notes) and restrictive covenants that, among other things, limit the ability of BVL and its subsidiaries to: (i) pay dividends on, purchase or redeem BVL’s equity interests or purchase or redeem subordinated debt, unless such distributions, purchases or redemptions are permitted by certain exceptions, including for amounts based on BVL’s operating results, subject to the satisfaction of certain conditions, and a $25 million basket; (ii) make certain investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create or incur certain secured debt; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of BVL’s assets; (vii) enter into agreements that restrict distributions or other payments from BVL’s restricted subsidiaries to BVL; (viii) engage in transactions with affiliates, including Chesapeake and its other subsidiaries; and (ix) create unrestricted subsidiaries. These covenants are subject to a number of important qualifications and limitations. In addition, most of the covenants will be terminated before the BVL Senior Notes mature if at any time no default or event of default exists under the BVL indenture and the BVL Senior Notes receive an investment grade rating from both of two specified ratings agencies. The BVL indenture also contains customary events of default. The BVL credit agreement and the BVL indenture constrain the ability of BVL and its subsidiaries to make distributions or otherwise provide funds to, or guarantee the obligations of, Chesapeake and its other subsidiaries. The provisions of the BVL credit agreement and the BVL indenture require that all transactions between BVL and its subsidiaries, on the one hand, and Chesapeake and its other subsidiaries, on the other hand, be on an arm's-length basis, subject to certain exceptions. Fair Value of Debt We estimate the fair value of our senior notes based on the market value of our publicly traded debt as determined based on the yield of our senior notes (Level 1). The fair value of all other debt is based on a market approach using estimates provided by an independent investment financial data services firm (Level 2). Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: June 30, 2019 December 31, 2018 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ — $ — $ 381 $ 379 Long-term debt (Level 1) $ 3,321 $ 3,126 $ 3,495 $ 3,173 Long-term debt (Level 2) $ 6,380 $ 6,060 $ 3,846 $ 3,644

Contingencies and Commitments

Contingencies and Commitments	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Contingencies and Commitments	Contingencies and Commitments There have been no material developments in previously reported legal or environmental contingencies or commitments other than the items discussed below. For a discussion of commitments and contingencies, see “Contingencies and Commitments,” Note 4 to the Consolidated Financial Statements in our 2018 Form 10-K. Contingencies Litigation and Regulatory Proceedings We are involved in a number of litigation and regulatory proceedings including those described below. Many of these proceedings are in early stages, and many of them seek or may seek damages and penalties, the amount of which is indeterminate. Our total accrued liability in respect of litigation and regulatory proceedings is determined on a case-by-case basis and represents an estimate of probable losses after considering, among other factors, the progress of each case or proceeding, our experience and the experience of others in similar cases or proceedings, and the opinions and views of legal counsel. Significant judgment is required in making these estimates and our final liabilities may ultimately be materially different. Business Operations. We are involved in various lawsuits and disputes incidental to our business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions. We and other natural gas producers have been named in various lawsuits alleging underpayment of royalties and other shares of the proceeds of production. The suits against us allege, among other things, that we used below-market prices, made improper deductions, utilized improper measurement techniques, entered into arrangements with affiliates that resulted in underpayment of amounts owed in connection with the production and sale of natural gas and NGL, or similar theories. These lawsuits include cases filed by individual royalty owners and putative class actions, some of which seek to certify a statewide class. The lawsuits seek compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our payment practices, pre-and post-judgment interest, and attorney’s fees and costs. Royalty plaintiffs have varying provisions in their respective leases, oil and gas law varies from state to state, and royalty owners and producers differ in their interpretation of the legal effect of lease provisions governing royalty calculations. We have resolved a number of these claims through negotiated settlements of past and future royalty obligations and have prevailed in various other lawsuits. We are currently defending numerous lawsuits seeking damages with respect to underpayment of royalties or other shares of the proceeds of production in multiple states where we have operated, including those discussed below. On December 9, 2015, the Commonwealth of Pennsylvania, by the Office of Attorney General, filed a lawsuit in the Bradford County Court of Common Pleas related to royalty underpayment and lease acquisition and accounting practices with respect to properties in Pennsylvania. The lawsuit, which primarily relates to the Marcellus Shale and Utica Shale, alleges that we violated the Pennsylvania Unfair Trade Practices and Consumer Protection Law (UTPCPL) by making improper deductions and entering into arrangements with affiliates that resulted in underpayment of royalties. The lawsuit includes other UTPCPL claims and antitrust claims, including that a joint exploration agreement to which we are a party established unlawful market allocation for the acquisition of leases. The lawsuit seeks statutory restitution, civil penalties and costs, as well as a temporary injunction from exploration and drilling activities in Pennsylvania until restitution, penalties and costs have been paid, and a permanent injunction from further violations of the UTPCPL. Putative statewide class actions in Pennsylvania and Ohio and purported class arbitrations in Pennsylvania have been filed on behalf of royalty owners asserting various claims for damages related to alleged underpayment of royalties as a result of the divestiture of substantially all of our midstream business and most of our gathering assets in 2012 and 2013. These cases include claims for violation of and conspiracy to violate the federal Racketeer Influenced and Corrupt Organizations Act and for an unlawful market allocation agreement for mineral rights, intentional interference with contractual relations, and violations of antitrust laws related to purported markets for gas mineral rights, operating rights and gas gathering sources. These lawsuits seek in aggregate compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our royalty payment practices, pre-and post-judgment interest, and attorney’s fees and costs. On December 20, 2017 and August 9, 2018, we reached tentative settlements to resolve substantially all Pennsylvania civil royalty cases for a total of approximately $35 million . We believe losses are reasonably possible in certain of the pending royalty cases for which we have not accrued a loss contingency, but we are currently unable to estimate an amount or range of loss or the impact the actions could have on our future results of operations or cash flows. Uncertainties in pending royalty cases generally include the complex nature of the claims and defenses, the potential size of the class in class actions, the scope and types of the properties and agreements involved, and the applicable production years. We also previously disclosed defending lawsuits alleging various violations of the Sherman Antitrust Act and state antitrust laws. In 2016, an individual lawsuit was filed in the U.S. District Court of Kansas against us and other defendants. The lawsuit generally alleged that, from 2007 and continuing through April 2013, the defendants conspired to rig bids and depress the market for the purchases of oil and natural gas leasehold interests and properties in the Anadarko Basin containing producing oil and natural gas wells. The lawsuit sought damages, attorney’s fees, costs and interest, as well as enjoinment from adopting practices or plans that would restrain competition in a similar manner as alleged in the lawsuit. This matter was resolved in connection with the resolution of the related Oklahoma cases for an insignificant amount of money. On July 24, 2018, Healthcare of Ontario Pension Plan (HOOPP) filed a demand for arbitration with the American Arbitration Association regarding HOOPP’s purchase of our interest in Chaparral Energy, Inc. stock for $215 million on January 5, 2014. HOOPP claims that we engaged in material misrepresentations and fraud, and that we violated the Securities Exchange Act of 1934 (the “Exchange Act”) and Oklahoma Uniform Securities Act. HOOPP seeks either rescission or $215 million in monetary damages, and in either case, interest, attorney’s fees, disgorgement and punitive damages. We intend to vigorously defend these claims. In January 2019, putative class action lawsuits were filed in U.S. District Courts for the Southern District of New York against WildHorse and other defendants. The lawsuits generally alleged various violations of the Exchange Act in connection with the disclosure contained in the joint proxy statement/prospectus filed in connection with the Merger. The lawsuits sought rescission of the Merger or rescissory damages and, in each case, attorney's fees, costs and interest. The lawsuits were voluntarily dismissed by the plaintiffs on July 10, 2019. In February 2019, a putative class action lawsuit was filed in the District Court of Dallas County, Texas against FTS International, Inc. (FTSI), certain investment banks, FTSI’s directors including certain of our officers and certain shareholders of FTSI including us. The lawsuit alleges various violations of Sections 11 (with respect to certain of our officers in their capacities as directors of FTSI) and 15 (with respect to such officers and us) of the Securities Act of 1933 in connection with public disclosure made during the initial public offering of FTSI. The suit seeks damages in excess of $1,000,000 and attorneys’ fees and other expenses. We intend to vigorously defend these claims. Environmental Contingencies The nature of the oil and gas business carries with it certain environmental risks for us and our subsidiaries. We have implemented various policies, programs, procedures, training and audits to reduce and mitigate such environmental risks. We conduct periodic reviews, on a company-wide basis, to assess changes in our environmental risk profile. Environmental reserves are established for environmental liabilities for which economic losses are probable and reasonably estimable. We manage our exposure to environmental liabilities in acquisitions by using an evaluation process that seeks to identify pre-existing contamination or compliance concerns and address the potential liability. Depending on the extent of an identified environmental concern, we may, among other things, exclude a property from the transaction, require the seller to remediate the property to our satisfaction in an acquisition or agree to assume liability for the remediation of the property. We are named as a defendant in numerous lawsuits in Oklahoma alleging that we and other companies have engaged in activities that have caused earthquakes. These lawsuits seek compensation for injury to real and personal property, diminution of property value, economic losses due to business interruption, interference with the use and enjoyment of property, annoyance and inconvenience, personal injury and emotional distress. In addition, they seek the reimbursement of insurance premiums and the award of punitive damages, attorneys’ fees, costs, expenses and interest. We intend to vigorously defend these claims. Other Matters Based on management’s current assessment, we are of the opinion that no pending or threatened lawsuit or dispute relating to our business operations is likely to have a material adverse effect on our future consolidated financial position, results of operations or cash flows. The final resolution of such matters could exceed amounts accrued, however, and actual results could differ materially from management’s estimates. Commitments Gathering, Processing and Transportation Agreements We have contractual commitments with midstream service companies and pipeline carriers for future gathering, processing and transportation of oil, natural gas and NGL to move certain of our production to market. Working interest owners and royalty interest owners, where appropriate, will be responsible for their proportionate share of these costs. Commitments related to gathering, processing and transportation agreements are not recorded as obligations in the accompanying condensed consolidated balance sheets; however, they are reflected in our estimates of proved reserves. The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: June 30, ($ in millions) Remainder of 2019 $ 415 2020 789 2021 691 2022 590 2023 477 2024 – 2035 2,451 Total $ 5,413 In addition, we have entered into long-term agreements for certain natural gas gathering and related services within specified acreage dedication areas in exchange for cost-of-service based fees redetermined annually, or tiered fees based on volumes delivered relative to scheduled volumes. Future gathering fees may vary with the applicable agreement.

Other Liabilities

Other Liabilities	6 Months Ended
	Jun. 30, 2019
Other Liabilities Disclosure [Abstract]
Other Liabilities	Other Liabilities Other current liabilities as of June 30, 2019 and December 31, 2018 are detailed below: June 30, December 31, ($ in millions) Revenues and royalties due others $ 434 $ 687 Accrued drilling and production costs 441 258 Joint interest prepayments received 60 73 VPP deferred revenue (a) 57 59 Accrued compensation and benefits 133 202 Other accrued taxes 126 108 Other 179 212 Total other current liabilities $ 1,430 $ 1,599 Other long-term liabilities as of June 30, 2019 and December 31, 2018 are detailed below: June 30, December 31, ($ in millions) VPP deferred revenue (a) $ 36 $ 63 Unrecognized tax benefits 54 53 Other 115 103 Total other long-term liabilities $ 205 $ 219 ____________________________________________ (a) At the inception of our volumetric production payment (VPP) agreements, we (i) removed the proved reserves associated with the VPP, (ii) recognized VPP proceeds as deferred revenue which are being amortized on a unit-of-production basis to other revenue over the term of the VPP, (iii) retained responsibility for the production costs and capital costs related to VPP interests and (iv) ceased recognizing production associated with the VPP volumes. The remaining deferred revenue balance will be recognized in other revenues in the consolidated statement of operations through 2021, assuming the related VPP production volumes are delivered as scheduled.

Leases

Leases	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Leases	Leases We are a lessee under various agreements for compressors, office space, vehicles and other equipment. As of June 30, 2019, these leases have remaining terms ranging from one month to 7.5 years . Certain of our lease agreements include options to renew the lease, terminate the lease early or purchase the underlying asset at the end of the lease. We determine the lease term at the lease commencement date as the non-cancelable period of the lease, including options to extend or terminate the lease when we are reasonably certain to exercise the option. The company’s vehicles are the only leases with renewal options that we are reasonably certain to exercise. The renewals are reflected in the ROU asset and lease liability balances. Upon adoption of ASC 842 on January 1, 2019, we recognized a nominal operating lease liability and a nominal related ROU asset related to vehicles we lease. On February 1, 2019, we acquired WildHorse and, as part of the purchase price allocation, we recognized additional operating lease liabilities of $40 million , a related ROU asset of $38 million , and lease incentives of $2 million related to two office space leases, a long-term hydraulic fracturing agreement and other equipment leases. Regarding our long-term hydraulic fracturing agreements, we made a policy election to treat both lease and non-lease components as a single lease component. In 2018, we sold our wholly owned subsidiary, Midcon Compression, L.L.C., to a third party and subsequently leased back some natural gas compressors for 38 months . The lease is accounted for as a finance lease liability. The following table presents our ROU assets and lease liabilities as of June 30, 2019. Financing Operating ($ in millions) ROU assets $ 22 $ 25 Lease liabilities: Current lease liabilities $ 9 $ 12 Long-term lease liabilities 13 15 Total lease liabilities $ 22 $ 27 Additional information for the Company’s operating and finance leases is presented below: Three Months Ended June 30, 2019 Six Months Ended Lease cost: ($ in millions) Amortization of ROU assets $ 2 $ 4 Interest on lease liability — 1 Finance lease cost 2 5 Operating lease cost 10 17 Short-term lease cost 26 48 Total lease cost (a) $ 38 $ 70 Other information: Operating cash outflows from finance lease $ — $ 1 Operating cash outflows from operating leases $ 3 $ 5 Investing cash outflows from operating leases $ 33 $ 60 Financing cash outflows from finance lease $ 2 $ 4 Weighted-average remaining lease term - finance lease 2.50 years Weighted-average remaining lease term - operating leases 4.50 years Weighted-average discount rate - finance lease 7.50 % Weighted-average discount rate - operating leases 4.83 % ____________________________________________ (a) Includes $33 million and $60 million of capitalized lease costs for the Current Quarter and the Current Period, respectively. Maturity analysis of finance lease liabilities and operating lease liabilities are presented below: June 30, 2019 Financing Lease Operating Leases ($ in millions) Remainder of 2019 $ 5 $ 8 2020 10 8 2021 10 3 2022 — 2 2023 — 2 Thereafter — 7 Total lease payments 25 30 Less imputed interest (3 ) (3 ) Present value of lease liabilities 22 27 Less current maturities (9 ) (12 ) Present value of lease liabilities, less current maturities $ 13 $ 15 The aggregate undiscounted minimum future lease payments under previous lease accounting standard, ASC 840, are presented below: December 31, 2018 Capital Lease Operating Leases ($ in millions) 2019 $ 10 $ 3 2020 10 1 2021 10 — Total minimum lease payments $ 30 $ 4
Leases	Leases We are a lessee under various agreements for compressors, office space, vehicles and other equipment. As of June 30, 2019, these leases have remaining terms ranging from one month to 7.5 years . Certain of our lease agreements include options to renew the lease, terminate the lease early or purchase the underlying asset at the end of the lease. We determine the lease term at the lease commencement date as the non-cancelable period of the lease, including options to extend or terminate the lease when we are reasonably certain to exercise the option. The company’s vehicles are the only leases with renewal options that we are reasonably certain to exercise. The renewals are reflected in the ROU asset and lease liability balances. Upon adoption of ASC 842 on January 1, 2019, we recognized a nominal operating lease liability and a nominal related ROU asset related to vehicles we lease. On February 1, 2019, we acquired WildHorse and, as part of the purchase price allocation, we recognized additional operating lease liabilities of $40 million , a related ROU asset of $38 million , and lease incentives of $2 million related to two office space leases, a long-term hydraulic fracturing agreement and other equipment leases. Regarding our long-term hydraulic fracturing agreements, we made a policy election to treat both lease and non-lease components as a single lease component. In 2018, we sold our wholly owned subsidiary, Midcon Compression, L.L.C., to a third party and subsequently leased back some natural gas compressors for 38 months . The lease is accounted for as a finance lease liability. The following table presents our ROU assets and lease liabilities as of June 30, 2019. Financing Operating ($ in millions) ROU assets $ 22 $ 25 Lease liabilities: Current lease liabilities $ 9 $ 12 Long-term lease liabilities 13 15 Total lease liabilities $ 22 $ 27 Additional information for the Company’s operating and finance leases is presented below: Three Months Ended June 30, 2019 Six Months Ended Lease cost: ($ in millions) Amortization of ROU assets $ 2 $ 4 Interest on lease liability — 1 Finance lease cost 2 5 Operating lease cost 10 17 Short-term lease cost 26 48 Total lease cost (a) $ 38 $ 70 Other information: Operating cash outflows from finance lease $ — $ 1 Operating cash outflows from operating leases $ 3 $ 5 Investing cash outflows from operating leases $ 33 $ 60 Financing cash outflows from finance lease $ 2 $ 4 Weighted-average remaining lease term - finance lease 2.50 years Weighted-average remaining lease term - operating leases 4.50 years Weighted-average discount rate - finance lease 7.50 % Weighted-average discount rate - operating leases 4.83 % ____________________________________________ (a) Includes $33 million and $60 million of capitalized lease costs for the Current Quarter and the Current Period, respectively. Maturity analysis of finance lease liabilities and operating lease liabilities are presented below: June 30, 2019 Financing Lease Operating Leases ($ in millions) Remainder of 2019 $ 5 $ 8 2020 10 8 2021 10 3 2022 — 2 2023 — 2 Thereafter — 7 Total lease payments 25 30 Less imputed interest (3 ) (3 ) Present value of lease liabilities 22 27 Less current maturities (9 ) (12 ) Present value of lease liabilities, less current maturities $ 13 $ 15 The aggregate undiscounted minimum future lease payments under previous lease accounting standard, ASC 840, are presented below: December 31, 2018 Capital Lease Operating Leases ($ in millions) 2019 $ 10 $ 3 2020 10 1 2021 10 — Total minimum lease payments $ 30 $ 4

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The FASB issued Revenue from Contracts with Customers (Topic 606) superseding virtually all existing revenue recognition guidance. We adopted this new standard in the Prior Period using the modified retrospective approach. We applied the new standard to all contracts that were not completed as of January 1, 2018 and reflected the aggregate effect of all modifications in determining and allocating the transaction price. The cumulative effect of adoption of $8 million in the Prior Period did not have a material impact on our consolidated financial statements. The following table shows revenue disaggregated by operating area and product type, for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended June 30, 2019 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 198 $ — $ 198 Haynesville — 164 — 164 Eagle Ford 349 37 20 406 Brazos Valley 199 9 5 213 Powder River Basin 102 18 8 128 Mid-Continent 50 10 10 70 Revenue from contracts with customers 700 436 43 1,179 Gains on oil, natural gas and NGL derivatives 86 189 — 275 Oil, natural gas and NGL revenue $ 786 $ 625 $ 43 $ 1,454 Marketing revenue from contracts with customers $ 614 $ 162 $ 48 $ 824 Other marketing revenue 78 15 — 93 Losses on oil, natural gas and NGL derivatives — (1 ) — (1 ) Marketing revenue $ 692 $ 176 $ 48 $ 916 Three Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 169 $ — $ 169 Haynesville 1 198 — 199 Eagle Ford 390 42 46 478 Powder River Basin 52 11 9 72 Mid-Continent 62 15 12 89 Utica 62 103 61 226 Revenue from contracts with customers 567 538 128 1,233 Losses on oil, natural gas and NGL derivatives (202 ) (35 ) (14 ) (251 ) Oil, natural gas and NGL revenue $ 365 $ 503 $ 114 $ 982 Marketing revenue from contracts with customers 732 235 102 1,069 Other marketing revenue 145 59 — 204 Marketing revenue $ 877 $ 294 $ 102 $ 1,273 Six Months Ended June 30, 2019 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 500 $ — $ 500 Haynesville — 365 — 365 Eagle Ford 680 85 66 831 Brazos Valley 320 13 7 340 Powder River Basin 176 43 18 237 Mid-Continent 90 25 21 136 Revenue from contracts with customers 1,266 1,031 112 2,409 Gains (losses) on oil, natural gas and NGL derivatives (173 ) 147 — (26 ) Oil, natural gas and NGL revenue $ 1,093 $ 1,178 $ 112 $ 2,383 Marketing revenue from contracts with customers $ 1,227 $ 575 $ 165 $ 1,967 Other marketing revenue 150 35 — 185 Losses on oil, natural gas and NGL derivatives — (3 ) — (3 ) Marketing revenue $ 1,377 $ 607 $ 165 $ 2,149 Six Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 462 $ — $ 462 Haynesville 2 409 — 411 Eagle Ford 750 84 85 919 Powder River Basin 95 23 17 135 Mid-Continent 138 47 30 215 Utica 119 219 113 451 Revenue from contracts with customers 1,104 1,244 245 2,593 Losses on oil, natural gas and NGL derivatives (288 ) (67 ) (13 ) (368 ) Oil, natural gas and NGL revenue $ 816 $ 1,177 $ 232 $ 2,225 Marketing revenue from contracts with customers 1,418 528 212 2,158 Other marketing revenue 262 99 — 361 Marketing revenue $ 1,680 $ 627 $ 212 $ 2,519 Accounts Receivable Our accounts receivable are primarily from purchasers of oil, natural gas and NGL and from exploration and production companies that own interests in properties we operate. This industry concentration could affect our overall exposure to credit risk, either positively or negatively, because our purchasers and joint working interest owners may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated. We utilize an allowance method in accounting for bad debt based on historical trends in addition to specifically identifying receivables that we believe may be uncollectible. Accounts receivable as of June 30, 2019 and December 31, 2018 are detailed below: June 30, 2019 December 31, 2018 ($ in millions) Oil, natural gas and NGL sales $ 682 $ 976 Joint interest 289 211 Other 71 77 Allowance for doubtful accounts (21 ) (17 ) Total accounts receivable, net $ 1,021 $ 1,247

