Expand Energy (EXE) 10-Q 2 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Oct. 31, 2017
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q3
Trading Symbol	CHK
Entity Registrant Name	CHESAPEAKE ENERGY CORPORATION
Entity Central Index Key	895,126
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		908,685,855

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents ($1 and $1 attributable to our VIE)	$ 5	$ 882
Accounts receivable, net	992	1,057
Short-term derivative assets	28	0
Other current assets	153	203
Total Current Assets	1,178	2,142
Oil and natural gas properties, at cost based on full cost accounting:
Proved oil and natural gas properties ($488 and $488 attributable to our VIE)	68,095	66,451
Unproved properties	3,838	4,802
Other property and equipment	2,004	2,053
Total Property and Equipment, at Cost	73,937	73,306
Less: accumulated depreciation, depletion and amortization (($460) and ($458) attributable to our VIE)	(63,375)	(62,726)
Property and equipment held for sale, net	18	29
Total Property and Equipment, Net	10,580	10,609
LONG-TERM ASSETS:
Other long-term assets	223	277
TOTAL ASSETS	11,981	13,028
CURRENT LIABILITIES:
Accounts payable	678	672
Current maturities of long-term debt, net	0	503
Accrued interest	135	113
Short-term derivative liabilities	8	562
Other current liabilities ($4 and $3 attributable to our VIE)	1,397	1,798
Total Current Liabilities	2,218	3,648
LONG-TERM LIABILITIES:
Long-term debt, net	9,899	9,938
Long-term derivative liabilities	11	15
Asset retirement obligations, net of current portion	197	247
Other long-term liabilities	360	383
Total Long-Term Liabilities	10,467	10,583
CONTINGENCIES AND COMMITMENTS (Note 4)
Chesapeake Stockholders’ Equity:
Preferred stock, $0.01 par value, 20,000,000 shares authorized: 5,603,458 and 5,839,506 shares outstanding	1,671	1,771
Common stock, $0.01 par value, 2,000,000,000 and 1,500,000,000 shares authorized: 908,662,243 and 896,279,353 shares issued	9	9
Additional paid-in capital	14,449	14,486
Accumulated deficit	(16,987)	(17,603)
Accumulated other comprehensive loss	(67)	(96)
Less: treasury stock, at cost; 2,323,475 and 1,220,504 common shares	(32)	(27)
Total Chesapeake Stockholders’ Equity (Deficit)	(957)	(1,460)
Noncontrolling interests	253	257
Total Equity (Deficit)	(704)	(1,203)
TOTAL LIABILITIES AND EQUITY	$ 11,981	$ 13,028

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
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	5,839,506
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common Stock, Shares Authorized	2,000,000,000	1,500,000,000
Common stock, shares issued	908,662,243	896,279,353
Treasury stock, common shares	2,323,475	1,220,504
VIE, cash and cash equivalents	$ 5	$ 882
VIE. proved oil and natural gas properties	68,095	66,451
VIE. accumulated depreciation, depletion and amortization	(63,375)	(62,726)
VIE. other current liabilities	1,397	1,798
Variable Interest Entities, Primary Beneficiary [Member]
VIE, cash and cash equivalents	1	1
VIE. proved oil and natural gas properties	488	488
VIE. accumulated depreciation, depletion and amortization	(460)	(458)
VIE. other current liabilities	$ 4	$ 3

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
REVENUES:
Oil, natural gas and NGL	$ 979	$ 1,177	$ 3,727	$ 2,610
Marketing, gathering and compression	964	1,099	3,250	3,241
Total Revenues	1,943	2,276	6,977	5,851
OPERATING EXPENSES:
Oil, natural gas and NGL production	151	164	426	552
Oil, natural gas and NGL gathering, processing and transportation	369	473	1,081	1,436
Production taxes	21	17	64	54
Marketing, gathering and compression	978	1,261	3,333	3,410
General and administrative	54	63	189	172
Restructuring and other termination costs	0	0	0	3
Provision for legal contingencies	20	8	35	112
Oil, natural gas and NGL depreciation, depletion and amortization	228	251	627	791
Depreciation and amortization of other assets	20	25	62	83
Impairment of oil and natural gas properties	0	497	0	2,564
Impairments of fixed assets and other	9	751	426	795
Net gains on sales of fixed assets	(1)	0	0	(5)
Total Operating Expenses	1,849	3,510	6,243	9,967
INCOME (LOSS) FROM OPERATIONS	94	(1,234)	734	(4,116)
OTHER INCOME (EXPENSE):
Interest expense	(114)	(73)	(302)	(197)
Losses on investments	0	(1)	0	(3)
Loss on sale of investment	0	0	0	(10)
Gains (losses) on purchases or exchanges of debt	(1)	87	183	255
Other income	4	7	6	13
Total Other Income (Expense)	(111)	20	(113)	58
INCOME (LOSS) BEFORE INCOME TAXES	(17)	(1,214)	621	(4,058)
Income Tax Expense	0	0	2	0
NET INCOME (LOSS)	(17)	(1,214)	619	(4,058)
Net income attributable to noncontrolling interests	(1)	(1)	(3)	(1)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(18)	(1,215)	616	(4,059)
Preferred stock dividends	(23)	(42)	(62)	(127)
Loss on exchange of preferred stock	0	0	(41)	0
Earnings allocated to participating securities	0	0	(7)	0
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ (41)	$ (1,257)	$ 506	$ (4,186)
EARNINGS (LOSS) PER COMMON SHARE:
Earnings Per Share, Basic	$ (0.05)	$ (1.62)	$ 0.56	$ (5.80)
Earnings Per Share, Diluted	$ (0.05)	$ (1.62)	$ 0.56	$ (5.80)
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Weighted Average Number of Shares Outstanding, Basic	909	777	908	722
Weighted Average Number of Shares Outstanding, Diluted	909	777	908	722