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We estimate our annual effective tax rate for continuing operations in recording our quarterly income tax provision (or benefit) for the various jurisdictions in which we operate. The tax effects of statutory rate changes, significant unusual or infrequent items, and certain changes in the assessment of the realizability of deferred tax assets are excluded from the determination of our estimated annual effective tax rate as such items are recognized as discrete items in the quarter in which they occur. For the Current Quarter, our estimated annual effective tax rate is 0.0% as a result of maintaining a full valuation allowance against our net deferred tax asset. Taking into account our projected operating results for the subsequent 2019 quarters, we project remaining in a net deferred tax asset position as of December 31, 2019. Based on all available positive and negative evidence, including projections of future taxable income, we believe it is more likely than not that these deferred tax assets will not be realized. A significant piece of objectively verifiable negative evidence evaluated is the cumulative loss incurred over the rolling thirty-six month period ended June 30, 2019. Such evidence limits our ability to consider various forms of subjective positive evidence, such as our projections for future growth and earnings. However, should we return to a level of sustained profitability, consideration will need to be given to projections of future taxable income to determine whether such projections provide an adequate source of taxable income for the realization of our deferred tax assets. A full valuation allowance was recorded against our net deferred tax asset position as of December 31, 2018 and June 30, 2019. On February 1, 2019, we completed the acquisition of WildHorse. For federal income tax purposes, the transaction qualified as a tax-free merger under Section 368 of the Internal Revenue Code of 1986, as amended, (the “Code”) and, as a result, we acquired carryover tax basis in WildHorse’s assets and liabilities. For the first quarter of 2019, we recorded a net deferred tax liability of $314 million as part of the business combination accounting for WildHorse. As a consequence of maintaining a full valuation allowance against our net deferred tax asset position, a partial release of the valuation allowance was recorded as a discrete income tax benefit of $314 million through the condensed consolidated statement of operations for the same quarter. The net deferred tax liability acquired includes deferred tax liabilities on plant, property and equipment and prepaid compensation totaling $401 million , partially offset by deferred tax assets totaling $87 million relating to federal net operating loss carryforwards, a disallowed interest carryforward and certain other less significant deferred tax assets. These carryforwards will be subject to an annual limitation under Section 382 of the Code of approximately $61 million . We determined that no separate valuation allowances were required to be established through business combination accounting against any of the individual deferred tax assets acquired. We are subject to U.S. federal income tax as well as income and capital taxes in various state jurisdictions in which we operate. We recorded no income tax provision for the Current Quarter and an income tax benefit of $314 million for the Current Period. The benefit for the Current Period was a result of the aforementioned discrete item relating to the partial release of the valuation allowance in the amount of $314 million and a nominal amount of state income tax refunds resulting from the filing of amended state income tax returns reporting federal audit adjustments.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2019
Share-based Payment Arrangement [Abstract]
Share-Based Compensation	Share-Based Compensation Our share-based compensation program consists of restricted stock, stock options, performance share units (PSUs) and cash restricted stock units (CRSUs) granted to employees and restricted stock granted to non-employee directors under our long-term incentive plans. The restricted stock and stock options are equity-classified awards and the PSUs and CRSUs are liability-classified awards. Equity-Classified Awards Restricted Stock. We grant restricted stock units to employees and non-employee directors. A summary of the changes in unvested restricted stock during the Current Period is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value Per Share (in thousands) Unvested restricted stock as of January 1, 2019 11,858 $ 4.43 Granted 5,364 $ 2.85 Vested (4,973 ) $ 4.36 Forfeited (1,027 ) $ 3.67 Unvested restricted stock as of June 30, 2019 11,222 $ 3.78 The aggregate intrinsic value of restricted stock that vested during the Current Period was approximately $14 million based on the stock price at the time of vesting. As of June 30, 2019 , there was approximately $30 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 2.01 years. Stock Options. In the Current Period and the Prior Period, we granted members of management stock options that vest ratably over a three -year period. Each stock option award has an exercise price equal to the closing price of our common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant. We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on the average historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account our dividend policy, over the expected life of the option. We used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period: Expected option life – years 6.0 Volatility 65.61 % Risk-free interest rate 2.47 % Dividend yield — % The following table provides information related to stock option activity in the Current Period: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2019 18,096 $ 7.20 7.15 $ — Granted 1,000 $ 2.97 Exercised — $ — $ — Expired (451 ) $ 6.57 Forfeited (554 ) $ 3.82 Outstanding as of June 30, 2019 18,091 $ 7.09 6.39 $ — Exercisable as of June 30, 2019 13,030 $ 8.29 5.59 $ — ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option. As of June 30, 2019 , there was $9 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 1.39 years , net of actual forfeitures. Restricted Stock and Stock Option Compensation. We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) General and administrative expenses $ 9 $ 10 $ 15 $ 17 Oil and natural gas properties — — 1 2 Oil, natural gas and NGL production expenses 1 1 2 3 Exploration expenses — — — — Total restricted stock and stock option compensation $ 10 $ 11 $ 18 $ 22 Liability-Classified Awards Performance Share Units. In the Current Period and the Prior Period, we granted PSUs to senior management that vest ratably over a three -year performance period and are settled in cash. The ultimate amount earned is based on achievement of performance metrics established by the Compensation Committee of the Board of Directors. Compensation expense associated with PSU awards is recognized over the service period based on the graded-vesting method. The value of the PSU awards at the end of each reporting period is dependent upon our estimates of the underlying performance measures. For PSUs granted in 2017, performance metrics include a total shareholder return (TSR) component, which can range from 0% to 100% and an operational performance component based on finding and development costs, which can range from 0% to 100% , resulting in a maximum payout of 200% . The payout percentage for the 2017 PSU awards is capped at 100% if our absolute TSR is less than zero . The PSUs are settled in cash on the third anniversary of the awards. We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value and the reporting date fair value of the 2017 awards. Grant Date Assumptions Assumption 2017 Awards Volatility 80.65 % Risk-free interest rate 1.54 % Dividend yield for value of awards — % Reporting Period Assumptions Assumption 2017 Awards Volatility 63.49 % Risk-free interest rate 2.08 % Dividend yield for value of awards — % As the above assumptions and expected satisfaction of performance metrics change, the PSU liabilities will be adjusted quarterly through the end of the performance period. For PSUs granted in 2018 and 2019, performance metrics include an operational performance component based on a ratio of cumulative earnings before interest expense, income taxes, and depreciation, depletion and amortization expense (EBITDA) to capital expenditures, for which payout can range from 0% to 200% . For the 2019 award, EBITDA and capital expenditures will be adjusted for changes resulting from our conversion from the full cost method of accounting to the successful efforts method. The vested PSUs are settled in cash on each of the three annual vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the PSUs. The PSU liability will be adjusted quarterly, based on changes in our stock price and expected satisfaction of performance metrics, through the end of the performance period. Cash Restricted Stock Units . In 2018, we granted CRSUs to employees that vest straight-line over a three -year period and are settled in cash on each of the three annual vesting dates. The ultimate amount earned is based on the closing price of our common stock on each of the vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the CRSUs. The CRSU liability will be adjusted quarterly, based on changes in our stock price, through the end of the vesting period. The following table presents a summary of our liability-classified awards: Grant Date Fair Value June 30, 2019 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2019 PSU Awards: Payable 2020, 2021 and 2022 4,887,868 $ 15 $ 12 $ — 2018 PSU Awards: Payable 2020 and 2021 2,418,281 $ 7 $ 5 $ — 2017 PSU Awards: Payable 2020 1,174,973 $ 8 $ 2 $ 1 2018 CRSU Awards: Payable 2020 and 2021 9,468,697 $ 29 $ 18 $ — We recognized the following compensation costs, net of actual forfeitures, related to our liability-classified awards for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) General and administrative expenses $ (1 ) $ 20 $ 8 $ 21 Oil and natural gas properties — 1 1 1 Oil, natural gas and NGL production expenses 1 2 3 2 Exploration expenses (1 ) 1 — 1 Total liability-classified awards compensation $ (1 ) $ 24 $ 12 $ 25

Derivative and Hedging Activiti

Derivative and Hedging Activities	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Hedging Activities	Derivative and Hedging Activities We use derivative instruments to reduce our exposure to fluctuations in future commodity prices and to protect our expected operating cash flow against significant market movements or volatility. All of our oil, natural gas and NGL derivative instruments are net settled based on the difference between the fixed-price payment and the floating-price payment, resulting in a net amount due to or from the counterparty. None of our open oil, natural gas or NGL derivative instruments were designated for hedge accounting as of June 30, 2019 or December 31, 2018. Oil, Natural Gas and NGL Derivatives As of June 30, 2019 and December 31, 2018, our oil, natural gas and NGL derivative instruments consisted of the following types of instruments: • Swaps : We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions. • Options : We occasionally sell and buy call and put options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. At the time of settlement, if the market price is lower than the fixed price of the put option, we receive the difference on bought put options and pay the counterparty the difference on sold put options. If the market price settles below the fixed price of the call option or above the fixed price of the put option, no payment is due from either party. • Call Swaptions : We sell call swaptions to counterparties in exchange for a premium that allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap. • Collars : These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price. • Basis Protection Swaps : These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity. The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of June 30, 2019 and December 31, 2018 are provided below: June 30, 2019 December 31, 2018 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 24 $ 64 12 $ 157 Collars 5 27 8 98 Call swaptions 2 (5 ) — — Put options 2 (5 ) — — Basis protection swaps 4 6 7 5 Total oil 37 87 27 260 Natural gas (bcf): Fixed-price swaps 505 176 623 26 Three-way collars 15 2 88 1 Collars 18 7 55 (3 ) Call options 33 — 44 — Call swaptions 106 (10 ) 106 (9 ) Basis protection swaps 20 — 50 — Total natural gas 697 175 966 15 Contingent consideration: Utica divestiture — 7 Total estimated fair value $ 262 $ 282 We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. See further discussion below under Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) . Contingent Consideration Arrangements In 2018, we sold our Utica Shale position to EAP Ohio, LLC (“Encino”). The purchase and sale agreement with Encino provides for additional contingent payments to us of up to $100 million comprised of $50 million in consideration in each case if, on or prior to December 31, 2019, there is a period of twenty ( 20 ) trading days out of a period of thirty ( 30 ) consecutive trading days where (i) the average of the NYMEX natural gas strip prices for the months comprising the year 2022 equals or exceeds $3.00 /mmbtu as calculated pursuant to the purchase agreement, and (ii) the average of the NYMEX natural gas strip price for the months comprising the year 2023 equals or exceeds $3.25 /mmbtu as calculated pursuant to the purchase and sale agreement. In the Current Quarter, based on the unlikelihood of any payout occurring related to the contingent consideration, we determined the contingent consideration had no fair value and recognized a $7 million unrealized loss, which is included as a reduction in our gains on sales of assets in the condensed consolidated statement of operations. Effect of Derivative Instruments – Condensed Consolidated Balance Sheets The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2019 and December 31, 2018 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of June 30, 2019 Commodity Contracts: Short-term derivative asset $ 250 $ (26 ) $ 224 Long-term derivative asset 64 (1 ) 63 Short-term derivative liability (48 ) 26 (22 ) Long-term derivative liability (4 ) 1 (3 ) Contingent Consideration: Short-term derivative asset — — — Total derivatives $ 262 $ — $ 262 As of December 31, 2018 Commodity Contracts: Short-term derivative asset $ 306 $ (104 ) $ 202 Long-term derivative asset 117 (41 ) 76 Short-term derivative liability (107 ) 104 (3 ) Long-term derivative liability (41 ) 41 — Contingent Consideration: Short-term derivative asset 7 — 7 Total derivatives $ 282 $ — $ 282 Effect of Derivative Instruments – Condensed Consolidated Statements of Operations The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) Oil, natural gas and NGL revenues $ 1,179 $ 1,233 $ 2,409 $ 2,593 Gains (losses) on undesignated oil, natural gas and NGL derivatives 283 (244 ) (8 ) (351 ) Losses on terminated cash flow hedges (8 ) (7 ) (18 ) (17 ) Total oil, natural gas and NGL revenues $ 1,454 $ 982 $ 2,383 $ 2,225 The components of marketing revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) Marketing revenues $ 917 $ 1,273 $ 2,152 $ 2,519 Losses on undesignated marketing natural gas derivatives (1 ) — (3 ) — Total marketing revenues $ 916 $ 1,273 $ 2,149 $ 2,519 Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below: Three Months Ended June 30, 2019 2018 Before After Before After ($ in millions) Balance, beginning of period $ (70 ) $ (13 ) $ (104 ) (47 ) Losses reclassified to income 8 8 7 7 Balance, end of period $ (62 ) $ (5 ) $ (97 ) $ (40 ) Six Months Ended June 30, 2019 2018 Before After Before After ($ in millions) Balance, beginning of period $ (80 ) $ (23 ) $ (114 ) (57 ) Losses reclassified to income 18 18 17 17 Balance, end of period $ (62 ) $ (5 ) $ (97 ) $ (40 ) The accumulated other comprehensive loss as of June 30, 2019 represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. Remaining deferred gain or loss amounts will be recognized in earnings in the month for which the original contract months are to occur. As of June 30, 2019 , we expect to transfer approximately $34 million of net loss included in accumulated other comprehensive income (loss) to net income (loss) during the next 12 months. The remaining amounts will be transferred by December 31, 2022. Credit Risk Considerations Our derivative instruments expose us to our counterparties’ credit risk. To mitigate this risk, we enter into derivative contracts only with counterparties that have a high credit rating or are deemed by us to have acceptable credit strength, and are deemed by management to be competent and competitive market-makers, and we attempt to limit our exposure to non-performance by any single counterparty. As of June 30, 2019 , our oil, natural gas and NGL derivative instruments were spread among 15 counterparties. Hedging Arrangements Certain of our hedging arrangements are with counterparties that are also lenders (or affiliates of lenders) under the Chesapeake revolving credit facility and/or the BVL revolving credit facility. The contracts entered into with these counterparties are secured by the same collateral that secures the revolving credit facilities. In addition, we enter into bilateral hedging agreements with other counterparties. The counterparties’ and our obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts owed to us or by us exceed defined thresholds. As of June 30, 2019 , no letters of credit or cash was posted as collateral for our commodity derivatives. Fair Value The fair value of our derivatives is based on third-party pricing models which utilize inputs that are either readily available in the public market, such as oil, natural gas and NGL forward curves and discount rates, or can be corroborated from active markets or broker quotes. These values are compared to the values given by our counterparties for reasonableness. Since oil, natural gas and NGL swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. All other derivatives have some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivatives are also subject to the risk that either party to a contract will be unable to meet its obligations. We factor non-performance risk into the valuation of our derivatives using current published credit default swap rates. To date, this has not had a material impact on the values of our derivatives. The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Derivative Assets (Liabilities): Commodity assets $ — $ 280 $ 34 $ 314 Commodity liabilities — (40 ) (12 ) (52 ) Utica divestiture contingent consideration — — — — Total derivatives $ — $ 240 $ 22 $ 262 As of December 31, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 319 $ 103 $ 422 Commodity liabilities — (131 ) (16 ) (147 ) Utica divestiture contingent consideration — — 7 7 Total derivatives $ — $ 188 $ 94 $ 282 A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives Utica Contingent Consideration ($ in millions) Balance, as of January 1, 2019 $ 87 $ 7 Total gains (losses) (realized/unrealized): Included in earnings (a) (64 ) (7 ) Total purchases, issuances, sales and settlements: Settlements (1 ) — Balance, as of June 30, 2019 $ 22 $ — Balance, as of January 1, 2018 $ (15 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) — Total purchases, issuances, sales and settlements: Settlements 2 — Balance, as of June 30, 2018 $ (45 ) $ — ___________________________________________ (a) Commodity Derivatives Utica Contingent Consideration 2019 2018 2019 2018 ($ in millions) Total gains (losses) included in earnings for the period $ (64 ) $ (32 ) $ (7 ) $ — Change in unrealized gains (losses) related to assets still held at reporting date $ (66 ) $ (30 ) $ (7 ) $ — Qualitative and Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements The significant unobservable inputs for Level 3 derivative contracts include market volatility. Changes in market volatility impact the fair value measurement of our derivative contracts, which is based on an estimate derived from option models. For example, an increase or decrease in the forward prices and volatility of oil and natural gas prices decreases or increases the fair value of oil and natural gas derivatives. The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of June 30, 2019 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 21.62% – 38.20% 27.79% $ 23 Natural gas trades Natural gas price volatility curves 19.94% – 145.47% 33.18% $ (1 )

Investments

Investments	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Investments	Investments In the Current Period in connection with the acquisition of WildHorse, we obtained a 50% membership interest in JWH Midstream LLC (JWH). The carrying value of our investment in JWH, which was being accounted for as an equity method investment, was approximately $17 million as of March 31, 2019. In the Current Quarter, we paid approximately $7 million to terminate our involvement in the partnership. This removed us from any future obligations related to this joint venture and, therefore, we impaired the full value of the investment and recognized approximately $24 million of impairment expense in the Current Quarter. In the Prior Period, FTS International, Inc. (NYSE: FTSI) completed an initial public offering. Due to the offering, the ownership percentage of our equity method investment in FTSI decreased from approximately 29% to 24% and resulted in a gain of approximately $78 million . In addition, we sold approximately 4.3 million shares of FTSI in the offering for net proceeds of approximately $74 million and recognized a gain of approximately $61 million decreasing our ownership percentage to approximately 20% . We continue to hold approximately 22.0 million shares in the publicly traded company.

Other Operating Expenses

Other Operating Expenses	6 Months Ended
	Jun. 30, 2019
Other Income and Expenses [Abstract]
Other Operating Expenses	Other Operating Expenses In the Current Period, we recorded approximately $26 million of costs related to our acquisition of WildHorse which consisted of financial advisory fees, legal fees and travel and lodging expenses. In addition, we recorded approximately $38 million of severance expense as a result of the acquisition of WildHorse. A majority of the WildHorse executives and employees were terminated. These executives and employees were entitled to severance benefits in accordance with existing employment agreements.

Restructuring and Other Termina

Restructuring and Other Termination Costs	6 Months Ended
	Jun. 30, 2019
Restructuring and Related Activities [Abstract]
Restructuring and Other Termination Costs	Restructuring and Other Termination Costs On January 30, 2018, we underwent a reduction in workforce impacting approximately 13% of employees across all functions, primarily on our Oklahoma City campus. In connection with the reduction, we incurred a total charge in the Prior Period of approximately $38 million for one-time termination benefits.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Recurring Fair Value Measurements Other Current Assets. Assets related to our deferred compensation plan are included in other current assets. The fair value of these assets is determined using quoted market prices, as they consist of exchange-traded securities. Other Current Liabilities . Liabilities related to our deferred compensation plan are included in other current liabilities. The fair values of these liabilities are determined using quoted market prices, as the plan consists of exchange-traded mutual funds. Financial Assets (Liabilities) . The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Financial Assets (Liabilities): Other current assets $ 44 $ — $ — $ 44 Other current liabilities (45 ) — — (45 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2018 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 ) See Note 6 for information regarding fair value measurement of our debt instruments. See Note 13 for information regarding fair value measurement of our derivatives.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2019
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information Chesapeake Energy Corporation is a holding company, owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under our outstanding senior notes, convertible senior notes and Chesapeake revolving credit facility listed in Note 6 are fully and unconditionally guaranteed, jointly and severally, by certain of our 100% owned subsidiaries. Our BVL subsidiaries are not guarantors of Chesapeake’s indebtedness and are subject to covenants under the BVL credit agreement and BVL indenture. Subsidiaries with noncontrolling interests, consolidated variable interest entities and certain de minimis subsidiaries are also non-guarantors. The tables below are condensed consolidating financial statements for Chesapeake Energy Corporation (parent) on a stand-alone, unconsolidated basis, and its combined guarantor and combined non-guarantor subsidiaries as of June 30, 2019 and December 31, 2018 and for the three and six months ended June 30, 2019 and 2018. This financial information may not necessarily be indicative of our results of operations, cash flows or financial position had these subsidiaries operated as independent entities. CONDENSED CONSOLIDATING BALANCE SHEET AS OF JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 9 $ 1 $ 2 $ (8 ) $ 4 Other current assets 54 1,229 97 — 1,380 Intercompany receivable, net 6,321 — — (6,321 ) — Total Current Assets 6,384 1,230 99 (6,329 ) 1,384 PROPERTY AND EQUIPMENT: Oil and natural gas properties, at cost based on successful efforts accounting, net — 9,556 4,132 — 13,688 Other property and equipment, net — 1,061 84 — 1,145 Property and equipment held for sale, net — 12 — — 12 Total Property and Equipment, Net — 10,629 4,216 — 14,845 LONG-TERM ASSETS: Other long-term assets 327 247 24 (287 ) 311 Investments in subsidiaries and intercompany advances 5,982 2,338 — (8,320 ) — TOTAL ASSETS $ 12,693 $ 14,444 $ 4,339 $ (14,936 ) $ 16,540 CURRENT LIABILITIES: Current liabilities $ 137 $ 1,841 $ 250 $ (8 ) $ 2,220 Intercompany payable, net — 6,321 — (6,321 ) — Total Current Liabilities 137 8,162 250 (6,329 ) 2,220 LONG-TERM LIABILITIES: Long-term debt, net 8,311 — 1,390 — 9,701 Other long-term liabilities 54 300 322 (287 ) 389 Total Long-Term Liabilities 8,365 300 1,712 (287 ) 10,090 EQUITY: Chesapeake stockholders’ equity 4,191 5,982 2,338 (8,320 ) 4,191 Noncontrolling interests — — 39 — 39 Total Equity 4,191 5,982 2,377 (8,320 ) 4,230 TOTAL LIABILITIES AND EQUITY $ 12,693 $ 14,444 $ 4,339 $ (14,936 ) $ 16,540 CONDENSED CONSOLIDATING BALANCE SHEET AS OF DECEMBER 31, 2018 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 4 $ 1 $ 1 $ (2 ) $ 4 Other current assets 60 1,532 2 — 1,594 Intercompany receivable, net 6,671 — — (6,671 ) — Total Current Assets 6,735 1,533 3 (6,673 ) 1,598 PROPERTY AND EQUIPMENT: Oil and natural gas properties, at cost based on successful efforts accounting, net — 9,664 48 — 9,712 Other property and equipment, net — 1,091 — — 1,091 Property and equipment held for sale, net — 15 — — 15 Total Property and Equipment, Net — 10,770 48 — 10,818 LONG-TERM ASSETS: Other long-term assets 26 293 — — 319 Investments in subsidiaries and intercompany advances 3,248 9 — (3,257 ) — TOTAL ASSETS $ 10,009 $ 12,605 $ 51 $ (9,930 ) $ 12,735 CURRENT LIABILITIES: Current liabilities $ 523 $ 2,365 $ 1 $ (2 ) $ 2,887 Intercompany payable, net — 6,671 — (6,671 ) — Total Current Liabilities 523 9,036 1 (6,673 ) 2,887 LONG-TERM LIABILITIES: Long-term debt, net 7,341 — — — 7,341 Other long-term liabilities 53 321 — — 374 Total Long-Term Liabilities 7,394 321 — — 7,715 EQUITY: Chesapeake stockholders’ equity 2,092 3,248 9 (3,257 ) 2,092 Noncontrolling interests — — 41 — 41 Total Equity 2,092 3,248 50 (3,257 ) 2,133 TOTAL LIABILITIES AND EQUITY $ 10,009 $ 12,605 $ 51 $ (9,930 ) $ 12,735 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 1,218 $ 236 $ — $ 1,454 Marketing — 916 — — 916 Total Revenues — 2,134 236 — 2,370 Other — 15 — — 15 Gains on sales of assets — 1 — — 1 Total Revenues and Other — 2,150 236 — 2,386 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 28 — 166 Oil, natural gas and NGL gathering, processing and transportation — 265 6 — 271 Production taxes — 30 10 — 40 Exploration — 16 (1 ) — 15 Marketing — 940 — — 940 General and administrative — 65 24 — 89 Provision for legal contingencies, net — 3 — — 3 Depreciation, depletion and amortization — 439 141 — 580 Impairments — 1 — — 1 Other operating expense — 3 — — 3 Total Operating Expenses — 1,900 208 — 2,108 INCOME FROM OPERATIONS — 250 28 — 278 OTHER INCOME (EXPENSE): Interest income (expense) (160 ) 5 (20 ) — (175 ) Losses on investments — — (23 ) — (23 ) Other income — 16 2 — 18 Equity in net earnings of subsidiary 281 10 — (291 ) — Total Other Income (Expense) 121 31 (41 ) (291 ) (180 ) INCOME(LOSS) BEFORE INCOME TAXES 121 281 (13 ) (291 ) 98 INCOME TAX (BENEFIT) EXPENSE 23 — (23 ) — — NET INCOME 98 281 10 (291 ) 98 Net income attributable to noncontrolling interests — — — — — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 98 281 10 (291 ) 98 Other comprehensive income — 8 — — 8 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 98 $ 289 $ 10 $ (291 ) $ 106 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 978 $ 4 $ — $ 982 Marketing — 1,273 — — 1,273 Total Revenues — 2,251 4 — 2,255 Other — 16 — — 16 Gains on sales of assets — 18 — — 18 Total Revenues and Other — 2,285 4 — 2,289 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 — — 138 Oil, natural gas and NGL gathering, processing and transportation — 338 2 — 340 Production taxes — 26 — — 26 Exploration — 20 — — 20 Marketing — 1,292 — — 1,292 General and administrative — 104 1 — 105 Provision for legal contingencies, net — 4 — — 4 Depreciation, depletion and amortization — 470 1 — 471 Impairments — 54 — — 54 Other operating income — (1 ) — — (1 ) Total Operating Expenses — 2,445 4 — 2,449 INCOME FROM OPERATIONS — (160 ) — — (160 ) OTHER INCOME (EXPENSE): Interest expense (155 ) — — — (155 ) Other income — 57 — — 57 Equity in net earnings of subsidiary (103 ) — (1 ) 104 — Total Other Income (Expense) (258 ) 57 (1 ) 104 (98 ) LOSS BEFORE INCOME TAXES (258 ) (103 ) (1 ) 104 (258 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET LOSS (249 ) (103 ) (1 ) 104 (249 ) Net (income) loss attributable to noncontrolling interests — (1 ) 1 — — NET LOSS ATTRIBUTABLE TO CHESAPEAKE (249 ) (104 ) — 104 (249 ) Other comprehensive income — 7 — — 7 COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (249 ) $ (97 ) $ — $ 104 $ (242 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,068 $ 315 $ — $ 2,383 Marketing — 2,149 — — 2,149 Total Revenues — 4,217 315 — 4,532 Other — 30 — — 30 Gains on sales of assets — 20 — — 20 Total Revenues and Other — 4,267 315 — 4,582 OPERATING EXPENSES: Oil, natural gas and NGL production — 255 43 — 298 Oil, natural gas and NGL gathering, processing and transportation — 534 11 — 545 Production taxes — 58 16 — 74 Exploration — 36 3 — 39 Marketing — 2,170 — — 2,170 General and administrative — 150 42 — 192 Provision for legal contingencies, net — 3 — — 3 Depreciation, depletion and amortization — 874 225 — 1,099 Impairments — 2 — — 2 Other operating expense — 26 38 — 64 Total Operating Expenses — 4,108 378 — 4,486 INCOME (LOSS) FROM OPERATIONS — 159 (63 ) — 96 OTHER INCOME (EXPENSE): Interest income (expense) (314 ) 10 (32 ) — (336 ) Losses on investments — — (24 ) — (24 ) Other income — 25 2 — 27 Equity in net earnings of subsidiary 104 (90 ) — (14 ) — Total Other Expense (210 ) (55 ) (54 ) (14 ) (333 ) INCOME (LOSS) BEFORE INCOME TAXES (210 ) 104 (117 ) (14 ) (237 ) INCOME TAX BENEFIT (287 ) — (27 ) — (314 ) NET INCOME (LOSS) 77 104 (90 ) (14 ) 77 Net income attributable to noncontrolling interests — — — — — NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE 77 104 (90 ) (14 ) 77 Other comprehensive income — 18 — — 18 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ 77 $ 122 $ (90 ) $ (14 ) $ 95 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,216 $ 9 $ — $ 2,225 Marketing — 2,519 — — 2,519 Total Revenues — 4,735 9 — 4,744 Other — 32 — — 32 Gains on sales of assets — 37 — — 37 Total Revenues and Other — 4,804 9 — 4,813 OPERATING EXPENSES: Oil, natural gas and NGL production — 285 — — 285 Oil, natural gas and NGL gathering, processing and transportation — 693 3 — 696 Production taxes — 57 — — 57 Exploration — 101 — — 101 Marketing — 2,560 — — 2,560 General and administrative — 191 1 — 192 Restructuring and other termination costs — 38 — — 38 Provision for legal contingencies, net — 9 — — 9 Depreciation, depletion and amortization — 927 3 — 930 Impairments — 64 — — 64 Other operating income — (1 ) — — (1 ) Total Operating Expenses — 4,924 7 — 4,931 INCOME (LOSS) FROM OPERATIONS — (120 ) 2 — (118 ) OTHER INCOME (EXPENSE): Interest expense (317 ) — — — (317 ) Gains on investments — 139 — — 139 Other income — 56 — — 56 Equity in net earnings of subsidiary 76 1 (1 ) (76 ) — Total Other Income (Expense) (241 ) 196 (1 ) (76 ) (122 ) INCOME (LOSS) BEFORE INCOME TAXES (241 ) 76 1 (76 ) (240 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME (LOSS) (232 ) 76 1 (76 ) (231 ) Net income attributable to noncontrolling interests — (1 ) — — (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE (232 ) 75 1 (76 ) (232 ) Other comprehensive income — 17 — — 17 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ (232 ) $ 92 $ 1 $ (76 ) $ (215 ) CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ — $ 613 $ 242 $ (2 ) $ 853 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (805 ) (265 ) — (1,070 ) Business combination, net — (381 ) 28 — (353 ) Acquisitions of proved and unproved properties — (17 ) — — (17 ) Proceeds from divestitures of proved and unproved properties — 82 — — 82 Additions to other property and equipment — (7 ) (11 ) — (18 ) Other investing activities — 4 — — 4 Net Cash Used In Investing Activities — (1,124 ) (248 ) — (1,372 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,119 — 297 — 6,416 Payments on revolving credit facility borrowings (5,166 ) — (286 ) — (5,452 ) Cash paid to purchase debt (381 ) — — — (381 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (12 ) (4 ) (4 ) 2 (18 ) Intercompany advances, net (515 ) 515 — — — Net Cash Provided By (Used In) Financing Activities (1 ) 511 7 2 519 Net increase (decrease) in cash and cash equivalents (1 ) — 1 — — Cash and cash equivalents, beginning of period 4 1 1 (2 ) 4 Cash and cash equivalents, end of period $ 3 $ 1 $ 2 $ (2 ) $ 4 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 88 $ 866 $ 5 $ (8 ) $ 951 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (928 ) — — (928 ) Acquisitions of proved and unproved properties — (102 ) — — (102 ) Proceeds from divestitures of proved and unproved properties — 384 — — 384 Additions to other property and equipment — (5 ) — — (5 ) Other investing activities — 148 — — 148 Net Cash Used In Investing Activities — (503 ) — — (503 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — — — 6,118 Payments on revolving credit facility borrowings (6,393 ) — — — (6,393 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (2 ) (126 ) (7 ) 6 (129 ) Intercompany advances, net 235 (237 ) 2 — — Net Cash Used In Financing Activities (88 ) (363 ) (5 ) 6 (450 ) Net decrease in cash and cash equivalents — — — (2 ) (2 ) Cash and cash equivalents, beginning of period 5 1 2 (3 ) 5 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (5 ) $ 3

Basis of Presentation and Sum_2

Basis of Presentation and Summary of Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying condensed consolidated financial statements of Chesapeake were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures have been condensed or omitted.
Recast Financial Information for Change in Accounting Principle	Recast Financial Information for Change in Accounting Principle In the first quarter of 2019, we voluntarily changed our method of accounting for oil and natural gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. Although the full cost method of accounting for oil and natural gas exploration and development activities continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the SEC and, because it is more widely used in the industry, we expect the change to improve the comparability of our financial statements to our peers. We also believe the successful efforts method provides a more representational depiction of assets and operating results and provides for our investments in oil and natural gas properties to be assessed for impairment in accordance with Accounting Standards Codification (ASC) Topic 360, Property Plant and Equipment, rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. For detailed information regarding the effects of the change to the successful efforts method, see Note 2 .
Oil and Natural Gas Properties	Oil and Natural Gas Properties We follow the successful efforts method of accounting for our oil and natural gas properties. Under this method, exploration costs, such as exploratory geological and geophysical costs, expiration of unproved leasehold, delay rentals and exploration overhead are expensed as incurred. All costs related to production, general corporate overhead and similar activities are also expensed as incurred. All property acquisition costs and development costs are capitalized when incurred. Exploratory drilling costs are initially capitalized, or suspended, pending the determination of proved reserves. If proved reserves are found, drilling costs remain capitalized and are classified as proved properties. Costs of unsuccessful wells are charged to exploration expense. For exploratory wells that find reserves that cannot be classified as proved when drilling is completed, costs continue to be capitalized as suspended exploratory drilling costs if there have been sufficient reserves found to justify completion as a producing well and sufficient progress is being made in assessing the reserves and the economic and operational viability of the project. If we determine that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed. In some instances, this determination may take longer than one year. We review the status of all suspended exploratory drilling costs quarterly. Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of oil and natural gas, are capitalized. Costs of drilling and equipping successful wells, costs to construct or acquire facilities, and associated asset retirement costs are depreciated using the unit-of-production (UOP) method based on total estimated proved developed oil and gas reserves. Costs of acquiring proved properties, including leasehold acquisition costs transferred from unproved properties, are depleted using the UOP method based on total estimated proved developed and undeveloped reserves. Proceeds from the sales of individual oil and natural gas properties and the capitalized costs of individual properties sold or abandoned are credited and charged, respectively, to accumulated depreciation, depletion and amortization, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recognized until an entire amortization base is sold. However, a gain or loss is recognized from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base. When circumstances indicate that the carrying value of proved oil and gas properties may not be recoverable, we compare unamortized capitalized costs to the expected undiscounted pre-tax future cash flows for the associated assets grouped at the lowest level for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows, based on our estimate of future crude oil and natural gas prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized costs, the capitalized costs are reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820, Fair Value Measurements . If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production volumes, commodity prices, operating costs, and capital investment plans, considering all available information at the date of review. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. We have classified these fair value measurements as Level 3 in the fair value hierarchy.
Capitalized Interest	Capitalized Interest Interest from external borrowings is capitalized on significant investments in major development projects until the asset is ready for service using the weighted average borrowing rate of outstanding borrowings. Capitalized interest is determined by multiplying our weighted average borrowing cost on debt by the average amount of qualifying costs incurred. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying asset.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (“ASC 842”) , which requires lessees to recognize a lease liability and a right-of-use (ROU) asset on the balance sheet for all leases, including operating leases, with terms in excess of 12 months. As the implicit rate of the lease is not always readily determinable, the company uses its incremental borrowing rate to calculate the present value of lease payments based on information available at the commencement date. Operating ROU assets are included in other long-term assets while operating lease liabilities are included in other current and other long-term liabilities on the condensed consolidated balance sheet. Finance ROU assets are reflected in total property and equipment, net, while finance lease liabilities are included in other current and other long-term liabilities on the condensed consolidated balance sheet. ASC 842 does not apply to our leases of mineral rights to explore for or use oil and natural gas resources, including the intangible rights to explore for those natural resources and rights to use the land in which those natural resources are contained. We adopted the new standard on January 1, 2019 and as permitted by ASU 2018-11, Leases (Topic 842): Targeted Improvements , we will not adjust comparative-period financial statements and will continue to apply the guidance in Topic 840, including its disclosure requirements, in the comparative periods presented prior to adoption. No cumulative-effect adjustment to retained earnings was required as a result of the modified retrospective approach. Upon adoption of ASC 842, we made certain elections permitting us to not reassess: (1) whether any expired or existing contracts contained leases (2) the lease classification for any expired or existing leases, and (3) initial direct costs for any existing leases. Upon adoption of ASC 842, we also made an election permitting us to continue applying our current policy for land easements. The adoption of ASC 842 did not result in a material impact on our balance sheet, results of operations or cash flows. Short-term leases will not be recognized on the balance sheet as an asset or a liability, and the related rental expense will be expensed as incurred. We have short-term lease agreements related to most of our drilling rig arrangements and hydraulic fracturing arrangements and some of our compressor rental arrangements. See Note 9 for further information regarding leases.

Change in Accounting Principle

Change in Accounting Principle (Tables)	6 Months Ended
	Jun. 30, 2019
Accounting Changes and Error Corrections [Abstract]
Schedule of changes in accounting principles	Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 1,454 $ — $ 1,454 Marketing 916 — 916 Total Revenues 2,370 — 2,370 Other — 15 15 Gains on sales of assets — 1 1 Total Revenues and Other 2,370 16 2,386 OPERATING EXPENSES: Oil, natural gas and NGL production 166 — 166 Oil, natural gas and NGL gathering, processing and transportation 271 — 271 Production taxes 40 — 40 Exploration — 15 15 Marketing 940 — 940 General and administrative 76 13 89 Provisions for legal contingencies, net 3 — 3 Depreciation, depletion and amortization 419 161 580 Impairments 1 — 1 Gain on sale of oil and natural gas properties (1 ) 1 — Other operating expense 4 (1 ) 3 Total Operating Expenses 1,919 189 2,108 INCOME FROM OPERATIONS 451 (173 ) 278 OTHER INCOME (EXPENSE): Interest expense (131 ) (44 ) (175 ) Losses on investments (23 ) — (23 ) Other income 13 5 18 Total Other Expense (141 ) (39 ) (180 ) INCOME BEFORE INCOME TAXES 310 (212 ) 98 Income tax benefit — — — NET INCOME 310 (212 ) 98 Net income attributable to noncontrolling interests — — — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 310 (212 ) 98 Preferred stock dividends (23 ) — (23 ) Earnings allocated to participating securities (1 ) 1 — NET INCOME AVAILABLE TO COMMON STOCKHOLDERS $ 286 $ (211 ) $ 75 EARNINGS PER COMMON SHARE: Basic $ 0.18 $ (0.13 ) $ 0.05 Diluted $ 0.18 $ (0.13 ) $ 0.05 WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 1,628 — 1,628 Diluted 1,628 — 1,628 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Full Cost Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 982 $ — $ 982 Marketing 1,273 — 1,273 Total Revenues 2,255 — 2,255 Other — 16 16 Gains on sales of assets — 18 18 Total Revenues and Other 2,255 34 2,289 OPERATING EXPENSES: Oil, natural gas and NGL production 138 — 138 Oil, natural gas and NGL gathering, processing and transportation 340 — 340 Production taxes 26 — 26 Exploration — 20 20 Marketing 1,292 — 1,292 General and administrative 91 14 105 Provision for legal contingencies, net 4 — 4 Depreciation, depletion and amortization 290 181 471 Impairments 46 8 54 Other operating income (2 ) 1 (1 ) Total Operating Expenses 2,225 224 2,449 INCOME (LOSS) FROM OPERATIONS 30 (190 ) (160 ) OTHER INCOME (EXPENSE): Interest expense (117 ) (38 ) (155 ) Other income (expense) 62 (5 ) 57 Total Other Expense (55 ) (43 ) (98 ) LOSS BEFORE INCOME TAXES (25 ) (233 ) (258 ) Income tax benefit (9 ) — (9 ) NET LOSS (16 ) (233 ) (249 ) Net income attributable to noncontrolling interests (1 ) 1 — NET LOSS ATTRIBUTABLE TO CHESAPEAKE (17 ) (232 ) (249 ) Preferred stock dividends (23 ) — (23 ) NET LOSS AVAILABLE TO COMMON STOCKHOLDERS $ (40 ) $ (232 ) $ (272 ) LOSS PER COMMON SHARE: Basic $ (0.04 ) $ (0.26 ) $ (0.30 ) Diluted $ (0.04 ) $ (0.26 ) $ (0.30 ) WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 909 — 909 Diluted 909 — 909 Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 2,383 $ — $ 2,383 Marketing 2,149 — 2,149 Total Revenues 4,532 — 4,532 Other — 30 30 Gains on sales of assets — 20 20 Total Revenues and Other 4,532 50 4,582 OPERATING EXPENSES: Oil, natural gas and NGL production 298 — 298 Oil, natural gas and NGL gathering, processing and transportation 545 — 545 Production taxes 74 — 74 Exploration — 39 39 Marketing 2,170 — 2,170 General and administrative 164 28 192 Provision for legal contingencies 3 — 3 Depreciation, depletion and amortization 776 323 1,099 Gain on sale of oil and natural gas properties (10 ) 10 — Impairments 2 — 2 Other operating expense 64 — 64 Total Operating Expenses 4,086 400 4,486 INCOME FROM OPERATIONS 446 (350 ) 96 OTHER INCOME (EXPENSE): Interest expense (266 ) (70 ) (336 ) Losses on investments (24 ) — (24 ) Other income 20 7 27 Total Other Expense (270 ) (63 ) (333 ) INCOME (LOSS) BEFORE INCOME TAXES 176 (413 ) (237 ) Income tax benefit (314 ) — (314 ) NET INCOME 490 (413 ) 77 Net income attributable to noncontrolling interests (1 ) 1 — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 489 (412 ) 77 Preferred stock dividends (46 ) — (46 ) Earnings allocated to participating securities (3 ) 3 — NET INCOME AVAILABLE TO COMMON STOCKHOLDERS $ 440 $ (409 ) $ 31 EARNINGS PER COMMON SHARE: Basic $ 0.29 $ (0.27 ) $ 0.02 Diluted $ 0.29 $ (0.27 ) $ 0.02 WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 1,505 — 1,505 Diluted 1,505 — 1,505 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS Under Full Cost Successful Under Successful Efforts ($ in millions except per share data) REVENUES AND OTHER: Oil, natural gas and NGL $ 2,225 $ — $ 2,225 Marketing 2,519 — 2,519 Total Revenues 4,744 — 4,744 Other — 32 32 Gains on sales of assets — 37 37 Total Revenues and Other 4,744 69 4,813 OPERATING EXPENSES: Oil, natural gas and NGL production 285 — 285 Oil, natural gas and NGL gathering, processing and transportation 696 — 696 Production taxes 57 — 57 Exploration — 101 101 Marketing 2,560 — 2,560 General and administrative 163 29 192 Restructuring and other termination costs 38 — 38 Provision for legal contingencies, net 9 — 9 Depreciation, depletion and amortization 576 354 930 Impairments 46 18 64 Other operating (income) expense 6 (7 ) (1 ) Total Operating Expenses 4,436 495 4,931 INCOME (LOSS) FROM OPERATIONS 308 (426 ) (118 ) OTHER INCOME (EXPENSE): Interest expense (240 ) (77 ) (317 ) Gains on investments 139 — 139 Other income 62 (6 ) 56 Total Other Expense (39 ) (83 ) (122 ) INCOME (LOSS) BEFORE INCOME TAXES 269 (509 ) (240 ) Income tax benefit (9 ) — (9 ) NET INCOME (LOSS) 278 (509 ) (231 ) Net income attributable to noncontrolling interests (2 ) 1 (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE 276 (508 ) (232 ) Preferred stock dividends (46 ) — (46 ) Earnings allocated to participating securities (2 ) 2 — NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS $ 228 $ (506 ) $ (278 ) EARNINGS (LOSS) PER COMMON SHARE: Basic $ 0.25 $ (0.56 ) $ (0.31 ) Diluted $ 0.25 $ (0.56 ) $ (0.31 ) WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions): Basic 908 — 908 Diluted 908 — 908 Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME $ 310 $ (212 ) $ 98 OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 8 — 8 Other Comprehensive Income 8 — 8 COMPREHENSIVE INCOME 318 (212 ) 106 COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS — — — COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 318 $ (212 ) $ 106 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET LOSS $ (16 ) $ (233 ) $ (249 ) OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 7 — 7 Other Comprehensive Income 7 — 7 COMPREHENSIVE LOSS (9 ) (233 ) (242 ) COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (1 ) 1 — COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (10 ) $ (232 ) $ (242 ) Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME (LOSS) $ 490 $ (413 ) $ 77 OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 18 — 18 Other Comprehensive Income 18 — 18 COMPREHENSIVE INCOME 508 (413 ) 95 COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (1 ) 1 — COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 507 $ (412 ) $ 95 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME Successful Under Successful Efforts ($ in millions) NET INCOME (LOSS) $ 278 $ (509 ) $ (231 ) OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX: Unrealized gains on derivative instruments — — — Reclassification of losses on settled derivative instruments 17 — 17 Other Comprehensive Income 17 — 17 COMPREHENSIVE INCOME (LOSS) 295 (509 ) (214 ) COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS (2 ) 1 (1 ) COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ 293 $ (508 ) $ (215 ) Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Under Full Cost Successful Under Successful Efforts ($ in millions) CASH FLOWS FROM OPERATING ACTIVITIES: NET INCOME $ 490 $ (413 ) $ 77 ADJUSTMENTS TO RECONCILE NET INCOME TO CASH PROVIDED BY OPERATING ACTIVITIES: Depreciation, depletion and amortization 776 323 1,099 Deferred income tax benefit (314 ) — (314 ) Derivative losses, net 30 — 30 Cash receipts on derivative settlements, net 15 — 15 Stock-based compensation 17 — 17 Gains on sales of assets — (20 ) (20 ) Impairments 2 — 2 Exploration — 25 25 Losses on investments 18 — 18 Other 31 10 41 Changes in assets and liabilities (107 ) (30 ) (137 ) Net Cash Provided By Operating Activities 958 (105 ) 853 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs (1,104 ) 34 (1,070 ) Business combination, net (353 ) — (353 ) Acquisitions of proved and unproved properties (88 ) 71 (17 ) Proceeds from divestitures of proved and unproved properties 82 — 82 Additions to other property and equipment (18 ) — (18 ) Proceeds from sales of other property and equipment 4 — 4 Net Cash Used In Investing Activities (1,477 ) 105 (1,372 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,416 — 6,416 Payments on revolving credit facility borrowings (5,452 ) — (5,452 ) Cash paid to purchase debt (381 ) — (381 ) Cash paid for preferred stock dividends (46 ) — (46 ) Distributions to noncontrolling interest owners (2 ) — (2 ) Other (16 ) — (16 ) Net Cash Provided By Financing Activities 519 — 519 Net increase in cash and cash equivalents — — — Cash and cash equivalents, beginning of period 4 — 4 Cash and cash equivalents, end of period $ 4 $ — $ 4 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Under Full Cost Successful Under Successful Efforts ($ in millions) CASH FLOWS FROM OPERATING ACTIVITIES: NET INCOME (LOSS) $ 278 $ (509 ) $ (231 ) ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH PROVIDED BY OPERATING ACTIVITIES: Depreciation, depletion and amortization 576 354 930 Deferred income tax benefit (9 ) — (9 ) Derivative losses, net 368 — 368 Cash payments on derivative settlements, net (55 ) — (55 ) Stock-based compensation 18 — 18 Gains on sales of assets — (37 ) (37 ) Impairments 46 18 64 Exploration — 73 73 Gains on investments (139 ) — (139 ) Other (86 ) (7 ) (93 ) Changes in assets and liabilities 94 (32 ) 62 Net Cash Provided By Operating Activities 1,091 (140 ) 951 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs (979 ) 51 (928 ) Acquisitions of proved and unproved properties (191 ) 89 (102 ) Proceeds from divestitures of proved and unproved properties 384 — 384 Additions to other property and equipment (5 ) — (5 ) Proceeds from sales of other property and equipment 74 — 74 Proceeds from sales of investments 74 — 74 Net Cash Used In Investing Activities (643 ) 140 (503 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — 6,118 Payments on revolving credit facility borrowings (6,393 ) — (6,393 ) Extinguishment of other financing (122 ) — (122 ) Cash paid for preferred stock dividends (46 ) — (46 ) Distributions to noncontrolling interest owners (3 ) — (3 ) Other (4 ) — (4 ) Net Cash Used In Financing Activities (450 ) — (450 ) Net decrease in cash and cash equivalents (2 ) — (2 ) Cash and cash equivalents, beginning of period 5 — 5 Cash and cash equivalents, end of period $ 3 $ — $ 3 Three Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning and end of period 16 — 16 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 16,392 — 16,392 Stock-based compensation 11 — 11 Dividends on preferred stock (23 ) — (23 ) Balance, end of period 16,380 — 16,380 ACCUMULATED DEFICIT: Balance, beginning of period (15,481 ) 1,548 (13,933 ) Net income attributable to Chesapeake 310 (212 ) 98 Balance, end of period (15,171 ) 1,336 (13,835 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (13 ) — (13 ) Hedging activity 8 — 8 Balance, end of period (5 ) — (5 ) TREASURY STOCK – COMMON: Balance, beginning of period (36 ) — (36 ) Purchase of 81,093 shares for company benefit plans (1 ) — (1 ) Release of 148,767 shares from company benefit plans 1 — 1 Balance, end of period (36 ) — (36 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY 2,855 1,336 4,191 NONCONTROLLING INTERESTS: Balance, beginning of period 122 (81 ) 41 Net income attributable to noncontrolling interests — — — Distributions to noncontrolling interest owners (2 ) — (2 ) Balance, end of period 120 (81 ) 39 TOTAL EQUITY $ 2,975 $ 1,255 $ 4,230 Three Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning of period 9 — 9 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,419 — 14,419 Stock-based compensation 12 — 12 Dividends on preferred stock (23 ) — (23 ) Balance, end of period 14,408 — 14,408 ACCUMULATED DEFICIT: Balance, beginning of period (16,240 ) 2,119 (14,121 ) Net loss attributable to Chesapeake (17 ) (232 ) (249 ) Balance, end of period (16,257 ) 1,887 (14,370 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (47 ) — (47 ) Hedging activity 7 — 7 Balance, end of period (40 ) — (40 ) TREASURY STOCK – COMMON: Balance, beginning of period (32 ) — (32 ) Purchase of 17,046 shares for company benefit plans — — — Release of 114,450 shares from company benefit plans 1 — 1 Balance, end of period (31 ) — (31 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY (DEFICIT) (240 ) 1,887 1,647 NONCONTROLLING INTERESTS: Balance, beginning of period 123 (80 ) 43 Net income attributable to noncontrolling interests 1 (1 ) — Distributions to noncontrolling interest owners (1 ) — (1 ) Balance, end of period 123 (81 ) 42 TOTAL EQUITY (DEFICIT) $ (117 ) $ 1,806 $ 1,689 Six Months Ended June 30, 2019 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning of period 9 — 9 Common shares issued for WildHorse Merger 7 — 7 Balance, end of period 16 — 16 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,378 — 14,378 Common shares issued for WildHorse Merger 2,030 — 2,030 Stock-based compensation 18 — 18 Dividends on preferred stock (46 ) — (46 ) Balance, end of period 16,380 — 16,380 ACCUMULATED DEFICIT: Balance, beginning of period (15,660 ) 1,748 (13,912 ) Net income attributable to Chesapeake 489 (412 ) 77 Balance, end of period (15,171 ) 1,336 (13,835 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (23 ) — (23 ) Hedging activity 18 — 18 Balance, end of period (5 ) — (5 ) TREASURY STOCK – COMMON: Balance, beginning of period (31 ) — (31 ) Purchase of 2,620,566 shares for company benefit plans (7 ) — (7 ) Release of 259,563 shares from company benefit plans 2 — 2 Balance, end of period (36 ) — (36 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY 2,855 1,336 4,191 NONCONTROLLING INTERESTS: Balance, beginning of period 123 (82 ) 41 Net income attributable to noncontrolling interests (1 ) 1 — Distributions to noncontrolling interest owners (2 ) — (2 ) Balance, end of period 120 (81 ) 39 TOTAL EQUITY $ 2,975 $ 1,255 $ 4,230 Six Months Ended June 30, 2018 CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY Under Successful Efforts Adjustment Under Successful Efforts ($ in millions) PREFERRED STOCK: Balance, beginning and end of period $ 1,671 $ — $ 1,671 COMMON STOCK: Balance, beginning and end of period 9 — 9 ADDITIONAL PAID-IN CAPITAL: Balance, beginning of period 14,437 — 14,437 Stock-based compensation 17 — 17 Dividends on preferred stock (46 ) — (46 ) Balance, end of period 14,408 — 14,408 ACCUMULATED DEFICIT: Balance, beginning of period (16,525 ) 2,395 (14,130 ) Net income (loss) attributable to Chesapeake 276 (508 ) (232 ) Cumulative effect of accounting change (8 ) — (8 ) Balance, end of period (16,257 ) 1,887 (14,370 ) ACCUMULATED OTHER COMPREHENSIVE LOSS: Balance, beginning of period (57 ) — (57 ) Hedging activity 17 — 17 Balance, end of period (40 ) — (40 ) TREASURY STOCK – COMMON: Balance, beginning of period (31 ) — (31 ) Purchase of 1,468,524 shares for company benefit plans (4 ) — (4 ) Release of 389,857 shares from company benefit plans 4 — 4 Balance, end of period (31 ) — (31 ) TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY (DEFICIT) (240 ) 1,887 1,647 NONCONTROLLING INTERESTS: Balance, beginning of period 124 (80 ) 44 Net income attributable to noncontrolling interests 2 (1 ) 1 Distributions to noncontrolling interest owners (3 ) — (3 ) Balance, end of period 123 (81 ) 42 TOTAL EQUITY (DEFICIT) $ (117 ) $ 1,806 $ 1,689