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
NET INCOME (LOSS)	$ (17)	$ (1,214)	$ 619	$ (4,058)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF INCOME TAX:
Unrealized gains (losses) on derivative instruments, net of income tax expense (benefit) of $0, $0, $0 and ($1)	0	(4)	4	(23)
Reclassification of losses on settled derivative instruments, net of income tax expense (benefit) of $0, $0, $0 and $3	8	7	25	21
Other Comprehensive Income (Loss)	8	3	29	(2)
COMPREHENSIVE INCOME (LOSS)	(9)	(1,211)	648	(4,060)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	(1)	(1)	(3)	(1)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	$ (10)	$ (1,212)	$ 645	$ (4,061)

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income tax expense (benefit) of $0,$0, $0 and ($1) on unrealized gains (losses) on derivative instruments	$ 0	$ 0	$ 0	$ (1)
Income tax expense (benefit) of $0, $0, $0 and $3 on reclassification of losses on settled derivative instruments	$ 0	$ 0	$ 0	$ 3

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
CASH FLOWS FROM OPERATING ACTIVITIES:
NET INCOME (LOSS)	$ 619	$ (4,058)
ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES:
Depreciation, depletion and amortization	689	874
Derivative (gains) losses, net	(452)	283
Cash receipts (payments) on derivative settlements, net	(46)	487
Stock-based compensation	38	40
Impairment of oil and natural gas properties	0	2,564
Net gains on sales of fixed assets	0	(5)
Renegotiation of natural gas gathering contract	0	(66)
Impairments of fixed assets and other	9	785
Losses on investments	0	3
Loss on sale of investment	0	10
Gains on purchases or exchanges of debt	(185)	(255)
Restructuring and other termination costs	0	1
Provision for legal contingencies	35	77
Other	(68)	(76)
Changes in assets and liabilities	(366)	(614)
Net Cash Provided By Operating Activities	273	50
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(1,597)	(948)
Acquisitions of proved and unproved properties	(226)	(583)
Proceeds from divestitures of proved and unproved properties	1,193	988
Additions to other property and equipment	(12)	(32)
Proceeds from sales of other property and equipment	40	70
Cash paid for title defects	0	(69)
Other	0	(5)
Net Cash Used In Investing Activities	(602)	(579)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	4,775	5,097
Payments on revolving credit facility borrowings	(4,130)	(4,857)
Proceeds from issuance of senior notes, net	742	0
Proceeds from issuance of term loan	0	1,500
Cash paid to purchase debt	(1,751)	(1,979)
Cash paid for preferred stock dividends	(160)	0
Distributions to noncontrolling interest owners	(7)	(8)
Other	(17)	(45)
Net Cash Used In Financing Activities	(548)	(292)
Net decrease in cash and cash equivalents	(877)	(821)
Cash and cash equivalents, beginning of period	882	825
Cash and cash equivalents, end of period	5	4
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid, net of capitalized interest	342	209
Income tax refunds received, net	(15)	(20)
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Debt exchanged for common stock	0	471
Change In Accrued Drilling And Completion Costs [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	134	(22)
Change In Accrued Acquisitions Of Proved And Unproved Properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	(1)	(1)
Change In Divested Proved And Unproved Properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	$ (23)	$ 12