Oil and Natural Gas Property _2

Oil and Natural Gas Property Transactions (Tables)	6 Months Ended
	Jun. 30, 2019
Business Combinations [Abstract]
Schedule of preliminary allocation of the total purchase price	The following table represents the preliminary allocation of the total purchase price of WildHorse to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date. Certain data necessary to complete the purchase price allocation is not yet available, and includes, but is not limited to, valuation of pre-acquisition contingencies, final tax returns that provide the underlying tax basis of WildHorse’s assets and liabilities and final appraisals of assets acquired and liabilities assumed. We expect to complete the purchase price allocation during the 12-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. Preliminary Purchase Price Allocation ($ in millions) Consideration: Cash $ 381 Fair value of Chesapeake’s common stock issued in the Merger (a) 2,037 Total consideration $ 2,418 Fair Value of Liabilities Assumed: Current liabilities $ 166 Long-term debt 1,379 Deferred tax liabilities 314 Other long-term liabilities 36 Amounts attributable to liabilities assumed $ 1,895 Fair Value of Assets Acquired: Cash and cash equivalents $ 28 Other current assets 128 Proved oil and natural gas properties 3,264 Unproved properties 756 Other property and equipment 77 Other long-term assets 60 Amounts attributable to assets acquired $ 4,313 Total identifiable net assets $ 2,418 ___________________________________________ (a) Based on 717,376,170 Chesapeake common shares issued at closing at $2.84 per share (closing price as of February 1, 2019).
Schedule of pro forma financial information	The following unaudited pro forma financial information for the six months ended June 30, 2019 and three and six months ended 2018, respectively, is based on our historical consolidated financial statements adjusted to reflect as if the WildHorse acquisition had occurred on January 1, 2018. The information below reflects pro forma adjustments based on available information and certain assumptions that we believe are reasonable, including adjustments to conform the classification of expenses in WildHorse’s statements of operations to our classification for similar expenses and the estimated tax impact of pro forma adjustments. Three Months Ended June 30, Six Months Ended June 30, 2018 2019 2018 ($ in millions except per share data) Revenues $ 2,403 $ 4,574 $ 5,085 Net income (loss) available to common stockholders $ (332 ) $ 16 $ (360 ) Earnings per common share: Basic $ (0.20 ) $ 0.01 $ (0.22 ) Diluted $ (0.20 ) $ 0.01 $ (0.22 )

Capitalized Exploratory Well _2

Capitalized Exploratory Well Costs (Tables)	6 Months Ended
	Jun. 30, 2019
Extractive Industries [Abstract]
Summary of changes in capitalized well costs	A summary of the changes in our capitalized well costs for the Current Period is detailed below. Additions pending the determination of proved reserves excludes amounts capitalized and subsequently charged to expense within the same year. 2019 ($ in millions) Balance as of January 1 $ 36 Additions pending the determination of proved reserves 9 Divestitures and other — Reclassifications to proved properties (18 ) Charges to exploration expense — Balance as of June 30 $ 27

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Securities excluded from calculation of diluted EPS	Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive: Three Months Ended Six Months Ended 2019 2018 2019 2018 (in millions) Common stock equivalent of our preferred stock outstanding 60 60 60 60 Common stock equivalent of our convertible senior notes outstanding 146 146 146 146 Participating securities 1 1 1 1

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Schedule of long-term debt	Our long-term debt consisted of the following as of June 30, 2019 and December 31, 2018: June 30, 2019 December 31, 2018 Principal Amount Carrying Principal Carrying ($ in millions) Floating rate senior notes due 2019 — — 380 380 6.625% senior notes due 2020 208 208 437 437 6.875% senior notes due 2020 93 93 227 227 6.125% senior notes due 2021 167 167 548 548 5.375% senior notes due 2021 127 127 267 267 4.875% senior notes due 2022 451 451 451 451 5.75% senior notes due 2023 338 338 338 338 7.00% senior notes due 2024 850 850 850 850 6.875% senior notes due 2025 (a) 700 704 — — 8.00% senior notes due 2025 1,300 1,292 1,300 1,291 5.5% convertible senior notes due 2026 (b) 1,250 882 1,250 866 7.5% senior notes due 2026 400 400 400 400 8.00% senior notes due 2026 919 884 — — 8.00% senior notes due 2027 1,300 1,299 1,300 1,299 2.25% contingent convertible senior notes due 2038 — — 1 1 Chesapeake revolving credit facility 1,372 1,372 419 419 BVL revolving credit facility (a) 686 686 — — Debt issuance costs — (53 ) — (53 ) Interest rate derivatives — 1 — 1 Total debt, net 10,161 9,701 8,168 7,722 Less current maturities of long-term debt, net — — (381 ) (381 ) Total long-term debt, net $ 10,161 $ 9,701 $ 7,787 $ 7,341 ___________________________________________ (a) On February 1, 2019, we acquired the debt of WildHorse which consisted of 6.875% Senior Notes due 2025 and a revolving credit facility. We now refer to this debt as our BVL Senior Notes and our BVL revolving credit facility, respectively. See further discussion below. (b) We are required to account for the liability and equity components of our convertible debt instrument separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rate for our 5.5% Convertible Senior Notes due 2026 is 11.5% . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. During the Current Quarter, the price of our common stock was below the threshold level for conversion and, as a result, the holders do not have the option to convert their notes in the third quarter of 2019.
Schedule of private exchange offer for outstanding senior unsecured notes	In the Current Quarter, we issued at par approximately $919 million of 8.00% Senior Notes due 2026 (“2026 notes”) pursuant to a private exchange offer for the following outstanding senior unsecured notes: Notes Exchanged ($ in millions) 6.625% senior notes due 2020 $ 229 6.875% senior notes due 2020 134 6.125% senior notes due 2021 381 5.375% senior notes due 2021 140 Total $ 884
Schedule of fair value of debt	Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: June 30, 2019 December 31, 2018 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ — $ — $ 381 $ 379 Long-term debt (Level 1) $ 3,321 $ 3,126 $ 3,495 $ 3,173 Long-term debt (Level 2) $ 6,380 $ 6,060 $ 3,846 $ 3,644

Contingencies and Commitments (

Contingencies and Commitments (Tables)	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of contractual obligation	The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: June 30, ($ in millions) Remainder of 2019 $ 415 2020 789 2021 691 2022 590 2023 477 2024 – 2035 2,451 Total $ 5,413

Other Liabilities (Tables)

Other Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
Other Liabilities Disclosure [Abstract]
Other current liabilities	Other current liabilities as of June 30, 2019 and December 31, 2018 are detailed below: June 30, December 31, ($ in millions) Revenues and royalties due others $ 434 $ 687 Accrued drilling and production costs 441 258 Joint interest prepayments received 60 73 VPP deferred revenue (a) 57 59 Accrued compensation and benefits 133 202 Other accrued taxes 126 108 Other 179 212 Total other current liabilities $ 1,430 $ 1,599
Other long-term liabilities	Other long-term liabilities as of June 30, 2019 and December 31, 2018 are detailed below: June 30, December 31, ($ in millions) VPP deferred revenue (a) $ 36 $ 63 Unrecognized tax benefits 54 53 Other 115 103 Total other long-term liabilities $ 205 $ 219 ____________________________________________ (a) At the inception of our volumetric production payment (VPP) agreements, we (i) removed the proved reserves associated with the VPP, (ii) recognized VPP proceeds as deferred revenue which are being amortized on a unit-of-production basis to other revenue over the term of the VPP, (iii) retained responsibility for the production costs and capital costs related to VPP interests and (iv) ceased recognizing production associated with the VPP volumes. The remaining deferred revenue balance will be recognized in other revenues in the consolidated statement of operations through 2021, assuming the related VPP production volumes are delivered as scheduled.

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Schedule of ROU assets and lease liabilities	The following table presents our ROU assets and lease liabilities as of June 30, 2019. Financing Operating ($ in millions) ROU assets $ 22 $ 25 Lease liabilities: Current lease liabilities $ 9 $ 12 Long-term lease liabilities 13 15 Total lease liabilities $ 22 $ 27
Schedule of operating and financing lease additional information	Additional information for the Company’s operating and finance leases is presented below: Three Months Ended June 30, 2019 Six Months Ended Lease cost: ($ in millions) Amortization of ROU assets $ 2 $ 4 Interest on lease liability — 1 Finance lease cost 2 5 Operating lease cost 10 17 Short-term lease cost 26 48 Total lease cost (a) $ 38 $ 70 Other information: Operating cash outflows from finance lease $ — $ 1 Operating cash outflows from operating leases $ 3 $ 5 Investing cash outflows from operating leases $ 33 $ 60 Financing cash outflows from finance lease $ 2 $ 4 Weighted-average remaining lease term - finance lease 2.50 years Weighted-average remaining lease term - operating leases 4.50 years Weighted-average discount rate - finance lease 7.50 % Weighted-average discount rate - operating leases 4.83 % ____________________________________________ (a) Includes $33 million and $60 million of capitalized lease costs for the Current Quarter and the Current Period, respectively.
Schedule of maturity analysis of operating lease liabilities	Maturity analysis of finance lease liabilities and operating lease liabilities are presented below: June 30, 2019 Financing Lease Operating Leases ($ in millions) Remainder of 2019 $ 5 $ 8 2020 10 8 2021 10 3 2022 — 2 2023 — 2 Thereafter — 7 Total lease payments 25 30 Less imputed interest (3 ) (3 ) Present value of lease liabilities 22 27 Less current maturities (9 ) (12 ) Present value of lease liabilities, less current maturities $ 13 $ 15 The aggregate undiscounted minimum future lease payments under previous lease accounting standard, ASC 840, are presented below: December 31, 2018 Capital Lease Operating Leases ($ in millions) 2019 $ 10 $ 3 2020 10 1 2021 10 — Total minimum lease payments $ 30 $ 4
Schedule of maturity analysis of finance lease liabilities	Maturity analysis of finance lease liabilities and operating lease liabilities are presented below: June 30, 2019 Financing Lease Operating Leases ($ in millions) Remainder of 2019 $ 5 $ 8 2020 10 8 2021 10 3 2022 — 2 2023 — 2 Thereafter — 7 Total lease payments 25 30 Less imputed interest (3 ) (3 ) Present value of lease liabilities 22 27 Less current maturities (9 ) (12 ) Present value of lease liabilities, less current maturities $ 13 $ 15 The aggregate undiscounted minimum future lease payments under previous lease accounting standard, ASC 840, are presented below: December 31, 2018 Capital Lease Operating Leases ($ in millions) 2019 $ 10 $ 3 2020 10 1 2021 10 — Total minimum lease payments $ 30 $ 4

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of revenue	The following table shows revenue disaggregated by operating area and product type, for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended June 30, 2019 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 198 $ — $ 198 Haynesville — 164 — 164 Eagle Ford 349 37 20 406 Brazos Valley 199 9 5 213 Powder River Basin 102 18 8 128 Mid-Continent 50 10 10 70 Revenue from contracts with customers 700 436 43 1,179 Gains on oil, natural gas and NGL derivatives 86 189 — 275 Oil, natural gas and NGL revenue $ 786 $ 625 $ 43 $ 1,454 Marketing revenue from contracts with customers $ 614 $ 162 $ 48 $ 824 Other marketing revenue 78 15 — 93 Losses on oil, natural gas and NGL derivatives — (1 ) — (1 ) Marketing revenue $ 692 $ 176 $ 48 $ 916 Three Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 169 $ — $ 169 Haynesville 1 198 — 199 Eagle Ford 390 42 46 478 Powder River Basin 52 11 9 72 Mid-Continent 62 15 12 89 Utica 62 103 61 226 Revenue from contracts with customers 567 538 128 1,233 Losses on oil, natural gas and NGL derivatives (202 ) (35 ) (14 ) (251 ) Oil, natural gas and NGL revenue $ 365 $ 503 $ 114 $ 982 Marketing revenue from contracts with customers 732 235 102 1,069 Other marketing revenue 145 59 — 204 Marketing revenue $ 877 $ 294 $ 102 $ 1,273 Six Months Ended June 30, 2019 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 500 $ — $ 500 Haynesville — 365 — 365 Eagle Ford 680 85 66 831 Brazos Valley 320 13 7 340 Powder River Basin 176 43 18 237 Mid-Continent 90 25 21 136 Revenue from contracts with customers 1,266 1,031 112 2,409 Gains (losses) on oil, natural gas and NGL derivatives (173 ) 147 — (26 ) Oil, natural gas and NGL revenue $ 1,093 $ 1,178 $ 112 $ 2,383 Marketing revenue from contracts with customers $ 1,227 $ 575 $ 165 $ 1,967 Other marketing revenue 150 35 — 185 Losses on oil, natural gas and NGL derivatives — (3 ) — (3 ) Marketing revenue $ 1,377 $ 607 $ 165 $ 2,149 Six Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 462 $ — $ 462 Haynesville 2 409 — 411 Eagle Ford 750 84 85 919 Powder River Basin 95 23 17 135 Mid-Continent 138 47 30 215 Utica 119 219 113 451 Revenue from contracts with customers 1,104 1,244 245 2,593 Losses on oil, natural gas and NGL derivatives (288 ) (67 ) (13 ) (368 ) Oil, natural gas and NGL revenue $ 816 $ 1,177 $ 232 $ 2,225 Marketing revenue from contracts with customers 1,418 528 212 2,158 Other marketing revenue 262 99 — 361 Marketing revenue $ 1,680 $ 627 $ 212 $ 2,519
Accounts receivable	Accounts receivable as of June 30, 2019 and December 31, 2018 are detailed below: June 30, 2019 December 31, 2018 ($ in millions) Oil, natural gas and NGL sales $ 682 $ 976 Joint interest 289 211 Other 71 77 Allowance for doubtful accounts (21 ) (17 ) Total accounts receivable, net $ 1,021 $ 1,247

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2019
Share-based Payment Arrangement [Abstract]
Summary of the changes in unvested restricted stock	A summary of the changes in unvested restricted stock during the Current Period is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value Per Share (in thousands) Unvested restricted stock as of January 1, 2019 11,858 $ 4.43 Granted 5,364 $ 2.85 Vested (4,973 ) $ 4.36 Forfeited (1,027 ) $ 3.67 Unvested restricted stock as of June 30, 2019 11,222 $ 3.78
Weighted average assumptions to estimate grant date fair value of the stock options granted	We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value and the reporting date fair value of the 2017 awards. Grant Date Assumptions Assumption 2017 Awards Volatility 80.65 % Risk-free interest rate 1.54 % Dividend yield for value of awards — % Reporting Period Assumptions Assumption 2017 Awards Volatility 63.49 % Risk-free interest rate 2.08 % Dividend yield for value of awards — % Expected option life – years 6.0 Volatility 65.61 % Risk-free interest rate 2.47 % Dividend yield — %
Schedule of stock option activity	The following table provides information related to stock option activity in the Current Period: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2019 18,096 $ 7.20 7.15 $ — Granted 1,000 $ 2.97 Exercised — $ — $ — Expired (451 ) $ 6.57 Forfeited (554 ) $ 3.82 Outstanding as of June 30, 2019 18,091 $ 7.09 6.39 $ — Exercisable as of June 30, 2019 13,030 $ 8.29 5.59 $ — ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.
Restricted stock and stock option compensation	We recognized the following compensation costs, net of actual forfeitures, related to our liability-classified awards for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) General and administrative expenses $ (1 ) $ 20 $ 8 $ 21 Oil and natural gas properties — 1 1 1 Oil, natural gas and NGL production expenses 1 2 3 2 Exploration expenses (1 ) 1 — 1 Total liability-classified awards compensation $ (1 ) $ 24 $ 12 $ 25 Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) General and administrative expenses $ 9 $ 10 $ 15 $ 17 Oil and natural gas properties — — 1 2 Oil, natural gas and NGL production expenses 1 1 2 3 Exploration expenses — — — — Total restricted stock and stock option compensation $ 10 $ 11 $ 18 $ 22
Summary of liability classified awards	The following table presents a summary of our liability-classified awards: Grant Date Fair Value June 30, 2019 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2019 PSU Awards: Payable 2020, 2021 and 2022 4,887,868 $ 15 $ 12 $ — 2018 PSU Awards: Payable 2020 and 2021 2,418,281 $ 7 $ 5 $ — 2017 PSU Awards: Payable 2020 1,174,973 $ 8 $ 2 $ 1 2018 CRSU Awards: Payable 2020 and 2021 9,468,697 $ 29 $ 18 $ —

Derivative and Hedging Activi_2

Derivative and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of estimated fair values of oil, natural gas and NGL derivative instruments	The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of June 30, 2019 and December 31, 2018 are provided below: June 30, 2019 December 31, 2018 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 24 $ 64 12 $ 157 Collars 5 27 8 98 Call swaptions 2 (5 ) — — Put options 2 (5 ) — — Basis protection swaps 4 6 7 5 Total oil 37 87 27 260 Natural gas (bcf): Fixed-price swaps 505 176 623 26 Three-way collars 15 2 88 1 Collars 18 7 55 (3 ) Call options 33 — 44 — Call swaptions 106 (10 ) 106 (9 ) Basis protection swaps 20 — 50 — Total natural gas 697 175 966 15 Contingent consideration: Utica divestiture — 7 Total estimated fair value $ 262 $ 282
Schedule of effect of derivative instruments, condensed consolidated balance sheets	The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2019 and December 31, 2018 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of June 30, 2019 Commodity Contracts: Short-term derivative asset $ 250 $ (26 ) $ 224 Long-term derivative asset 64 (1 ) 63 Short-term derivative liability (48 ) 26 (22 ) Long-term derivative liability (4 ) 1 (3 ) Contingent Consideration: Short-term derivative asset — — — Total derivatives $ 262 $ — $ 262 As of December 31, 2018 Commodity Contracts: Short-term derivative asset $ 306 $ (104 ) $ 202 Long-term derivative asset 117 (41 ) 76 Short-term derivative liability (107 ) 104 (3 ) Long-term derivative liability (41 ) 41 — Contingent Consideration: Short-term derivative asset 7 — 7 Total derivatives $ 282 $ — $ 282
Schedule of effect of derivative instruments, condensed consolidated statements of operations	The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) Oil, natural gas and NGL revenues $ 1,179 $ 1,233 $ 2,409 $ 2,593 Gains (losses) on undesignated oil, natural gas and NGL derivatives 283 (244 ) (8 ) (351 ) Losses on terminated cash flow hedges (8 ) (7 ) (18 ) (17 ) Total oil, natural gas and NGL revenues $ 1,454 $ 982 $ 2,383 $ 2,225 The components of marketing revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2019 2018 2019 2018 ($ in millions) Marketing revenues $ 917 $ 1,273 $ 2,152 $ 2,519 Losses on undesignated marketing natural gas derivatives (1 ) — (3 ) — Total marketing revenues $ 916 $ 1,273 $ 2,149 $ 2,519
Schedule of effect of derivative instruments, accumulated other comprehensive income (loss)	A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below: Three Months Ended June 30, 2019 2018 Before After Before After ($ in millions) Balance, beginning of period $ (70 ) $ (13 ) $ (104 ) (47 ) Losses reclassified to income 8 8 7 7 Balance, end of period $ (62 ) $ (5 ) $ (97 ) $ (40 ) Six Months Ended June 30, 2019 2018 Before After Before After ($ in millions) Balance, beginning of period $ (80 ) $ (23 ) $ (114 ) (57 ) Losses reclassified to income 18 18 17 17 Balance, end of period $ (62 ) $ (5 ) $ (97 ) $ (40 )
Schedule of financial assets (liabilities)	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Derivative Assets (Liabilities): Commodity assets $ — $ 280 $ 34 $ 314 Commodity liabilities — (40 ) (12 ) (52 ) Utica divestiture contingent consideration — — — — Total derivatives $ — $ 240 $ 22 $ 262 As of December 31, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 319 $ 103 $ 422 Commodity liabilities — (131 ) (16 ) (147 ) Utica divestiture contingent consideration — — 7 7 Total derivatives $ — $ 188 $ 94 $ 282 A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives Utica Contingent Consideration ($ in millions) Balance, as of January 1, 2019 $ 87 $ 7 Total gains (losses) (realized/unrealized): Included in earnings (a) (64 ) (7 ) Total purchases, issuances, sales and settlements: Settlements (1 ) — Balance, as of June 30, 2019 $ 22 $ — Balance, as of January 1, 2018 $ (15 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) — Total purchases, issuances, sales and settlements: Settlements 2 — Balance, as of June 30, 2018 $ (45 ) $ — ___________________________________________ (a) Commodity Derivatives Utica Contingent Consideration 2019 2018 2019 2018 ($ in millions) Total gains (losses) included in earnings for the period $ (64 ) $ (32 ) $ (7 ) $ — Change in unrealized gains (losses) related to assets still held at reporting date $ (66 ) $ (30 ) $ (7 ) $ — June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Financial Assets (Liabilities): Other current assets $ 44 $ — $ — $ 44 Other current liabilities (45 ) — — (45 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2018 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 )
Schedule of quantitative information about level 3 inputs used	The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of June 30, 2019 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 21.62% – 38.20% 27.79% $ 23 Natural gas trades Natural gas price volatility curves 19.94% – 145.47% 33.18% $ (1 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Schedule of fair value measurement of financial assets (liabilities) measured at fair value on a recurring basis	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Derivative Assets (Liabilities): Commodity assets $ — $ 280 $ 34 $ 314 Commodity liabilities — (40 ) (12 ) (52 ) Utica divestiture contingent consideration — — — — Total derivatives $ — $ 240 $ 22 $ 262 As of December 31, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 319 $ 103 $ 422 Commodity liabilities — (131 ) (16 ) (147 ) Utica divestiture contingent consideration — — 7 7 Total derivatives $ — $ 188 $ 94 $ 282 A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives Utica Contingent Consideration ($ in millions) Balance, as of January 1, 2019 $ 87 $ 7 Total gains (losses) (realized/unrealized): Included in earnings (a) (64 ) (7 ) Total purchases, issuances, sales and settlements: Settlements (1 ) — Balance, as of June 30, 2019 $ 22 $ — Balance, as of January 1, 2018 $ (15 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) — Total purchases, issuances, sales and settlements: Settlements 2 — Balance, as of June 30, 2018 $ (45 ) $ — ___________________________________________ (a) Commodity Derivatives Utica Contingent Consideration 2019 2018 2019 2018 ($ in millions) Total gains (losses) included in earnings for the period $ (64 ) $ (32 ) $ (7 ) $ — Change in unrealized gains (losses) related to assets still held at reporting date $ (66 ) $ (30 ) $ (7 ) $ — June 30, 2019 and December 31, 2018: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2019 Financial Assets (Liabilities): Other current assets $ 44 $ — $ — $ 44 Other current liabilities (45 ) — — (45 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2018 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 )

Condensed Consolidating Finan_2

Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2019
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidated Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEET AS OF JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 9 $ 1 $ 2 $ (8 ) $ 4 Other current assets 54 1,229 97 — 1,380 Intercompany receivable, net 6,321 — — (6,321 ) — Total Current Assets 6,384 1,230 99 (6,329 ) 1,384 PROPERTY AND EQUIPMENT: Oil and natural gas properties, at cost based on successful efforts accounting, net — 9,556 4,132 — 13,688 Other property and equipment, net — 1,061 84 — 1,145 Property and equipment held for sale, net — 12 — — 12 Total Property and Equipment, Net — 10,629 4,216 — 14,845 LONG-TERM ASSETS: Other long-term assets 327 247 24 (287 ) 311 Investments in subsidiaries and intercompany advances 5,982 2,338 — (8,320 ) — TOTAL ASSETS $ 12,693 $ 14,444 $ 4,339 $ (14,936 ) $ 16,540 CURRENT LIABILITIES: Current liabilities $ 137 $ 1,841 $ 250 $ (8 ) $ 2,220 Intercompany payable, net — 6,321 — (6,321 ) — Total Current Liabilities 137 8,162 250 (6,329 ) 2,220 LONG-TERM LIABILITIES: Long-term debt, net 8,311 — 1,390 — 9,701 Other long-term liabilities 54 300 322 (287 ) 389 Total Long-Term Liabilities 8,365 300 1,712 (287 ) 10,090 EQUITY: Chesapeake stockholders’ equity 4,191 5,982 2,338 (8,320 ) 4,191 Noncontrolling interests — — 39 — 39 Total Equity 4,191 5,982 2,377 (8,320 ) 4,230 TOTAL LIABILITIES AND EQUITY $ 12,693 $ 14,444 $ 4,339 $ (14,936 ) $ 16,540 CONDENSED CONSOLIDATING BALANCE SHEET AS OF DECEMBER 31, 2018 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 4 $ 1 $ 1 $ (2 ) $ 4 Other current assets 60 1,532 2 — 1,594 Intercompany receivable, net 6,671 — — (6,671 ) — Total Current Assets 6,735 1,533 3 (6,673 ) 1,598 PROPERTY AND EQUIPMENT: Oil and natural gas properties, at cost based on successful efforts accounting, net — 9,664 48 — 9,712 Other property and equipment, net — 1,091 — — 1,091 Property and equipment held for sale, net — 15 — — 15 Total Property and Equipment, Net — 10,770 48 — 10,818 LONG-TERM ASSETS: Other long-term assets 26 293 — — 319 Investments in subsidiaries and intercompany advances 3,248 9 — (3,257 ) — TOTAL ASSETS $ 10,009 $ 12,605 $ 51 $ (9,930 ) $ 12,735 CURRENT LIABILITIES: Current liabilities $ 523 $ 2,365 $ 1 $ (2 ) $ 2,887 Intercompany payable, net — 6,671 — (6,671 ) — Total Current Liabilities 523 9,036 1 (6,673 ) 2,887 LONG-TERM LIABILITIES: Long-term debt, net 7,341 — — — 7,341 Other long-term liabilities 53 321 — — 374 Total Long-Term Liabilities 7,394 321 — — 7,715 EQUITY: Chesapeake stockholders’ equity 2,092 3,248 9 (3,257 ) 2,092 Noncontrolling interests — — 41 — 41 Total Equity 2,092 3,248 50 (3,257 ) 2,133 TOTAL LIABILITIES AND EQUITY $ 10,009 $ 12,605 $ 51 $ (9,930 ) $ 12,735
Condensed Consolidated Income Statements	CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 1,218 $ 236 $ — $ 1,454 Marketing — 916 — — 916 Total Revenues — 2,134 236 — 2,370 Other — 15 — — 15 Gains on sales of assets — 1 — — 1 Total Revenues and Other — 2,150 236 — 2,386 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 28 — 166 Oil, natural gas and NGL gathering, processing and transportation — 265 6 — 271 Production taxes — 30 10 — 40 Exploration — 16 (1 ) — 15 Marketing — 940 — — 940 General and administrative — 65 24 — 89 Provision for legal contingencies, net — 3 — — 3 Depreciation, depletion and amortization — 439 141 — 580 Impairments — 1 — — 1 Other operating expense — 3 — — 3 Total Operating Expenses — 1,900 208 — 2,108 INCOME FROM OPERATIONS — 250 28 — 278 OTHER INCOME (EXPENSE): Interest income (expense) (160 ) 5 (20 ) — (175 ) Losses on investments — — (23 ) — (23 ) Other income — 16 2 — 18 Equity in net earnings of subsidiary 281 10 — (291 ) — Total Other Income (Expense) 121 31 (41 ) (291 ) (180 ) INCOME(LOSS) BEFORE INCOME TAXES 121 281 (13 ) (291 ) 98 INCOME TAX (BENEFIT) EXPENSE 23 — (23 ) — — NET INCOME 98 281 10 (291 ) 98 Net income attributable to noncontrolling interests — — — — — NET INCOME ATTRIBUTABLE TO CHESAPEAKE 98 281 10 (291 ) 98 Other comprehensive income — 8 — — 8 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 98 $ 289 $ 10 $ (291 ) $ 106 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 978 $ 4 $ — $ 982 Marketing — 1,273 — — 1,273 Total Revenues — 2,251 4 — 2,255 Other — 16 — — 16 Gains on sales of assets — 18 — — 18 Total Revenues and Other — 2,285 4 — 2,289 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 — — 138 Oil, natural gas and NGL gathering, processing and transportation — 338 2 — 340 Production taxes — 26 — — 26 Exploration — 20 — — 20 Marketing — 1,292 — — 1,292 General and administrative — 104 1 — 105 Provision for legal contingencies, net — 4 — — 4 Depreciation, depletion and amortization — 470 1 — 471 Impairments — 54 — — 54 Other operating income — (1 ) — — (1 ) Total Operating Expenses — 2,445 4 — 2,449 INCOME FROM OPERATIONS — (160 ) — — (160 ) OTHER INCOME (EXPENSE): Interest expense (155 ) — — — (155 ) Other income — 57 — — 57 Equity in net earnings of subsidiary (103 ) — (1 ) 104 — Total Other Income (Expense) (258 ) 57 (1 ) 104 (98 ) LOSS BEFORE INCOME TAXES (258 ) (103 ) (1 ) 104 (258 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET LOSS (249 ) (103 ) (1 ) 104 (249 ) Net (income) loss attributable to noncontrolling interests — (1 ) 1 — — NET LOSS ATTRIBUTABLE TO CHESAPEAKE (249 ) (104 ) — 104 (249 ) Other comprehensive income — 7 — — 7 COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE $ (249 ) $ (97 ) $ — $ 104 $ (242 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,068 $ 315 $ — $ 2,383 Marketing — 2,149 — — 2,149 Total Revenues — 4,217 315 — 4,532 Other — 30 — — 30 Gains on sales of assets — 20 — — 20 Total Revenues and Other — 4,267 315 — 4,582 OPERATING EXPENSES: Oil, natural gas and NGL production — 255 43 — 298 Oil, natural gas and NGL gathering, processing and transportation — 534 11 — 545 Production taxes — 58 16 — 74 Exploration — 36 3 — 39 Marketing — 2,170 — — 2,170 General and administrative — 150 42 — 192 Provision for legal contingencies, net — 3 — — 3 Depreciation, depletion and amortization — 874 225 — 1,099 Impairments — 2 — — 2 Other operating expense — 26 38 — 64 Total Operating Expenses — 4,108 378 — 4,486 INCOME (LOSS) FROM OPERATIONS — 159 (63 ) — 96 OTHER INCOME (EXPENSE): Interest income (expense) (314 ) 10 (32 ) — (336 ) Losses on investments — — (24 ) — (24 ) Other income — 25 2 — 27 Equity in net earnings of subsidiary 104 (90 ) — (14 ) — Total Other Expense (210 ) (55 ) (54 ) (14 ) (333 ) INCOME (LOSS) BEFORE INCOME TAXES (210 ) 104 (117 ) (14 ) (237 ) INCOME TAX BENEFIT (287 ) — (27 ) — (314 ) NET INCOME (LOSS) 77 104 (90 ) (14 ) 77 Net income attributable to noncontrolling interests — — — — — NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE 77 104 (90 ) (14 ) 77 Other comprehensive income — 18 — — 18 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ 77 $ 122 $ (90 ) $ (14 ) $ 95 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,216 $ 9 $ — $ 2,225 Marketing — 2,519 — — 2,519 Total Revenues — 4,735 9 — 4,744 Other — 32 — — 32 Gains on sales of assets — 37 — — 37 Total Revenues and Other — 4,804 9 — 4,813 OPERATING EXPENSES: Oil, natural gas and NGL production — 285 — — 285 Oil, natural gas and NGL gathering, processing and transportation — 693 3 — 696 Production taxes — 57 — — 57 Exploration — 101 — — 101 Marketing — 2,560 — — 2,560 General and administrative — 191 1 — 192 Restructuring and other termination costs — 38 — — 38 Provision for legal contingencies, net — 9 — — 9 Depreciation, depletion and amortization — 927 3 — 930 Impairments — 64 — — 64 Other operating income — (1 ) — — (1 ) Total Operating Expenses — 4,924 7 — 4,931 INCOME (LOSS) FROM OPERATIONS — (120 ) 2 — (118 ) OTHER INCOME (EXPENSE): Interest expense (317 ) — — — (317 ) Gains on investments — 139 — — 139 Other income — 56 — — 56 Equity in net earnings of subsidiary 76 1 (1 ) (76 ) — Total Other Income (Expense) (241 ) 196 (1 ) (76 ) (122 ) INCOME (LOSS) BEFORE INCOME TAXES (241 ) 76 1 (76 ) (240 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME (LOSS) (232 ) 76 1 (76 ) (231 ) Net income attributable to noncontrolling interests — (1 ) — — (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE (232 ) 75 1 (76 ) (232 ) Other comprehensive income — 17 — — 17 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ (232 ) $ 92 $ 1 $ (76 ) $ (215 )
Condensed Consolidated Cash Flow Statements	CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2019 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ — $ 613 $ 242 $ (2 ) $ 853 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (805 ) (265 ) — (1,070 ) Business combination, net — (381 ) 28 — (353 ) Acquisitions of proved and unproved properties — (17 ) — — (17 ) Proceeds from divestitures of proved and unproved properties — 82 — — 82 Additions to other property and equipment — (7 ) (11 ) — (18 ) Other investing activities — 4 — — 4 Net Cash Used In Investing Activities — (1,124 ) (248 ) — (1,372 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,119 — 297 — 6,416 Payments on revolving credit facility borrowings (5,166 ) — (286 ) — (5,452 ) Cash paid to purchase debt (381 ) — — — (381 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (12 ) (4 ) (4 ) 2 (18 ) Intercompany advances, net (515 ) 515 — — — Net Cash Provided By (Used In) Financing Activities (1 ) 511 7 2 519 Net increase (decrease) in cash and cash equivalents (1 ) — 1 — — Cash and cash equivalents, beginning of period 4 1 1 (2 ) 4 Cash and cash equivalents, end of period $ 3 $ 1 $ 2 $ (2 ) $ 4 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 88 $ 866 $ 5 $ (8 ) $ 951 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (928 ) — — (928 ) Acquisitions of proved and unproved properties — (102 ) — — (102 ) Proceeds from divestitures of proved and unproved properties — 384 — — 384 Additions to other property and equipment — (5 ) — — (5 ) Other investing activities — 148 — — 148 Net Cash Used In Investing Activities — (503 ) — — (503 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — — — 6,118 Payments on revolving credit facility borrowings (6,393 ) — — — (6,393 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (2 ) (126 ) (7 ) 6 (129 ) Intercompany advances, net 235 (237 ) 2 — — Net Cash Used In Financing Activities (88 ) (363 ) (5 ) 6 (450 ) Net decrease in cash and cash equivalents — — — (2 ) (2 ) Cash and cash equivalents, beginning of period 5 1 2 (3 ) 5 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (5 ) $ 3

Change in Accounting Principl_2

Change in Accounting Principle - Statements of Operations (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
REVENUES AND OTHER:
Revenues	$ 2,386	$ 2,289	[1]	$ 4,582		$ 4,813	[1]
Gains on sales of assets	1	18	[1]	20		37	[1],[2]
OPERATING EXPENSES:
Production taxes	40	26	[1]	74		57	[1]
General and administrative	89	105	[1]	192		192	[1]
Restructuring and other termination costs	0	0	[1]	0		38	[1]
Provision for legal contingencies, net	3	4	[1]	3		9	[1]
Depreciation, depletion and amortization	580	471	[1]	1,099		930	[1],[2]
Impairments	1	54	[1]	2		64	[1],[2]
Gain (loss) on sale of oil and natural gas properties	0			0
Other operating (income) expense	3	(1)	[1]	64		(1)	[1]
Total Operating Expenses	2,108	2,449	[1]	4,486		4,931	[1]
INCOME (LOSS) FROM OPERATIONS	278	(160)	[1]	96		(118)	[1]
OTHER INCOME (EXPENSE):
Interest expense	(175)	(155)	[1]	(336)	[1]	(317)	[1]
Gains (losses) on investments	(23)	0	[1]	(24)		139	[1]
Other income	18	57	[1]	27	[1]	56	[1]
Total Other Expense	(180)	(98)	[1]	(333)	[1]	(122)	[1]
INCOME (LOSS) BEFORE INCOME TAXES	98	(258)	[1]	(237)	[1]	(240)	[1]
INCOME TAX (BENEFIT) EXPENSE	0	(9)	[1]	(314)	[1]	(9)	[1]
NET INCOME (LOSS)	98	(249)	[3]	77	[2],[3]	(231)	[2],[3]
Net income attributable to noncontrolling interests	0	0	[3]	0	[3]	(1)	[3]
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98	(249)	[1]	77	[1]	(232)	[1]
Preferred stock dividends	(23)	(23)	[1]	(46)		(46)	[1]
Earnings allocated to participating securities	0			0		0
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ 75	$ (272)	[1]	$ 31		$ (278)	[1]
EARNINGS (LOSS) PER COMMON SHARE:
Basic (in dollars per share)	$ 0.05	$ (0.30)	[1]	$ 0.02		$ (0.31)	[1]
Diluted (in dollars per share)	$ 0.05	$ (0.30)	[1]	$ 0.02		$ (0.31)	[1]
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Basic (in shares)	1,628	909	[1]	1,505		908	[1]
Diluted (in shares)	1,628	909	[1]	1,505		908	[1]
Oil, natural gas and NGL
REVENUES AND OTHER:
Revenues	$ 1,454	$ 982	[1]	$ 2,383		$ 2,225	[1]
Marketing
REVENUES AND OTHER:
Revenues	916	1,273	[1]	2,149		2,519	[1]
OPERATING EXPENSES:
Expense	940	1,292	[1]	2,170		2,560	[1]
Oil, natural gas and NGL and Marketing
REVENUES AND OTHER:
Revenues	2,370	2,255	[1]	4,532		4,744	[1]
Other
REVENUES AND OTHER:
Revenues	15	16	[1]	30		32	[1]
Oil, natural gas and NGL production
OPERATING EXPENSES:
Expense	166	138	[1]	298		285	[1]
Oil, natural gas and NGL gathering, processing and transportation
OPERATING EXPENSES:
Expense	271	340	[1]	545		696	[1]
Exploration
OPERATING EXPENSES:
Expense	15	20	[1]	39		101	[1]
Under Full Cost
REVENUES AND OTHER:
Revenues	2,370	2,255		4,532		4,744
Gains on sales of assets	0	0		0		0
OPERATING EXPENSES:
Production taxes	40	26		74		57
General and administrative	76	91		164		163
Restructuring and other termination costs						38
Provision for legal contingencies, net	3	4		3		9
Depreciation, depletion and amortization	419	290		776		576
Impairments	1	46		2		46
Gain (loss) on sale of oil and natural gas properties	(1)			(10)
Other operating (income) expense	4	(2)		64		6
Total Operating Expenses	1,919	2,225		4,086		4,436
INCOME (LOSS) FROM OPERATIONS	451	30		446		308
OTHER INCOME (EXPENSE):
Interest expense	(131)	(117)		(266)		(240)
Gains (losses) on investments	(23)			(24)		139
Other income	13	62		20		62
Total Other Expense	(141)	(55)		(270)		(39)
INCOME (LOSS) BEFORE INCOME TAXES	310	(25)		176		269
INCOME TAX (BENEFIT) EXPENSE	0	(9)		(314)		(9)
NET INCOME (LOSS)	310	(16)		490		278
Net income attributable to noncontrolling interests	0	(1)		(1)		(2)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		(17)		489		276
Preferred stock dividends	(23)	(23)		(46)		(46)
Earnings allocated to participating securities	(1)			(3)		(2)
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ 286	$ (40)		$ 440		$ 228
EARNINGS (LOSS) PER COMMON SHARE:
Basic (in dollars per share)	$ 0.18	$ (0.04)		$ 0.29		$ 0.25
Diluted (in dollars per share)	$ 0.18	$ (0.04)		$ 0.29		$ 0.25
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Basic (in shares)	1,628	909		1,505		908
Diluted (in shares)	1,628	909		1,505		908
Under Full Cost | Oil, natural gas and NGL
REVENUES AND OTHER:
Revenues	$ 1,454	$ 982		$ 2,383		$ 2,225
Under Full Cost | Marketing
REVENUES AND OTHER:
Revenues	916	1,273		2,149		2,519
OPERATING EXPENSES:
Expense	940	1,292		2,170		2,560
Under Full Cost | Oil, natural gas and NGL and Marketing
REVENUES AND OTHER:
Revenues	2,370	2,255		4,532		4,744
Under Full Cost | Other
REVENUES AND OTHER:
Revenues	0	0		0		0
Under Full Cost | Oil, natural gas and NGL production
OPERATING EXPENSES:
Expense	166	138		298		285
Under Full Cost | Oil, natural gas and NGL gathering, processing and transportation
OPERATING EXPENSES:
Expense	271	340		545		696
Under Full Cost | Exploration
OPERATING EXPENSES:
Expense	0	0		0		0
Successful Efforts Adjustment
REVENUES AND OTHER:
Revenues	16	34		50		69
Gains on sales of assets	1	18		20		37
OPERATING EXPENSES:
Production taxes	0	0		0		0
General and administrative	13	14		28		29
Restructuring and other termination costs						0
Provision for legal contingencies, net	0	0		0		0
Depreciation, depletion and amortization	161	181		323		354
Impairments	0	8		0		18
Gain (loss) on sale of oil and natural gas properties	1			10
Other operating (income) expense	(1)	1		0		(7)
Total Operating Expenses	189	224		400		495
INCOME (LOSS) FROM OPERATIONS	(173)	(190)		(350)		(426)
OTHER INCOME (EXPENSE):
Interest expense	(44)	(38)		(70)		(77)
Gains (losses) on investments	0			0		0
Other income	5	(5)		7		(6)
Total Other Expense	(39)	(43)		(63)		(83)
INCOME (LOSS) BEFORE INCOME TAXES	(212)	(233)		(413)		(509)
INCOME TAX (BENEFIT) EXPENSE	0	0		0		0
NET INCOME (LOSS)	(212)	(233)		(413)		(509)
Net income attributable to noncontrolling interests	0	1		1		1
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(212)	(232)		(412)		(508)
Preferred stock dividends	0	0		0		0
Earnings allocated to participating securities	1			3		2
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ (211)	$ (232)		$ (409)		$ (506)
EARNINGS (LOSS) PER COMMON SHARE:
Basic (in dollars per share)	$ (0.13)	$ (0.26)		$ (0.27)		$ (0.56)
Diluted (in dollars per share)	$ (0.13)	$ (0.26)		$ (0.27)		$ (0.56)
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Basic (in shares)	0	0		0		0
Diluted (in shares)	0	0		0		0
Successful Efforts Adjustment | Oil, natural gas and NGL
REVENUES AND OTHER:
Revenues	$ 0	$ 0		$ 0		$ 0
Successful Efforts Adjustment | Marketing
REVENUES AND OTHER:
Revenues	0	0		0		0
OPERATING EXPENSES:
Expense	0	0		0		0
Successful Efforts Adjustment | Oil, natural gas and NGL and Marketing
REVENUES AND OTHER:
Revenues	0	0		0		0
Successful Efforts Adjustment | Other
REVENUES AND OTHER:
Revenues	15	16		30		32
Successful Efforts Adjustment | Oil, natural gas and NGL production
OPERATING EXPENSES:
Expense	0	0		0		0
Successful Efforts Adjustment | Oil, natural gas and NGL gathering, processing and transportation
OPERATING EXPENSES:
Expense	0	0		0		0
Successful Efforts Adjustment | Exploration
OPERATING EXPENSES:
Expense	$ 15	$ 20		$ 39		$ 101
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Change in Accounting Principl_3

Change in Accounting Principle - Statements of Comprehensive Income (Loss) (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS)		$ 98	$ (249)	[1]	$ 77	[1],[2]	$ (231)	[1],[2]
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Unrealized gains on derivative instruments	[3]	0			0
Unrealized gains on derivative instruments	[1],[3]		0				0
Reclassification of losses on settled derivative instruments	[1],[3]		7				17
Losses reclassified to income, after tax	[3]	8			18
Other Comprehensive Income		8	7	[1]	18		17	[1]
COMPREHENSIVE INCOME (LOSS)		106	(242)	[1]	95		(214)	[1]
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	0	[1]	0		(1)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		106	(242)	[1]	95		(215)	[1]
Under Full Cost
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS)		310	(16)		490		278
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Unrealized gains on derivative instruments	[3]	0			0
Unrealized gains on derivative instruments	[3]		0				0
Reclassification of losses on settled derivative instruments		8	7				17
Losses reclassified to income, after tax					18
Other Comprehensive Income		8	7		18		17
COMPREHENSIVE INCOME (LOSS)		318	(9)		508		295
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	(1)		(1)		(2)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		318	(10)		507		293
Successful Efforts Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
NET INCOME (LOSS)		(212)	(233)		(413)		(509)
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Unrealized gains on derivative instruments	[3]	0			0
Unrealized gains on derivative instruments	[3]		0				0
Reclassification of losses on settled derivative instruments		0	0				0
Losses reclassified to income, after tax					0
Other Comprehensive Income		0	0		0		0
COMPREHENSIVE INCOME (LOSS)		(212)	(233)		(413)		(509)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		0	1		1		1
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		$ (212)	$ (232)		$ (412)		$ (508)
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Change in Accounting Principl_4

Change in Accounting Principle - Statements of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
Condensed Cash Flow Statements, Captions [Line Items]
NET INCOME (LOSS)	$ 98	$ (249)	[1]	$ 77	[1],[2]	$ (231)	[1],[2]
CASH FLOWS FROM OPERATING ACTIVITIES:
Depreciation, depletion and amortization	580	471	[3]	1,099		930	[2],[3]
Deferred income tax benefit				(314)		(9)	[2]
Derivative losses, net				30		368	[2]
Cash payments on derivative settlements, net				15		(55)	[2]
Stock-based compensation				17		18	[2]
Gains on sales of assets	(1)	(18)	[3]	(20)		(37)	[2],[3]
Impairments	1	54	[3]	2		64	[2],[3]
Exploration				25		73	[2]
(Gains) losses on investments				18		(139)	[2]
Other				41		(93)	[2]
Changes in assets and liabilities				(137)		62	[2]
Net Cash Provided By Operating Activities				853		951	[2]
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs				(1,070)		(928)	[2]
Business combination, net				(353)		0	[2]
Acquisitions of proved and unproved properties				(17)		(102)	[2]
Proceeds from divestitures of proved and unproved properties				82		384	[2]
Additions to other property and equipment				(18)		(5)	[2]
Proceeds from sales of other property and equipment				4		74	[2]
Proceeds from sales of investments				0		74	[2]
Net Cash Used In Investing Activities				(1,372)		(503)	[2]
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings				6,416		6,118	[2]
Payments on revolving credit facility borrowings				(5,452)		(6,393)	[2]
Extinguishment of other financing				0		(122)	[2]
Cash paid to purchase debt				(381)		0	[2]
Cash paid for preferred stock dividends				(46)		(46)	[2]
Distributions to noncontrolling interest owners				(2)		(3)	[2]
Other				(16)		(4)	[2]
Net Cash Provided By (Used In) Financing Activities				519		(450)	[2]
Net decrease in cash and cash equivalents				0		(2)	[2]
Cash and cash equivalents, beginning of period				4		5	[2]
Cash and cash equivalents, end of period	4	3	[2]	4		3	[2]
Under Full Cost
Condensed Cash Flow Statements, Captions [Line Items]
NET INCOME (LOSS)	310	(16)		490		278
CASH FLOWS FROM OPERATING ACTIVITIES:
Depreciation, depletion and amortization	419	290		776		576
Deferred income tax benefit				(314)		(9)
Derivative losses, net				30		368
Cash payments on derivative settlements, net				15		(55)
Stock-based compensation				17		18
Gains on sales of assets	0	0		0		0
Impairments	1	46		2		46
Exploration				0		0
(Gains) losses on investments				18		(139)
Other				31		(86)
Changes in assets and liabilities				(107)		94
Net Cash Provided By Operating Activities				958		1,091
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs				(1,104)		(979)
Business combination, net				(353)
Acquisitions of proved and unproved properties				(88)		(191)
Proceeds from divestitures of proved and unproved properties				82		384
Additions to other property and equipment				(18)		(5)
Proceeds from sales of other property and equipment				4		74
Proceeds from sales of investments						74
Net Cash Used In Investing Activities				(1,477)		(643)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings				6,416		6,118
Payments on revolving credit facility borrowings				(5,452)		(6,393)
Extinguishment of other financing						(122)
Cash paid to purchase debt				(381)
Cash paid for preferred stock dividends				(46)		(46)
Distributions to noncontrolling interest owners				(2)		(3)
Other				(16)		(4)
Net Cash Provided By (Used In) Financing Activities				519		(450)
Net decrease in cash and cash equivalents				0		(2)
Cash and cash equivalents, beginning of period				4		5
Cash and cash equivalents, end of period	4	3		4		3
Successful Efforts Adjustment
Condensed Cash Flow Statements, Captions [Line Items]
NET INCOME (LOSS)	(212)	(233)		(413)		(509)
CASH FLOWS FROM OPERATING ACTIVITIES:
Depreciation, depletion and amortization	161	181		323		354
Deferred income tax benefit				0		0
Derivative losses, net				0		0
Cash payments on derivative settlements, net				0		0
Stock-based compensation				0		0
Gains on sales of assets	(1)	(18)		(20)		(37)
Impairments	0	8		0		18
Exploration				25		73
(Gains) losses on investments				0		0
Other				10		(7)
Changes in assets and liabilities				(30)		(32)
Net Cash Provided By Operating Activities				(105)		(140)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs				34		51
Business combination, net				0
Acquisitions of proved and unproved properties				71		89
Proceeds from divestitures of proved and unproved properties				0		0
Additions to other property and equipment				0		0
Proceeds from sales of other property and equipment				0		0
Proceeds from sales of investments						0
Net Cash Used In Investing Activities				105		140
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings				0		0
Payments on revolving credit facility borrowings				0		0
Extinguishment of other financing						0
Cash paid to purchase debt				0
Cash paid for preferred stock dividends				0		0
Distributions to noncontrolling interest owners				0		0
Other				0		0
Net Cash Provided By (Used In) Financing Activities				0		0
Net decrease in cash and cash equivalents				0		0
Cash and cash equivalents, beginning of period				0		0
Cash and cash equivalents, end of period	$ 0	$ 0		$ 0		$ 0
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Change in Accounting Principl_5

Change in Accounting Principle - Statements of Shareholders' Equity (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018		Jan. 01, 2019	Dec. 31, 2018	Jan. 01, 2018	[3]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period					$ 2,092
Net loss attributable to Chesapeake		$ 98	$ (249)	[1]	77	[1]	$ (232)	[1]
Chesapeake stockholders’ equity, end of period		4,191			4,191
Stockholders' equity attributable to noncontrolling interest, beginning of period					41
Net income attributable to noncontrolling interests		0	0	[2]	0	[2]	(1)	[2]
Stockholders' equity attributable to noncontrolling interest, end of period		39			39
TOTAL EQUITY		4,230	1,689	[3]	4,230		1,689	[3]		$ 2,133
PREFERRED STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period	[3]	1,671	1,671		1,671		1,671
Chesapeake stockholders’ equity, end of period		1,671	1,671	[3]	1,671		1,671	[3]
COMMON STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		16	9	[3]	9		9	[3]
Common shares issued for WildHorse Merger		0	0	[3]	7		0	[3]
Chesapeake stockholders’ equity, end of period	[3]	16	9		16		9
ADDITIONAL PAID-IN CAPITAL
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		16,392	14,419	[3]	14,378		14,437	[3]
Common shares issued for WildHorse Merger		0	0	[3]	2,030		0	[3]
Stock-based compensation		11	12	[3]	18		17	[3]
Dividends on preferred stock		(23)	(23)	[3]	(46)		(46)	[3]
Chesapeake stockholders’ equity, end of period		16,380	14,408	[3]	16,380		14,408	[3]
ACCUMULATED DEFICIT
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(13,933)	(14,121)	[3]	(13,912)		(14,130)	[3]
Net loss attributable to Chesapeake		98	(249)	[3]	77		(232)	[3]
Cumulative effect of accounting change									$ 0		$ (8)
Chesapeake stockholders’ equity, end of period	[3]	(13,835)	(14,370)		(13,835)		(14,370)
ACCUMULATED OTHER COMPREHENSIVE LOSS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(13)	(47)	[3]	(23)		(57)	[3]
Hedging activity		8	7	[3]	18		17	[3]
Chesapeake stockholders’ equity, end of period		(5)	(40)	[3]	(5)		(40)	[3]
TREASURY STOCK – COMMON:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(36)	(32)	[3]	(31)		(31)	[3]
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans		(1)	0	[3]	(7)		(4)	[3]
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans		1	1	[3]	2		4	[3]
Chesapeake stockholders’ equity, end of period		$ (36)	$ (31)	[3]	$ (36)		$ (31)	[3]
Purchase of shares for company benefit plans (in shares)		81,093	17,046		2,620,566		1,468,524
Release of shares from company benefit plans (in shares)		148,767	114,450		259,563		389,857
TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, end of period		$ 4,191	$ 1,647	[3]	$ 4,191		$ 1,647	[3]
NONCONTROLLING INTERESTS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to noncontrolling interest, beginning of period		41	43	[3]	41		44	[3]
Net income attributable to noncontrolling interests		0	0	[3]	0		1	[3]
Distributions to noncontrolling interest owners		(2)	(1)	[3]	(2)		(3)	[3]
Stockholders' equity attributable to noncontrolling interest, end of period		39	42	[3]	39		42	[3]
Under Full Cost
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss attributable to Chesapeake			(17)		489		276
Net income attributable to noncontrolling interests		0	(1)		(1)		(2)
TOTAL EQUITY		2,975	(117)		2,975		(117)
Under Full Cost | PREFERRED STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		1,671	1,671		1,671		1,671
Chesapeake stockholders’ equity, end of period		1,671	1,671		1,671		1,671
Under Full Cost | COMMON STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		16	9		9		9
Common shares issued for WildHorse Merger					7
Chesapeake stockholders’ equity, end of period		16	9		16		9
Under Full Cost | ADDITIONAL PAID-IN CAPITAL
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		16,392	14,419		14,378		14,437
Common shares issued for WildHorse Merger					2,030
Stock-based compensation		11	12		18		17
Dividends on preferred stock		(23)	(23)		(46)		(46)
Chesapeake stockholders’ equity, end of period		16,380	14,408		16,380		14,408
Under Full Cost | ACCUMULATED DEFICIT
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(15,481)	(16,240)		(15,660)		(16,525)
Net loss attributable to Chesapeake		310	(17)				276
Cumulative effect of accounting change			(8)				(8)
Chesapeake stockholders’ equity, end of period		(15,171)	(16,257)		(15,171)		(16,257)
Under Full Cost | ACCUMULATED OTHER COMPREHENSIVE LOSS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(13)	(47)		(23)		(57)
Hedging activity		8	7		18		17
Chesapeake stockholders’ equity, end of period		(5)	(40)		(5)		(40)
Under Full Cost | TREASURY STOCK – COMMON:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		(36)	(32)		(31)		(31)
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans		(1)	0		(7)		(4)
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans		1	1		2		4
Chesapeake stockholders’ equity, end of period		(36)	(31)		(36)		(31)
Under Full Cost | TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, end of period		2,855	(240)		2,855		(240)
Under Full Cost | NONCONTROLLING INTERESTS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to noncontrolling interest, beginning of period		122	123		123		124
Net income attributable to noncontrolling interests		0	1		(1)		2
Distributions to noncontrolling interest owners		(2)	(1)		(2)		(3)
Stockholders' equity attributable to noncontrolling interest, end of period		120	123		120		123
Successful Efforts Adjustment
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss attributable to Chesapeake		(212)	(232)		(412)		(508)
Net income attributable to noncontrolling interests		0	1		1		1
TOTAL EQUITY		1,255	1,806		1,255		1,806
Successful Efforts Adjustment | PREFERRED STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		0	0		0		0
Chesapeake stockholders’ equity, end of period		0	0		0		0
Successful Efforts Adjustment | COMMON STOCK
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		0	0		0		0
Common shares issued for WildHorse Merger					0
Chesapeake stockholders’ equity, end of period		0	0		0		0
Successful Efforts Adjustment | ADDITIONAL PAID-IN CAPITAL
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		0	0		0		0
Common shares issued for WildHorse Merger					0
Stock-based compensation		0	0		0		0
Dividends on preferred stock		0	0		0		0
Chesapeake stockholders’ equity, end of period		0	0		0		0
Successful Efforts Adjustment | ACCUMULATED DEFICIT
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		1,548	2,119		1,748		2,395
Net loss attributable to Chesapeake		(212)	(232)				(508)
Cumulative effect of accounting change			0				0
Chesapeake stockholders’ equity, end of period		1,336	1,887		1,336		1,887
Successful Efforts Adjustment | ACCUMULATED OTHER COMPREHENSIVE LOSS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		0	0		0		0
Hedging activity		0	0		0		0
Chesapeake stockholders’ equity, end of period		0	0		0		0
Successful Efforts Adjustment | TREASURY STOCK – COMMON:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, beginning of period		0	0		0		0
Purchase of 81,093, 17,046, 2,620,566, and 1,468,524 shares for company benefit plans		0	0		0		0
Release of 148,767, 114,450, 259,563 and 389,857 shares from company benefit plans		0	0		0		0
Chesapeake stockholders’ equity, end of period		0	0		0		0
Successful Efforts Adjustment | TOTAL CHESAPEAKE STOCKHOLDERS’ EQUITY
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Chesapeake stockholders’ equity, end of period		1,336	1,887		1,336		1,887
Successful Efforts Adjustment | NONCONTROLLING INTERESTS:
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to noncontrolling interest, beginning of period		(81)	(80)		(82)		(80)
Net income attributable to noncontrolling interests		0	(1)		1		(1)
Distributions to noncontrolling interest owners		0	0		0		0
Stockholders' equity attributable to noncontrolling interest, end of period		$ (81)	$ (81)		$ (81)		$ (81)
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for prior periods has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Oil and Natural Gas Property _3

Oil and Natural Gas Property Transactions - Narrative (Details) shares in Millions, $ in Millions	Feb. 01, 2019USD ($)shares	Mar. 31, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Jun. 30, 2018USD ($)well		Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)awell
Business Acquisition [Line Items]
Revenues			$ 2,386		$ 2,289	[1]		$ 4,582	$ 4,813	[1]
Proceeds from divestitures of proved and unproved properties								82	384	[2]
Mid-Continent
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties									$ 491
Number of net acres | a									238,500
Productive gas wells, number of wells, net | well					3,200				3,200
Other properties
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties			$ 56	$ 5				$ 82	$ 23
Wildhorse Resource Development Corporation
Business Acquisition [Line Items]
Common stock issued in the merger (in shares) | shares	717.4
Cash	$ 381
Revenues							$ 308
Operating expenses		$ 369
Other expenses		$ 54
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Oil and Natural Gas Property _4

Oil and Natural Gas Property Transactions - Purchase Price Allocation (Details) - USD ($) $ / shares in Units, $ in Millions	Feb. 01, 2019	Mar. 31, 2019
Fair Value of Assets Acquired:
Common shares, outstanding (in shares)	717,376,170
Share price (in dollars per share)	$ 2.84
Wildhorse Resource Development Corporation
Consideration:
Cash	$ 381
Fair value of Chesapeake’s common stock issued in the Merger (a)	2,037
Total consideration	2,418
Fair Value of Liabilities Assumed:
Current liabilities	166
Long-term debt	1,379
Deferred tax liabilities	314	$ 314
Other long-term liabilities	36
Amounts attributable to liabilities assumed	1,895
Fair Value of Assets Acquired:
Cash and cash equivalents	28
Other current assets	128
Proved oil and natural gas properties	3,264
Unproved properties	756
Other property and equipment	77
Other long-term assets	60
Amounts attributable to assets acquired	4,313
Total identifiable net assets	$ 2,418

Oil and Natural Gas Property _5

Oil and Natural Gas Property Transactions - Pro Forma Financial Information (Details) - Wildhorse Resource Development Corporation - USD ($) $ / shares in Units, $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Business Acquisition [Line Items]
Revenues	$ 2,403	$ 4,574	$ 5,085
Net income (loss) available to common stockholders	$ (332)	$ 16	$ (360)
Basic (in dollars per share)	$ (0.20)	$ 0.01	$ (0.22)
Diluted (in dollars per share)	$ (0.20)	$ 0.01	$ (0.22)

Capitalized Exploratory Well _3

Capitalized Exploratory Well Costs (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2019USD ($)
Changes in Capitalized Well Costs
Beginning balance	$ 36,000
Additions pending the determination of proved reserves	9,000
Divestitures and other	0
Reclassifications to proved properties	(18,000)
Charges to exploration expense	0
Ending balance	27,000
Capitalized exploratory well costs that have been capitalized for period greater than one year	$ 1,000

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities Excluded from Computation of EPS Table (Details) - shares shares in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Common stock equivalent of our convertible senior notes outstanding
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares of common stock that were excluded from the calculation of diluted EPS (in shares)	146	146	146	146
Participating securities
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares of common stock that were excluded from the calculation of diluted EPS (in shares)	1	1	1	1
Common stock equivalent of our preferred stock outstanding
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares of common stock that were excluded from the calculation of diluted EPS (in shares)	60	60	60	60

- Long-Term Debt Table (Details

- Long-Term Debt Table (Details) - USD ($)	Jun. 30, 2019	Feb. 01, 2019	Dec. 31, 2018
Long-Term Debt Instrument [Line Items]
Principal amount	$ 10,161,000,000		$ 8,168,000,000
Carrying amount	9,701,000,000		7,722,000,000
Debt issuance costs	(53,000,000)		(53,000,000)
Debt, current	0		(381,000,000)
Current maturities of long-term debt, net	0		(381,000,000)
Long-term debt, fair value	10,161,000,000		7,787,000,000
Long-term debt, net	9,701,000,000		7,341,000,000
Interest rate derivatives
Long-Term Debt Instrument [Line Items]
Principal amount	0		0
Interest rate derivatives	1,000,000		1,000,000
Senior notes | Floating rate senior notes due 2019
Long-Term Debt Instrument [Line Items]
Principal amount	0		380,000,000
Carrying amount	0		380,000,000
Senior notes | 6.625% senior notes due 2020
Long-Term Debt Instrument [Line Items]
Principal amount	208,000,000		437,000,000
Carrying amount	$ 208,000,000		437,000,000
Interest rate, stated percentage	6.625%
Senior notes | 6.875% senior notes due 2020
Long-Term Debt Instrument [Line Items]
Principal amount	$ 93,000,000		227,000,000
Carrying amount	$ 93,000,000		227,000,000
Interest rate, stated percentage	6.875%
Senior notes | 6.125% senior notes due 2021
Long-Term Debt Instrument [Line Items]
Principal amount	$ 167,000,000		548,000,000
Carrying amount	$ 167,000,000		548,000,000
Interest rate, stated percentage	6.125%
Senior notes | 5.375% senior notes due 2021
Long-Term Debt Instrument [Line Items]
Principal amount	$ 127,000,000		267,000,000
Carrying amount	$ 127,000,000		267,000,000
Interest rate, stated percentage	5.375%
Senior notes | 4.875% senior notes due 2022
Long-Term Debt Instrument [Line Items]
Principal amount	$ 451,000,000		451,000,000
Carrying amount	$ 451,000,000		451,000,000
Interest rate, stated percentage	4.875%
Senior notes | 5.75% senior notes due 2023
Long-Term Debt Instrument [Line Items]
Principal amount	$ 338,000,000		338,000,000
Carrying amount	$ 338,000,000		338,000,000
Interest rate, stated percentage	5.75%
Senior notes | 7.00% senior notes due 2024
Long-Term Debt Instrument [Line Items]
Principal amount	$ 850,000,000		850,000,000
Carrying amount	$ 850,000,000		850,000,000
Interest rate, stated percentage	7.00%
Senior notes | 6.875% senior notes due 2025
Long-Term Debt Instrument [Line Items]
Principal amount	$ 700,000,000	$ 700,000,000	0
Carrying amount	$ 704,000,000		0
Interest rate, stated percentage	6.875%	6.875%
Senior notes | 8.00% senior notes due 2025
Long-Term Debt Instrument [Line Items]
Principal amount	$ 1,300,000,000		1,300,000,000
Carrying amount	$ 1,292,000,000		1,291,000,000
Interest rate, stated percentage	8.00%
Senior notes | 7.5% senior notes due 2026
Long-Term Debt Instrument [Line Items]
Principal amount	$ 400,000,000		400,000,000
Carrying amount	400,000,000		400,000,000
Senior notes | 8.00% senior notes due 2026
Long-Term Debt Instrument [Line Items]
Principal amount	919,000,000		0
Carrying amount	$ 884,000,000		0
Interest rate, stated percentage	8.00%
Senior notes | 8.00% senior notes due 2027
Long-Term Debt Instrument [Line Items]
Principal amount	$ 1,300,000,000		1,300,000,000
Carrying amount	$ 1,299,000,000		1,299,000,000
Interest rate, stated percentage	8.00%
Convertible debt | 5.5% convertible senior notes due 2026
Long-Term Debt Instrument [Line Items]
Principal amount	$ 1,250,000,000		1,250,000,000
Carrying amount	$ 882,000,000		866,000,000
Interest rate, stated percentage	5.50%
Interest rate, effective percentage	11.50%
Convertible debt | 7.5% senior notes due 2026
Long-Term Debt Instrument [Line Items]
Interest rate, stated percentage	7.50%
Convertible debt | 8.00% senior notes due 2026
Long-Term Debt Instrument [Line Items]
Interest rate, stated percentage	8.00%
Convertible debt | 2.25% contingent convertible senior notes due 2038
Long-Term Debt Instrument [Line Items]
Principal amount	$ 0		1,000,000
Carrying amount	$ 0		1,000,000
Interest rate, stated percentage	2.25%
Line of credit | Chesapeake revolving credit facility | Revolving credit facility
Long-Term Debt Instrument [Line Items]
Principal amount	$ 1,372,000,000		419,000,000
Chesapeake revolving credit facility	1,372,000,000		419,000,000
Line of credit | BVL revolving credit facility | Revolving credit facility
Long-Term Debt Instrument [Line Items]
Principal amount	686,000,000		0
Chesapeake revolving credit facility	$ 686,000,000		$ 0

- Narrative (Details)

- Narrative (Details)	Feb. 01, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2018USD ($)
Long-Term Debt Instrument [Line Items]
Debt instrument, principal amount		$ 10,161,000,000						$ 8,168,000,000
Senior notes
Long-Term Debt Instrument [Line Items]
Repayments of senior debt		$ 380,000,000
Debt redemption, percent of principal amount of notes to be redeemed		100.00%
Debt redemption, percent of aggregate amount of notes to be redeemed		35.00%
Senior notes | 8.00% senior notes due 2026
Long-Term Debt Instrument [Line Items]
Debt instrument, principal amount		$ 919,000,000						0
Interest rate, stated percentage		8.00%
Senior notes | 6.875% senior notes due 2025
Long-Term Debt Instrument [Line Items]
Debt instrument, principal amount	$ 700,000,000	$ 700,000,000						0
Interest rate, stated percentage	6.875%	6.875%
Debt covenant, basket	$ 25,000,000
Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity		$ 3,000,000,000
Line of credit facility, maximum borrowing capacity, increased maximum		4,000,000,000
Letters of credit outstanding, amount		54,000,000
Leverage ratio	4
Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity		2,000,000,000
Line of credit facility, current borrowing capacity		$ 1,300,000,000
Mortgage guarantee, secured percent on proved reserves		85.00%
Ratio of net debt to EBITDAX	4
Ratio of funded debt to EBITDAX	4
Current Ratio	1
Revolving credit facility | Line of credit | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Debt instrument, principal amount		$ 1,372,000,000						419,000,000
Revolving credit facility | Line of credit | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Debt instrument, principal amount		$ 686,000,000						$ 0
Minimum | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Commitment fee	0.375%
Minimum | Alternative Base Rate (ABR) | Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	0.50%
Minimum | Alternative Base Rate (ABR) | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	0.50%
Minimum | Eurodollar | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	1.50%
Minimum | London Interbank Offered Rate (LIBOR) | Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	1.50%
Minimum | London Interbank Offered Rate (LIBOR) | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	1.50%
Maximum | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Commitment fee	0.50%
Maximum | Alternative Base Rate (ABR) | Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	2.00%
Maximum | Alternative Base Rate (ABR) | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	1.50%
Maximum | Eurodollar | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	2.50%
Maximum | London Interbank Offered Rate (LIBOR) | Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	3.00%
Maximum | London Interbank Offered Rate (LIBOR) | Revolving credit facility | BVL revolving credit facility
Long-Term Debt Instrument [Line Items]
Variable rate percentage	2.50%
Forecast | Revolving credit facility | Chesapeake revolving credit facility
Long-Term Debt Instrument [Line Items]
Leverage ratio			4				5.50
Secured leverage ratio			2.50
Fixed charge coverage ratio				2.50	2.25	2

Debt - Conversion (Details)

Debt - Conversion (Details) - Senior notes $ in Millions	3 Months Ended
	Jun. 30, 2019USD ($)
Debt Conversion [Line Items]
Amount of notes exchanged	$ 884
6.625% senior notes due 2020
Debt Conversion [Line Items]
Amount of notes exchanged	229
6.875% senior notes due 2020
Debt Conversion [Line Items]
Amount of notes exchanged	134
6.125% senior notes due 2021
Debt Conversion [Line Items]
Amount of notes exchanged	381
5.375% senior notes due 2021
Debt Conversion [Line Items]
Amount of notes exchanged	$ 140

- Fair Value of Debt Table (Det

- Fair Value of Debt Table (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 10,161	$ 7,787
Quoted Prices in Active Markets (Level 1) | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term debt, fair value	0	381
Long-term debt, fair value	3,321	3,495
Quoted Prices in Active Markets (Level 1) | Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term debt, fair value	0	379
Long-term debt, fair value	3,126	3,173
Significant Other Observable Inputs (Level 2) | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	6,380	3,846
Significant Other Observable Inputs (Level 2) | Estimated Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 6,060	$ 3,644

Contingencies and Commitments -

Contingencies and Commitments - Narrative (Details) - USD ($)	Jan. 05, 2014	Feb. 28, 2019	Aug. 09, 2018
Loss Contingencies [Line Items]
Settlement amount			$ 35,000,000
Chaparral Energy, Inc. | Healthcare of Ontario Pension Plan (HOOPP) | Pending litigation
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 215,000,000
FTS International, Inc. | Putative class action lawsuit | Pending litigation
Loss Contingencies [Line Items]
Loss contingency, damages sought, value		$ 1,000,000

Contingencies and Commitments_2

Contingencies and Commitments - Gathering Processing and Transportation Commitments Table (Details) - Gathering, processing and transportation agreement $ in Millions	Jun. 30, 2019USD ($)
Other Commitments [Line Items]
Remainder of 2019	$ 415
2020	789
2021	691
2022	590
2023	477
2024-2035	2,451
Total	$ 5,413

Other Liabilities - Current Tab

Other Liabilities - Current Table (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Other Liabilities Disclosure [Abstract]
Revenues and royalties due others	$ 434	$ 687
Accrued drilling and production costs	441	258
Joint interest prepayments received	60	73
VPP deferred revenue	57	59
Accrued compensation and benefits	133	202
Other accrued taxes	126	108
Other	179	212
Total other current liabilities	$ 1,430	$ 1,599

Other Liabilities - Long-Term T

Other Liabilities - Long-Term Table (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Other Liabilities Disclosure [Abstract]
VPP deferred revenue	$ 36	$ 63
Unrecognized tax benefits	54	53
Other	115	103
Total other long-term liabilities	$ 205	$ 219

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	Feb. 01, 2019USD ($)contract	Jun. 30, 2019USD ($)	Dec. 31, 2018
Lessee, Lease, Description [Line Items]
Operating lease liability		$ 27
Operating lease, right-of-use asset		$ 25
Natural Gas Compressors | Midcon Compression, L.L.C.
Lessee, Lease, Description [Line Items]
Lease terms			38 months
Wildhorse Resource Development Corporation
Lessee, Lease, Description [Line Items]
Operating lease liability	$ 40
Operating lease, right-of-use asset	38
Lease incentive	$ 2
Number of leases | contract	2
Minimum
Lessee, Lease, Description [Line Items]
Lease, remaining lease term		1 month
Maximum
Lessee, Lease, Description [Line Items]
Lease, remaining lease term		7 years 6 months

Leases - ROU Assets and Liabili

Leases - ROU Assets and Liabilities (Details) $ in Millions	Jun. 30, 2019USD ($)
Assets and Liabilities, Lessee [Abstract]
Financing, ROU assets	$ 22
Financing, current lease liabilities	9
Financing, long-term lease liabilities	13
Present value of lease liabilities	22
Operating, ROU assets	25
Operating, current lease liabilities	12
Operating, long-term lease liabilities	15
Present value of lease liabilities	$ 27

Leases - Additional Information

Leases - Additional Information (Details) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)
Lease cost:
Amortization of ROU assets	$ 2	$ 4
Interest on lease liability	0	1
Finance lease cost	2	5
Operating lease cost	10	17
Short-term lease cost	26	48
Total lease cost	38	70
Other information:
Operating cash outflows from finance lease	0	1
Operating cash outflows from operating leases	3	5
Investing cash outflows from operating leases	33	60
Financing cash outflows from finance lease	$ 2	$ 4
Weighted-average remaining lease term - finance lease	2 years 6 months	2 years 6 months
Weighted-average remaining lease term - operating leases	4 years 6 months	4 years 6 months
Weighted-average discount rate - finance lease	7.50%	7.50%
Weighted-average discount rate - operating leases	4.83%	4.83%
Capitalized lease costs	$ 33	$ 60

Leases - Maturity Analysis of F

Leases - Maturity Analysis of Finance and Operating Lease Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Finance Leases, After Adoption of 842:
Remainder of 2019	$ 5
2020	10
2021	10
2022	0
2023	0
Thereafter	0
Total lease payments	25
Less imputed interest	(3)
Present value of lease liabilities	22
Less current maturities	(9)
Present value of lease liabilities, less current maturities	13
Operating Leases, After Adoption of 842:
Remainder of 2019	8
2020	8
2021	3
2022	2
2023	2
Thereafter	7
Total lease payments	30
Less imputed interest	(3)
Present value of lease liabilities	27
Less current maturities	(12)
Present value of lease liabilities, less current maturities	$ 15
Capital Leases, Before Adoption of 842:
2019		$ 10
2020		10
2021		10
Total minimum lease payments		30
Operating Leases, After Before of 842:
2019		3
2020		1
2021		0
Total minimum lease payments		$ 4

Revenue Recognition - Additiona

Revenue Recognition - Additional Information (Details) - Retained Earnings - USD ($) $ in Millions	Jan. 01, 2019	Jan. 01, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Cumulative effect of accounting change	$ 0	$ (8)	[1]
ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Cumulative effect of accounting change		$ (8)
[1]	Financial information for prior periods has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregated Revenue (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues	$ 1,179	$ 1,233		$ 2,409	$ 2,593
Gains (losses) on oil, natural gas and NGL derivatives	275	(251)		(26)	(368)
Revenues	2,386	2,289	[1]	4,582	4,813	[1]
Oil, natural gas and NGL
Disaggregation of Revenue [Line Items]
Revenues	1,454	982	[1]	2,383	2,225	[1]
Marketing
Disaggregation of Revenue [Line Items]
Revenues	824	1,069		1,967	2,158
Gains (losses) on oil, natural gas and NGL derivatives	(1)			(3)
Revenues	916	1,273	[1]	2,149	2,519	[1]
Other marketing revenue
Disaggregation of Revenue [Line Items]
Revenues	93	204		185	361
Marcellus
Disaggregation of Revenue [Line Items]
Revenues	198	169		500	462
Haynesville
Disaggregation of Revenue [Line Items]
Revenues	164	199		365	411
Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues	406	478		831	919
Brazos Valley
Disaggregation of Revenue [Line Items]
Revenues	213			340
Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	128	72		237	135
Mid-Continent
Disaggregation of Revenue [Line Items]
Revenues	70	89		136	215
Utica
Disaggregation of Revenue [Line Items]
Revenues		226			451
Oil
Disaggregation of Revenue [Line Items]
Revenues	700	567		1,266	1,104
Gains (losses) on oil, natural gas and NGL derivatives	86	(202)		(173)	(288)
Oil | Oil, natural gas and NGL
Disaggregation of Revenue [Line Items]
Revenues	786	365		1,093	816
Oil | Marketing
Disaggregation of Revenue [Line Items]
Revenues	614	732		1,227	1,418
Gains (losses) on oil, natural gas and NGL derivatives	0			0
Revenues	692	877		1,377	1,680
Oil | Other marketing revenue
Disaggregation of Revenue [Line Items]
Revenues	78	145		150	262
Oil | Marcellus
Disaggregation of Revenue [Line Items]
Revenues	0	0		0	0
Oil | Haynesville
Disaggregation of Revenue [Line Items]
Revenues	0	1		0	2
Oil | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues	349	390		680	750
Oil | Brazos Valley
Disaggregation of Revenue [Line Items]
Revenues	199			320
Oil | Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	102	52		176	95
Oil | Mid-Continent
Disaggregation of Revenue [Line Items]
Revenues	50	62		90	138
Oil | Utica
Disaggregation of Revenue [Line Items]
Revenues		62			119
Natural Gas
Disaggregation of Revenue [Line Items]
Revenues	436	538		1,031	1,244
Gains (losses) on oil, natural gas and NGL derivatives	189	(35)		147	(67)
Natural Gas | Oil, natural gas and NGL
Disaggregation of Revenue [Line Items]
Revenues	625	503		1,178	1,177
Natural Gas | Marketing
Disaggregation of Revenue [Line Items]
Revenues	162	235		575	528
Gains (losses) on oil, natural gas and NGL derivatives	(1)			(3)
Revenues	176	294		607	627
Natural Gas | Other marketing revenue
Disaggregation of Revenue [Line Items]
Revenues	15	59		35	99
Natural Gas | Marcellus
Disaggregation of Revenue [Line Items]
Revenues	198	169		500	462
Natural Gas | Haynesville
Disaggregation of Revenue [Line Items]
Revenues	164	198		365	409
Natural Gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues	37	42		85	84
Natural Gas | Brazos Valley
Disaggregation of Revenue [Line Items]
Revenues	9			13
Natural Gas | Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	18	11		43	23
Natural Gas | Mid-Continent
Disaggregation of Revenue [Line Items]
Revenues	10	15		25	47
Natural Gas | Utica
Disaggregation of Revenue [Line Items]
Revenues		103			219
NGL
Disaggregation of Revenue [Line Items]
Revenues	43	128		112	245
Gains (losses) on oil, natural gas and NGL derivatives	0	(14)		0	(13)
NGL | Oil, natural gas and NGL
Disaggregation of Revenue [Line Items]
Revenues	43	114		112	232
NGL | Marketing
Disaggregation of Revenue [Line Items]
Revenues	48	102		165	212
Gains (losses) on oil, natural gas and NGL derivatives	0			0
Revenues	48	102		165	212
NGL | Other marketing revenue
Disaggregation of Revenue [Line Items]
Revenues	0	0		0	0
NGL | Marcellus
Disaggregation of Revenue [Line Items]
Revenues	0	0		0	0
NGL | Haynesville
Disaggregation of Revenue [Line Items]
Revenues	0	0		0	0
NGL | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues	20	46		66	85
NGL | Brazos Valley
Disaggregation of Revenue [Line Items]
Revenues	5			7
NGL | Powder River Basin
Disaggregation of Revenue [Line Items]
Revenues	8	9		18	17
NGL | Mid-Continent
Disaggregation of Revenue [Line Items]
Revenues	$ 10	12		$ 21	30
NGL | Utica
Disaggregation of Revenue [Line Items]
Revenues		$ 61			$ 113
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Revenue Recognition - Accounts

Revenue Recognition - Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Allowance for doubtful accounts	$ (21)	$ (17)
Total accounts receivable, net	1,021	1,247
Oil, natural gas and NGL sales
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	682	976
Joint interest
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	289	211
Other
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	$ 71	$ 77

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	[1]	Jun. 30, 2019		Jun. 30, 2018	[1]	Feb. 01, 2019
Business Acquisition [Line Items]
Effective income tax rate	0.00%
Income tax benefit	$ 0		$ 9,000,000		$ 314,000,000	[1]	$ 9,000,000
Wildhorse Resource Development Corporation
Business Acquisition [Line Items]
Deferred tax liabilities		$ 314,000,000							$ 314,000,000
Income tax benefit	0	314,000,000			314,000,000
Deferred tax liability, plant, property and equipment and prepaid compensation		401,000,000
Deferred tax assets, operating loss carryforward, limitations	$ 61,000,000				$ 61,000,000
Wildhorse Resource Development Corporation | Federal
Business Acquisition [Line Items]
Deferred tax asset, operating loss carryforward		$ 87,000,000
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock (Details) - Participating securities shares in Thousands	6 Months Ended
	Jun. 30, 2019$ / sharesshares
Shares of Unvested Restricted Stock
Unvested restricted stock, beginning balance (in shares) | shares	11,858
Granted (in shares) | shares	5,364
Vested (in shares) | shares	(4,973)
Forfeited (in shares) | shares	(1,027)
Unvested restricted stock, ending balance (in shares) | shares	11,222
Weighted Average Grant Date Fair Value Per Share
Unvested restricted stock, beginning balance (in dollars per share) | $ / shares	$ 4.43
Granted (in dollars per share) | $ / shares	2.85
Vested (in dollars per share) | $ / shares	4.36
Forfeited (in dollars per share) | $ / shares	3.67
Unvested restricted stock, ending balance (in dollars per share) | $ / shares	$ 3.78

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Participating securities
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value of restricted stock, vested	$ 14
Unrecognized compensation expense	$ 30
Share-based compensation expense, weighted average period for recognition	2 years 3 days
Stock option
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense, weighted average period for recognition	1 year 4 months 20 days
Unrecognized compensation expense	$ 9
Stock option | Management
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period	3 years
Stock option | Management | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period	7 years
Stock option | Management | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period	10 years
Performance Share Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period	3 years
Performance Share Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance share units maximum payout percentage	0.00%
Performance Share Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance share units maximum payout percentage	200.00%
Performance Share Units | Management
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period	3 years
Performance share units maximum payout percentage	200.00%
Performance share grant maximum payout percentage	100.00%
Terms of award	less than zero
Performance Share Units | Management | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR component percentage performance share units	0.00%
Operational component percentage performance share ufnits	0.00%
Performance Share Units | Management | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR component percentage performance share units	100.00%
Operational component percentage performance share ufnits	100.00%
Cash Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period		3 years

Share-Based Compensation - Equi

Share-Based Compensation - Equity-Classified Valuation Table (Details) - Stock option	6 Months Ended
	Jun. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected option life – years	6 years
Volatility	65.61%
Risk-free interest rate	2.47%
Dividend yield	0.00%

Share-Based Compensation - Stoc

Share-Based Compensation - Stock Option Activity Table (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning balance (in shares options)	18,096
Granted (in shares options)	1,000
Exercised (in shares options)	0
Expired (in shares options)	(451)
Forfeited (in shares options)	(554)
Outstanding, ending balance (in shares options)	18,091	18,096
Weighted Average Exercise Price Per Share
Outstanding, beginning (in dollars per share)	$ 7.20
Granted (in dollars per share)	2.97
Exercised (in dollars per share)	0
Expired (in dollars per share)	6.57
Forfeited (in dollars per share)	3.82
Outstanding, ending (in dollars per share)	$ 7.09	$ 7.20
Weighted average contract life, outstanding	6 years 4 months 20 days	7 years 1 month 24 days
Aggregate intrinsic value, outstanding	$ 0	$ 0
Aggregate intrinsic value, exercised	$ 0
Exercisable (in shares options)	13,030
Weighted average exercise price, exercisable (in dollars per share)	$ 8.29
Weighted average contract life, exercisable (in years)	5 years 7 months 2 days
Aggregate intrinsic value, exercisable	$ 0

Share-Based Compensation - Eq_2

Share-Based Compensation - Equity-Classified Compensation Table (Details) - Restricted stock and stock options - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 10	$ 11	$ 18	$ 22
General and administrative expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	9	10	15	17
Oil and natural gas properties
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	0	0	1	2
Oil, natural gas and NGL production expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	1	1	2	3
Exploration expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 0	$ 0	$ 0	$ 0

Share-Based Compensation - Liab

Share-Based Compensation - Liability Classified Valuation Table (Details) - 2017 Awards - Performance Share Units	6 Months Ended
	Jun. 30, 2019
Grant Date Assumptions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	80.65%
Risk-free interest rate	1.54%
Dividend yield	0.00%
Reporting Period Assumptions
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	63.49%
Risk-free interest rate	2.08%
Dividend yield	0.00%

Share-Based Compensation - Perf

Share-Based Compensation - Performance Share Unit Breakout (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Performance Share Units | Award Year 2019, Payable 2020, 2021 and 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	4,887,868
Fair Value	$ 12	$ 15
Vested Liability	$ 0
Performance Share Units | Award Year 2018, Payable 2020 and 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	2,418,281
Fair Value	$ 5	7
Vested Liability	$ 0
Performance Share Units | Award Year 2017, Payable 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	1,174,973
Fair Value	$ 2	8
Vested Liability	$ 1
Cash Restricted Stock Units | Award Year 2018, Payable 2020 and 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	9,468,697
Fair Value	$ 18	$ 29
Vested Liability	$ 0

Share-Based Compensation - Li_2

Share-Based Compensation - Liability-Classified Compensation Table (Details) - Performance Share Units - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ (1)	$ 24	$ 12	$ 25
General and administrative expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	(1)	20	8	21
Oil and natural gas properties
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	0	1	1	1
Oil, natural gas and NGL production expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	1	2	3	2
Exploration expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ (1)	$ 1	$ 0	$ 1

Derivative and Hedging Activi_3

Derivative and Hedging Activities - Derivative Instruments (Details) MMBbls in Millions, $ in Millions, Bcf in Trillions	6 Months Ended	12 Months Ended
	Jun. 30, 2019USD ($)BcfMMBbls	Dec. 31, 2018USD ($)BcfMMBbls
Derivative [Line Items]
Derivative assets (liabilities), at fair value, net	$ 262	$ 282
Energy related derivative
Derivative [Line Items]
Derivative assets (liabilities), at fair value, net	262	282
Energy related derivative | Future Natural Gas Prices | Utica Shale
Derivative [Line Items]
Derivative assets (liabilities), at fair value, net	$ 0	$ 7
Energy related derivative | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	37	27
Derivative assets (liabilities), at fair value, net	$ 87	$ 260
Energy related derivative | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	697	966
Derivative assets (liabilities), at fair value, net	$ 175	$ 15
Energy related derivative | Fixed-price swaps | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	24	12
Derivative assets (liabilities), at fair value, net	$ 64	$ 157
Energy related derivative | Fixed-price swaps | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	505	623
Derivative assets (liabilities), at fair value, net	$ 176	$ 26
Energy related derivative | Three-way collars | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	15	88
Derivative assets (liabilities), at fair value, net	$ 2	$ 1
Energy related derivative | Collars | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	5	8
Derivative assets (liabilities), at fair value, net	$ 27	$ 98
Energy related derivative | Collars | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	18	55
Derivative assets (liabilities), at fair value, net	$ 7	$ (3)
Energy related derivative | Call options | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	33	44
Derivative assets (liabilities), at fair value, net	$ 0	$ 0
Energy related derivative | Call swaptions | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	2
Derivative assets (liabilities), at fair value, net	$ (5)
Energy related derivative | Call swaptions | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	106	106
Derivative assets (liabilities), at fair value, net	$ (10)	$ (9)
Energy related derivative | Put options | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	2
Derivative assets (liabilities), at fair value, net	$ (5)
Energy related derivative | Basis protection swaps | Oil
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	4	7
Derivative assets (liabilities), at fair value, net	$ 6	$ 5
Energy related derivative | Basis protection swaps | Natural Gas
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | Bcf	20	50
Derivative assets (liabilities), at fair value, net	$ 0	$ 0

Derivative and Hedging Activi_4

Derivative and Hedging Activities - Derivative Instruments in Balance Sheet Table (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative assets (liabilities), at fair value, net	$ 262	$ 282
Commodity contract
Derivatives, Fair Value [Line Items]
Derivative asset	314	422
Derivative liability	(52)	(147)
Energy related derivative
Derivatives, Fair Value [Line Items]
Derivative assets (liabilities), at fair value, net	262	282
Not designated as hedging instrument | Commodity contract
Derivatives, Fair Value [Line Items]
Derivative asset (liability), fair value, gross asset (liability)	262	282
Derivative asset (liability) fair value, net asset (liability), netted	0	0
Derivative assets (liabilities), at fair value, net	262	282
Short-term derivative asset | Not designated as hedging instrument | Commodity contract
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	250	306
Derivative asset, fair value, gross liability, netted	(26)	(104)
Derivative asset	224	202
Long-term derivative asset | Not designated as hedging instrument | Commodity contract
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	64	117
Derivative asset, fair value, gross liability, netted	(1)	(41)
Derivative asset	63	76
Short-term derivative liability | Not designated as hedging instrument | Commodity contract
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross liability	(48)	(107)
Derivative liability, fair value, gross asset, netted	26	104
Derivative liability	(22)	(3)
Long-term derivative liability | Not designated as hedging instrument | Commodity contract
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross liability	(4)	(41)
Derivative liability, fair value, gross asset, netted	1	41
Derivative liability	(3)	0
Future Natural Gas Prices | Short-term derivative asset | Not designated as hedging instrument | Energy related derivative
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	0	7
Derivative asset, fair value, gross liability, netted	0	0
Derivative asset	$ 0	$ 7

Derivative and Hedging Activi_5

Derivative and Hedging Activities - Oil, Natural Gas and NGL Revenues (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019	Jun. 30, 2018
Derivative [Line Items]
Gains (losses) on undesignated oil, natural gas and NGL derivatives	$ 275	$ (251)		$ (26)	$ (368)
Revenues	2,386	2,289	[1]	4,582	4,813	[1]
Oil, natural gas and NGL sales
Derivative [Line Items]
Losses on terminated cash flow hedges	(8)	(7)		(18)	(17)
Oil, natural gas and NGL sales | Commodity contract | Not designated as hedging instrument
Derivative [Line Items]
Gains (losses) on undesignated oil, natural gas and NGL derivatives	283	(244)		(8)	(351)
Oil, natural gas and NGL
Derivative [Line Items]
Oil, natural gas and NGL revenues	1,179	1,233		2,409	2,593
Revenues	$ 1,454	$ 982	[1]	$ 2,383	$ 2,225	[1]
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Derivative and Hedging Activi_6

Derivative and Hedging Activities - Marketing Revenues (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019	Jun. 30, 2018
Derivative [Line Items]
Revenues	$ 1,179	$ 1,233		$ 2,409	$ 2,593
Losses on undesignated marketing natural gas derivatives	275	(251)		(26)	(368)
Revenues	2,386	2,289	[1]	4,582	4,813	[1]
Marketing, Gathering And Compression | Other contract
Derivative [Line Items]
Losses on undesignated marketing natural gas derivatives	(1)	0		(3)	0
Marketing | Marketing, Gathering And Compression
Derivative [Line Items]
Revenues	917	1,273		2,152	2,519
Marketing
Derivative [Line Items]
Revenues	824	1,069		1,967	2,158
Losses on undesignated marketing natural gas derivatives	(1)			(3)
Revenues	$ 916	$ 1,273	[1]	$ 2,149	$ 2,519	[1]
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Derivative and Hedging Activi_7

Derivative and Hedging Activities - Cash Flow Hedges Components of AOCI (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
AOCI, after tax, beginning of period				$ (23)
Losses reclassified to income, after tax	[1]	$ 8		18
Losses reclassified to income, after tax	[1],[2]		$ 7		$ 17
AOCI, after tax, end of period		(5)		(5)
Cash flow hedging
AOCI Attributable to Parent, Net of Tax [Roll Forward]
AOCI, before tax, beginning of period		(70)	(104)	(80)	(114)
AOCI, after tax, beginning of period		(13)	(47)	(23)	(57)
Losses reclassified to income, before tax		8		18
Losses reclassified to income, after tax		8		18
Losses reclassified to income, before tax			7		17
Losses reclassified to income, after tax			7		17
AOCI, before tax, end of period		(62)	(97)	(62)	(97)
AOCI, after tax, end of period		$ (5)	$ (40)	$ (5)	$ (40)
[1]	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Derivative and Hedging Activi_8

Derivative and Hedging Activities - Fair Value of Recurring Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	$ 262	$ 282
Commodity contract
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	314	422
Derivative liability	52	147
Energy related derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	262	282
Energy related derivative | Future Natural Gas Prices | Utica Shale
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	0	7
Derivative assets (liabilities), at fair value, net	0	7
Quoted Prices in Active Markets (Level 1)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	0	0
Quoted Prices in Active Markets (Level 1) | Commodity contract
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	0	0
Derivative liability	0	0
Quoted Prices in Active Markets (Level 1) | Energy related derivative | Future Natural Gas Prices | Utica Shale
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	0	0
Significant Other Observable Inputs (Level 2)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	240	188
Significant Other Observable Inputs (Level 2) | Commodity contract
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	280	319
Derivative liability	40	131
Significant Other Observable Inputs (Level 2) | Energy related derivative | Future Natural Gas Prices | Utica Shale
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	0	0
Significant Unobservable Inputs (Level 3)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	22	94
Significant Unobservable Inputs (Level 3) | Commodity contract
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	34	103
Derivative liability	12	16
Derivative assets (liabilities), at fair value, net	22	87	$ (45)	$ (15)
Significant Unobservable Inputs (Level 3) | Energy related derivative | Future Natural Gas Prices | Utica Shale
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative asset	0	7
Derivative assets (liabilities), at fair value, net	$ 0	$ 7	$ 0	$ 0

Derivative and Hedging Activi_9

Derivative and Hedging Activities - Fair Value Level 3 Measurements (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	$ 282
Derivative assets (liabilities), at fair value, net, end of period	262
Energy related derivative
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	282
Derivative assets (liabilities), at fair value, net, end of period	262
Future Natural Gas Prices | Utica Shale | Energy related derivative
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	7
Derivative assets (liabilities), at fair value, net, end of period	0
Significant Unobservable Inputs (Level 3)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	94
Derivative assets (liabilities), at fair value, net, end of period	22
Significant Unobservable Inputs (Level 3) | Commodity contract
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	87	$ (15)
Gains (loses) included in earnings	(64)	(32)
Settlements	(1)	2
Derivative assets (liabilities), at fair value, net, end of period	22	(45)
Significant Unobservable Inputs (Level 3) | Commodity contract | Oil, natural gas and NGL sales
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Gains (loses) included in earnings	(64)	(32)
Change in unrealized gains (losses) related to assets still held at reporting date	(66)	(30)
Significant Unobservable Inputs (Level 3) | Future Natural Gas Prices | Utica Shale | Energy related derivative
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	7	0
Gains (loses) included in earnings	(7)	0
Settlements	0	0
Derivative assets (liabilities), at fair value, net, end of period	0	0
Significant Unobservable Inputs (Level 3) | Future Natural Gas Prices | Utica Shale | Energy related derivative | Oil, natural gas and NGL sales
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Gains (loses) included in earnings	(7)	0
Change in unrealized gains (losses) related to assets still held at reporting date	$ (7)	$ 0

Derivative and Hedging Activ_10

Derivative and Hedging Activities - Quantitative Disclosures Level 3 (Details) - Energy related derivative $ in Millions	Jun. 30, 2019USD ($)
Oil
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Fair value, measurement with unobservable inputs reconciliations, recurring basis, asset value	$ 23
Natural Gas
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Fair value, measurement with unobservable inputs reconciliations, recurring basis, liability value	$ (1)
Price volatility | Oil | Weighted average
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.2779
Price volatility | Oil | Minimum
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.2162
Price volatility | Oil | Maximum
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.3820
Price volatility | Natural Gas | Weighted average
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.3318
Price volatility | Natural Gas | Minimum
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.1994
Price volatility | Natural Gas | Maximum
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	1.4547

Derivative and Hedging Activ_11

Derivative and Hedging Activities - Narrative (Details) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2019USD ($)counterpartyderivative	Dec. 31, 2018USD ($)dayderivative$ / BTU
Derivative [Line Items]
Expected amount to be transferred of during the next 12 months	$ 34
Designated as Hedging Instrument
Derivative [Line Items]
Derivative, number of instruments held | derivative	0	0
Credit Risk
Derivative [Line Items]
Number of counterparties in hedge facility | counterparty	15
Disposal group, disposed of by sale, not discontinued operations | Utica Shale | Future Natural Gas Prices
Derivative [Line Items]
Disposal group, including discontinued operation, consideration		$ 100
Debt instrument, convertible, threshold trading days | day		20
Debt instrument, convertible, threshold consecutive trading days | day		30
Unrealized gain (loss)	$ (7)
2022 NYMEX Natural Gas | Disposal group, disposed of by sale, not discontinued operations | Utica Shale | Future Natural Gas Prices
Derivative [Line Items]
Disposal group, including discontinued operation, consideration		$ 50
2022 NYMEX Natural Gas | Disposal group, disposed of by sale, not discontinued operations | Utica Shale | Future Natural Gas Prices 2022
Derivative [Line Items]
Average sales prices (in dollars per mmbtu) | $ / BTU		3
2022 NYMEX Natural Gas | Disposal group, disposed of by sale, not discontinued operations | Utica Shale | Future Natural Gas Prices 2023
Derivative [Line Items]
Average sales prices (in dollars per mmbtu) | $ / BTU		3.25

Investments - Narrative (Detail

Investments - Narrative (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018
JWH Midstream LLC (JWH)
Schedule of Equity Method Investments [Line Items]
Business acquisition, percent acquired	50.00%	50.00%
Equity method investments			$ 17
Payments to terminate involvement in partnership	$ 7
Impairment expense	$ 24
FTS International, Inc.
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage	20.00%	20.00%		29.00%
Investment, realized gain (loss)		$ 61
Number of shares sold (in shares)		4.3
Proceeds from sale of equity method investments		$ 74
Shares held (in shares)	22	22
FTS International, Inc. | IPO
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage	24.00%	24.00%
Investment, realized gain (loss)		$ 78

Other Operating Expenses - Narr

Other Operating Expenses - Narrative (Details) - Wildhorse Resource Development Corporation $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)
Business Acquisition [Line Items]
Acquisition related costs	$ 26
Severance expense	$ 38

Restructuring and Other Termi_2

Restructuring and Other Termination Costs (Details) - USD ($) $ in Millions	Jan. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	[1]	Jun. 30, 2019	Jun. 30, 2018
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs, number of positions eliminated, period percent	13.00%
Restructuring and other termination costs		$ 0	$ 0		$ 0	$ 38	[1]
One-time termination benefits
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs						$ 38
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Table (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	$ (1)	$ (1)
Short-term derivative asset
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	44	50
Short-term derivative liability
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	(45)	(51)
Quoted Prices in Active Markets (Level 1)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	(1)	(1)
Quoted Prices in Active Markets (Level 1) | Short-term derivative asset
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	44	50
Quoted Prices in Active Markets (Level 1) | Short-term derivative liability
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	(45)	(51)
Significant Other Observable Inputs (Level 2)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	0	0
Significant Other Observable Inputs (Level 2) | Short-term derivative asset
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	0	0
Significant Other Observable Inputs (Level 2) | Short-term derivative liability
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	0	0
Significant Unobservable Inputs (Level 3)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	0	0
Significant Unobservable Inputs (Level 3) | Short-term derivative asset
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	0	0
Significant Unobservable Inputs (Level 3) | Short-term derivative liability
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	$ 0	$ 0

Condensed Consolidating Finan_3

Condensed Consolidating Financial Information - Narrative (Details)	Jun. 30, 2019
Owned subsidiaries | Senior notes
Condensed Financial Statements, Captions [Line Items]
Noncontrolling interest, ownership percentage by parent	100.00%

Condensed Consolidating Finan_4

Condensed Consolidating Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	[1]
CURRENT ASSETS:
Cash and cash equivalents	$ 4	$ 4
Other current assets	1,380	1,594
Intercompany receivable, net	0	0
Total Current Assets	1,384	1,598
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting, net	13,688	9,712
Other property and equipment, net	1,145	1,091
Property and equipment held for sale, net	12	15
Total Property and Equipment, Net	14,845	10,818
LONG-TERM ASSETS:
Other long-term assets	311	319
Investments in subsidiaries and intercompany advances	0	0
TOTAL ASSETS	16,540	12,735
CURRENT LIABILITIES:
Current liabilities	2,220	2,887
Intercompany payable, net	0	0
Total Current Liabilities	2,220	2,887
LONG-TERM LIABILITIES:
Long-term debt, net	9,701	7,341
Other long-term liabilities	389	374
Total Long-Term Liabilities	10,090	7,715
EQUITY:
Chesapeake stockholders’ equity	4,191	2,092
Noncontrolling interests	39	41
Total Equity	4,230	2,133	$ 1,689
TOTAL LIABILITIES AND EQUITY	16,540	12,735
Eliminations
CURRENT ASSETS:
Cash and cash equivalents	(8)	(2)
Other current assets	0	0
Intercompany receivable, net	(6,321)	(6,671)
Total Current Assets	(6,329)	(6,673)
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting, net	0	0
Other property and equipment, net	0	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	0	0
LONG-TERM ASSETS:
Other long-term assets	(287)	0
Investments in subsidiaries and intercompany advances	(8,320)	(3,257)
TOTAL ASSETS	(14,936)	(9,930)
CURRENT LIABILITIES:
Current liabilities	(8)	(2)
Intercompany payable, net	(6,321)	(6,671)
Total Current Liabilities	(6,329)	(6,673)
LONG-TERM LIABILITIES:
Long-term debt, net	0	0
Other long-term liabilities	(287)	0
Total Long-Term Liabilities	(287)	0
EQUITY:
Chesapeake stockholders’ equity	(8,320)	(3,257)
Noncontrolling interests	0	0
Total Equity	(8,320)	(3,257)
TOTAL LIABILITIES AND EQUITY	(14,936)	(9,930)
Parent | Reportable legal entities
CURRENT ASSETS:
Cash and cash equivalents	9	4
Other current assets	54	60
Intercompany receivable, net	6,321	6,671
Total Current Assets	6,384	6,735
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting, net	0	0
Other property and equipment, net	0	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	0	0
LONG-TERM ASSETS:
Other long-term assets	327	26
Investments in subsidiaries and intercompany advances	5,982	3,248
TOTAL ASSETS	12,693	10,009
CURRENT LIABILITIES:
Current liabilities	137	523
Intercompany payable, net	0	0
Total Current Liabilities	137	523
LONG-TERM LIABILITIES:
Long-term debt, net	8,311	7,341
Other long-term liabilities	54	53
Total Long-Term Liabilities	8,365	7,394
EQUITY:
Chesapeake stockholders’ equity	4,191	2,092
Noncontrolling interests	0	0
Total Equity	4,191	2,092
TOTAL LIABILITIES AND EQUITY	12,693	10,009
Guarantor Subsidiaries | Reportable legal entities
CURRENT ASSETS:
Cash and cash equivalents	1	1
Other current assets	1,229	1,532
Intercompany receivable, net	0	0
Total Current Assets	1,230	1,533
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting, net	9,556	9,664
Other property and equipment, net	1,061	1,091
Property and equipment held for sale, net	12	15
Total Property and Equipment, Net	10,629	10,770
LONG-TERM ASSETS:
Other long-term assets	247	293
Investments in subsidiaries and intercompany advances	2,338	9
TOTAL ASSETS	14,444	12,605
CURRENT LIABILITIES:
Current liabilities	1,841	2,365
Intercompany payable, net	6,321	6,671
Total Current Liabilities	8,162	9,036
LONG-TERM LIABILITIES:
Long-term debt, net	0	0
Other long-term liabilities	300	321
Total Long-Term Liabilities	300	321
EQUITY:
Chesapeake stockholders’ equity	5,982	3,248
Noncontrolling interests	0	0
Total Equity	5,982	3,248
TOTAL LIABILITIES AND EQUITY	14,444	12,605
Non-Guarantor Subsidiaries | Reportable legal entities
CURRENT ASSETS:
Cash and cash equivalents	2	1
Other current assets	97	2
Intercompany receivable, net	0	0
Total Current Assets	99	3
PROPERTY AND EQUIPMENT:
Oil and natural gas properties, at cost based on successful efforts accounting, net	4,132	48
Other property and equipment, net	84	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	4,216	48
LONG-TERM ASSETS:
Other long-term assets	24	0
Investments in subsidiaries and intercompany advances	0	0
TOTAL ASSETS	4,339	51
CURRENT LIABILITIES:
Current liabilities	250	1
Intercompany payable, net	0	0
Total Current Liabilities	250	1
LONG-TERM LIABILITIES:
Long-term debt, net	1,390	0
Other long-term liabilities	322	0
Total Long-Term Liabilities	1,712	0
EQUITY:
Chesapeake stockholders’ equity	2,338	9
Noncontrolling interests	39	41
Total Equity	2,377	50
TOTAL LIABILITIES AND EQUITY	$ 4,339	$ 51
[1]	Financial information for prior periods has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Condensed Consolidating Finan_5

Condensed Consolidating Financial Information - Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018		Jun. 30, 2019		Jun. 30, 2018
REVENUES AND OTHER:
Revenues	$ 2,386	$ 2,289	[1]	$ 4,582		$ 4,813	[1]
Gains on sales of assets	1	18	[1]	20		37	[1],[2]
OPERATING EXPENSES:
Production taxes	40	26	[1]	74		57	[1]
General and administrative	89	105	[1]	192		192	[1]
Restructuring and other termination costs	0	0	[1]	0		38	[1]
Provision for legal contingencies, net	3	4	[1]	3		9	[1]
Depreciation, depletion and amortization	580	471	[1]	1,099		930	[1],[2]
Impairments	1	54	[1]	2		64	[1],[2]
Other operating (income) expense	3	(1)	[1]	64		(1)	[1]
Total Operating Expenses	2,108	2,449	[1]	4,486		4,931	[1]
INCOME (LOSS) FROM OPERATIONS	278	(160)	[1]	96		(118)	[1]
OTHER INCOME (EXPENSE):
Interest expense	(175)	(155)	[1]	(336)	[1]	(317)	[1]
Gains (losses) on investments	(23)	0	[1]	(24)		139	[1]
Other income	18	57	[1]	27	[1]	56	[1]
Equity in net earnings of subsidiary	0	0		0		0
Total Other Expense	(180)	(98)	[1]	(333)	[1]	(122)	[1]
INCOME (LOSS) BEFORE INCOME TAXES	98	(258)	[1]	(237)	[1]	(240)	[1]
INCOME TAX (BENEFIT) EXPENSE	0	(9)	[1]	(314)	[1]	(9)	[1]
NET INCOME (LOSS)	98	(249)	[3]	77	[2],[3]	(231)	[2],[3]
Net income attributable to noncontrolling interests	0	0	[3]	0	[3]	(1)	[3]
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98	(249)	[1]	77	[1]	(232)	[1]
Other comprehensive income	8	7	[3]	18		17	[3]
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	106	(242)	[3]	95		(215)	[3]
Eliminations
REVENUES AND OTHER:
Revenues	0	0		0		0
Gains on sales of assets	0	0		0		0
OPERATING EXPENSES:
Production taxes	0	0		0		0
General and administrative	0	0		0		0
Restructuring and other termination costs						0
Provision for legal contingencies, net	0	0		0		0
Depreciation, depletion and amortization	0	0		0		0
Impairments	0	0		0		0
Other operating (income) expense	0	0		0		0
Total Operating Expenses	0	0		0		0
INCOME (LOSS) FROM OPERATIONS	0	0		0		0
OTHER INCOME (EXPENSE):
Interest expense	0	0		0		0
Gains (losses) on investments	0			0		0
Other income	0	0		0		0
Equity in net earnings of subsidiary	(291)	104		(14)		(76)
Total Other Expense	(291)	104		(14)		(76)
INCOME (LOSS) BEFORE INCOME TAXES	(291)	104		(14)		(76)
INCOME TAX (BENEFIT) EXPENSE	0	0		0		0
NET INCOME (LOSS)	(291)	104		(14)		(76)
Net income attributable to noncontrolling interests	0	0		0		0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(291)	104		(14)		(76)
Other comprehensive income	0	0		0		0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(291)	104		(14)		(76)
Parent | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
Gains on sales of assets	0	0		0		0
OPERATING EXPENSES:
Production taxes	0	0		0		0
General and administrative	0	0		0		0
Restructuring and other termination costs						0
Provision for legal contingencies, net	0	0		0		0
Depreciation, depletion and amortization	0	0		0		0
Impairments	0	0		0		0
Other operating (income) expense	0	0		0		0
Total Operating Expenses	0	0		0		0
INCOME (LOSS) FROM OPERATIONS	0	0		0		0
OTHER INCOME (EXPENSE):
Interest expense	(160)	(155)		(314)		(317)
Gains (losses) on investments	0			0		0
Other income	0	0		0		0
Equity in net earnings of subsidiary	281	(103)		104		76
Total Other Expense	121	(258)		(210)		(241)
INCOME (LOSS) BEFORE INCOME TAXES	121	(258)		(210)		(241)
INCOME TAX (BENEFIT) EXPENSE	23	(9)		(287)		(9)
NET INCOME (LOSS)	98	(249)		77		(232)
Net income attributable to noncontrolling interests	0	0		0		0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98	(249)		77		(232)
Other comprehensive income	0	0		0		0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98	(249)		77		(232)
Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	2,150	2,285		4,267		4,804
Gains on sales of assets	1	18		20		37
OPERATING EXPENSES:
Production taxes	30	26		58		57
General and administrative	65	104		150		191
Restructuring and other termination costs						38
Provision for legal contingencies, net	3	4		3		9
Depreciation, depletion and amortization	439	470		874		927
Impairments	1	54		2		64
Other operating (income) expense	3	(1)		26		(1)
Total Operating Expenses	1,900	2,445		4,108		4,924
INCOME (LOSS) FROM OPERATIONS	250	(160)		159		(120)
OTHER INCOME (EXPENSE):
Interest expense	5	0		10		0
Gains (losses) on investments	0			0		139
Other income	16	57		25		56
Equity in net earnings of subsidiary	10	0		(90)		1
Total Other Expense	31	57		(55)		196
INCOME (LOSS) BEFORE INCOME TAXES	281	(103)		104		76
INCOME TAX (BENEFIT) EXPENSE	0	0		0		0
NET INCOME (LOSS)	281	(103)		104		76
Net income attributable to noncontrolling interests	0	(1)		0		(1)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	281	(104)		104		75
Other comprehensive income	8	7		18		17
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	289	(97)		122		92
Non-Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	236	4		315		9
Gains on sales of assets	0	0		0		0
OPERATING EXPENSES:
Production taxes	10	0		16		0
General and administrative	24	1		42		1
Restructuring and other termination costs						0
Provision for legal contingencies, net	0	0		0		0
Depreciation, depletion and amortization	141	1		225		3
Impairments	0	0		0		0
Other operating (income) expense	0	0		38		0
Total Operating Expenses	208	4		378		7
INCOME (LOSS) FROM OPERATIONS	28	0		(63)		2
OTHER INCOME (EXPENSE):
Interest expense	(20)	0		(32)		0
Gains (losses) on investments	(23)			(24)		0
Other income	2	0		2		0
Equity in net earnings of subsidiary	0	(1)		0		(1)
Total Other Expense	(41)	(1)		(54)		(1)
INCOME (LOSS) BEFORE INCOME TAXES	(13)	(1)		(117)		1
INCOME TAX (BENEFIT) EXPENSE	(23)	0		(27)		0
NET INCOME (LOSS)	10	(1)		(90)		1
Net income attributable to noncontrolling interests	0	1		0		0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	10	0		(90)		1
Other comprehensive income	0	0		0		0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	10	0		(90)		1
Oil, natural gas and NGL
REVENUES AND OTHER:
Revenues	1,454	982	[1]	2,383		2,225	[1]
Oil, natural gas and NGL | Eliminations
REVENUES AND OTHER:
Revenues	0	0		0		0
Oil, natural gas and NGL | Parent | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
Oil, natural gas and NGL | Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	1,218	978		2,068		2,216
Oil, natural gas and NGL | Non-Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	236	4		315		9
Marketing
REVENUES AND OTHER:
Revenues	916	1,273	[1]	2,149		2,519	[1]
OPERATING EXPENSES:
Expense	940	1,292	[1]	2,170		2,560	[1]
Marketing | Eliminations
REVENUES AND OTHER:
Revenues	0	0		0		0
OPERATING EXPENSES:
Expense	0	0		0		0
Marketing | Parent | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
OPERATING EXPENSES:
Expense	0	0		0		0
Marketing | Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	916	1,273		2,149		2,519
OPERATING EXPENSES:
Expense	940	1,292		2,170		2,560
Marketing | Non-Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
OPERATING EXPENSES:
Expense	0	0		0		0
Oil, natural gas and NGL and Marketing
REVENUES AND OTHER:
Revenues	2,370	2,255	[1]	4,532		4,744	[1]
Oil, natural gas and NGL and Marketing | Eliminations
REVENUES AND OTHER:
Revenues	0	0		0		0
Oil, natural gas and NGL and Marketing | Parent | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
Oil, natural gas and NGL and Marketing | Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	2,134	2,251		4,217		4,735
Oil, natural gas and NGL and Marketing | Non-Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	236	4		315		9
Other
REVENUES AND OTHER:
Revenues	15	16	[1]	30		32	[1]
Other | Eliminations
REVENUES AND OTHER:
Revenues	0	0		0		0
Other | Parent | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
Other | Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	15	16		30		32
Other | Non-Guarantor Subsidiaries | Reportable legal entities
REVENUES AND OTHER:
Revenues	0	0		0		0
Oil, natural gas and NGL production
OPERATING EXPENSES:
Expense	166	138	[1]	298		285	[1]
Oil, natural gas and NGL production | Eliminations
OPERATING EXPENSES:
Expense	0	0		0		0
Oil, natural gas and NGL production | Parent | Reportable legal entities
OPERATING EXPENSES:
Expense	0	0		0		0
Oil, natural gas and NGL production | Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	138	138		255		285
Oil, natural gas and NGL production | Non-Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	28	0		43		0
Oil, natural gas and NGL gathering, processing and transportation
OPERATING EXPENSES:
Expense	271	340	[1]	545		696	[1]
Oil, natural gas and NGL gathering, processing and transportation | Eliminations
OPERATING EXPENSES:
Expense	0	0		0		0
Oil, natural gas and NGL gathering, processing and transportation | Parent | Reportable legal entities
OPERATING EXPENSES:
Expense	0	0		0		0
Oil, natural gas and NGL gathering, processing and transportation | Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	265	338		534		693
Oil, natural gas and NGL gathering, processing and transportation | Non-Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	6	2		11		3
Exploration
OPERATING EXPENSES:
Expense	15	20	[1]	39		101	[1]
Exploration | Eliminations
OPERATING EXPENSES:
Expense	0	0		0		0
Exploration | Parent | Reportable legal entities
OPERATING EXPENSES:
Expense	0	0		0		0
Exploration | Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	16	20		36		101
Exploration | Non-Guarantor Subsidiaries | Reportable legal entities
OPERATING EXPENSES:
Expense	$ (1)	$ 0		$ 3		$ 0
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[2]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .
[3]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .

Condensed Consolidating Finan_6

Condensed Consolidating Financial Information - Statements of Cash Flows (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	$ 853	$ 951	[1]
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(1,070)	(928)	[1]
Business combination, net	(353)	0	[1]
Acquisitions of proved and unproved properties	(17)	(102)	[1]
Proceeds from divestitures of proved and unproved properties	82	384	[1]
Additions to other property and equipment	(18)	(5)	[1]
Other investing activities	4	148
Net Cash Used In Investing Activities	(1,372)	(503)	[1]
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	6,416	6,118	[1]
Payments on revolving credit facility borrowings	(5,452)	(6,393)	[1]
Cash paid to purchase debt	(381)	0	[1]
Cash paid for preferred stock dividends	(46)	(46)	[1]
Other financing activities	(18)	(129)
Intercompany advances, net	0	0
Net Cash Provided By (Used In) Financing Activities	519	(450)	[1]
Net decrease in cash and cash equivalents	0	(2)	[1]
Cash and cash equivalents, beginning of period	4	5	[1]
Cash and cash equivalents, end of period	4	3	[1]
Eliminations
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	(2)	(8)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	0	0
Business combination, net	0
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	0	0
Other investing activities	0	0
Net Cash Used In Investing Activities	0	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	0	0
Payments on revolving credit facility borrowings	0	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0	0
Other financing activities	2	6
Intercompany advances, net	0	0
Net Cash Provided By (Used In) Financing Activities	2	6
Net decrease in cash and cash equivalents	0	(2)
Cash and cash equivalents, beginning of period	(2)	(3)
Cash and cash equivalents, end of period	(2)	(5)
Parent | Reportable legal entities
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	0	88
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	0	0
Business combination, net	0
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	0	0
Other investing activities	0	0
Net Cash Used In Investing Activities	0	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	6,119	6,118
Payments on revolving credit facility borrowings	(5,166)	(6,393)
Cash paid to purchase debt	(381)
Cash paid for preferred stock dividends	(46)	(46)
Other financing activities	(12)	(2)
Intercompany advances, net	(515)	235
Net Cash Provided By (Used In) Financing Activities	(1)	(88)
Net decrease in cash and cash equivalents	(1)	0
Cash and cash equivalents, beginning of period	4	5
Cash and cash equivalents, end of period	3	5
Guarantor Subsidiaries | Reportable legal entities
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	613	866
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(805)	(928)
Business combination, net	(381)
Acquisitions of proved and unproved properties	(17)	(102)
Proceeds from divestitures of proved and unproved properties	82	384
Additions to other property and equipment	(7)	(5)
Other investing activities	4	148
Net Cash Used In Investing Activities	(1,124)	(503)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	0	0
Payments on revolving credit facility borrowings	0	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0	0
Other financing activities	(4)	(126)
Intercompany advances, net	515	(237)
Net Cash Provided By (Used In) Financing Activities	511	(363)
Net decrease in cash and cash equivalents	0	0
Cash and cash equivalents, beginning of period	1	1
Cash and cash equivalents, end of period	1	1
Non-Guarantor Subsidiaries | Reportable legal entities
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	242	5
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(265)	0
Business combination, net	28
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	(11)	0
Other investing activities	0	0
Net Cash Used In Investing Activities	(248)	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	297	0
Payments on revolving credit facility borrowings	(286)	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0	0
Other financing activities	(4)	(7)
Intercompany advances, net	0	2
Net Cash Provided By (Used In) Financing Activities	7	(5)
Net decrease in cash and cash equivalents	1	0
Cash and cash equivalents, beginning of period	1	2
Cash and cash equivalents, end of period	$ 2	$ 2
[1]	Financial information for 2018 has been recast to reflect the retrospective application of the successful efforts method of accounting. See Note 1 .