CONDENSED CONSOLIDATED STATEME8

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	Preferred Stock [Member]	Preferred Stock [Member]Preferred Stock, Exchanged for Shares of Common Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]	Additional Paid-in Capital [Member]Senior Notes Exchanged for Shares of Common Stock [Member]	Additional Paid-in Capital [Member]Preferred Stock, Exchanged for Shares of Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Stock - Common [Member]	Parent [Member]	Noncontrolling Interest [Member]
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2015		$ 3,062		$ 7	$ 12,403				$ (13,202)	$ (99)	$ (33)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock repurchased during period, value			$ (26)
Stock issued during period, value, conversion of convertible securities				1
Stock-based compensation					49
Convertible notes exchanged, value						$ 241	$ 229
Exchange of preferred stock for shares of common stock								$ 26
Equity component of contingent convertible notes repurchased					(25)
Dividends on preferred stock					0
Net income (loss) attributable to Chesapeake	$ (4,059)								(4,059)
Hedging activity										(2)
Purchase of 1,194,986 and 33,955 shares for company benefit plans											0
Release of 92,015 and 182,092 shares from company benefit plans											4
Chesapeake stockholders’ equity, end of period at Sep. 30, 2016		3,036		8	12,923				(17,261)	(101)	(29)	$ (1,424)
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2015													$ 259
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	1												1
Distributions to noncontrolling interest owners													(1)
Stockholders' equity attributable to noncontrolling interest, end of period at Sep. 30, 2016													259
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	(1,165)
TOTAL EQUITY (DEFICIT)	(1,203)
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2016	(1,460)	1,771		9	14,486				(17,603)	(96)	(27)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock repurchased during period, value			$ (100)
Stock issued during period, value, conversion of convertible securities				0
Stock-based compensation					43
Convertible notes exchanged, value						$ 0	$ 0
Exchange of preferred stock for shares of common stock								$ 100
Equity component of contingent convertible notes repurchased					(20)
Dividends on preferred stock					(160)
Net income (loss) attributable to Chesapeake	616								616
Hedging activity										29
Purchase of 1,194,986 and 33,955 shares for company benefit plans											(7)
Release of 92,015 and 182,092 shares from company benefit plans											2
Chesapeake stockholders’ equity, end of period at Sep. 30, 2017	(957)	$ 1,671		$ 9	$ 14,449				$ (16,987)	$ (67)	$ (32)	$ (957)
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2016	257												257
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	3												3
Distributions to noncontrolling interest owners													(7)
Stockholders' equity attributable to noncontrolling interest, end of period at Sep. 30, 2017	253												$ 253
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	$ (704)

CONDENSED CONSOLIDATED STATEME9

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - shares	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Treasury Stock - Common [Member]
Purchase of shares for company benefit plans, shares	1,194,986	33,955
Release of shares from company benefit plans, shares	92,015	182,092
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Preferred Stock [Member]
Conversion of Stock, Shares Converted	236,048	25,802
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	9,965,835	1,021,506
Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	55,427,782
Senior Notes Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	53,923,925

Basis of Presentation (Notes)

Basis of Presentation (Notes)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies Disclosure	Basis of Presentation The accompanying condensed consolidated financial statements of Chesapeake Energy Corporation (“Chesapeake” or the “Company”) were prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) and include the accounts of our direct and indirect wholly owned subsidiaries and entities in which Chesapeake has a controlling financial interest. Intercompany accounts and balances have been eliminated. These financial statements were prepared in accordance with the instructions to Form 10-Q and, therefore, do not include all disclosures required for financial statements prepared in conformity with U.S. GAAP. This Form 10-Q relates to the three and nine months ended September 30, 2017 (the “Current Quarter” and the “Current Period”, respectively) and the three and nine months ended September 30, 2016 (the “Prior Quarter” and the “Prior Period”, respectively). Chesapeake’s annual report on Form 10-K for the year ended December 31, 2016 (“2016 Form 10-K”) includes certain definitions and a summary of significant accounting policies and should be read in conjunction with this Form 10-Q. All material adjustments (consisting solely of normal recurring adjustments) which, in the opinion of management, are necessary for a fair statement of the results for the interim periods have been reflected. The results for the Current Quarter and the Current Period are not necessarily indicative of the results to be expected for the full year. Revision of Previously Reported Condensed Consolidated Financial Statements During the fourth quarter of 2016, we identified certain errors to the basis price differentials used in calculating the impairment of oil and natural gas properties and oil, natural gas and NGL depreciation, depletion and amortization for each of the first three interim periods in 2016. As disclosed within our 2016 Form 10-K, it was determined that these errors were not material to our previously issued 2016 interim financial statements. Accordingly, the correction of these errors was reflected in the quarterly unaudited financial data included within our 2016 Form 10-K. These revisions have been reflected in the comparative 2016 condensed consolidated financi al statements presented herein. See Evaluation of Disclosure Controls and Procedure s in Item 4 of this Form 10-Q. The following table reconciles the amounts as previously reported in the applicable financial statement to the corresponding revised amounts: Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Revision Adjustment As Revised ($ in millions except per share data) Oil, natural gas and NGL depreciation, depletion and amortization $ 255 $ (4 ) $ 251 Impairment of oil and natural gas properties $ 433 $ 64 $ 497 Total operating expenses $ 3,450 $ 60 $ 3,510 Loss from operations $ (1,174 ) $ (60 ) $ (1,234 ) Loss before income taxes $ (1,154 ) $ (60 ) $ (1,214 ) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Net loss attributable to Chesapeake $ (1,155 ) $ (60 ) $ (1,215 ) Net loss available to common stockholders $ (1,197 ) $ (60 ) $ (1,257 ) Loss per common share basic $ (1.54 ) $ (0.08 ) $ (1.62 ) Loss per common share diluted $ (1.54 ) $ (0.08 ) $ (1.62 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 Total operating expenses $ 9,734 $ 233 $ 9,967 Loss from operations $ (3,883 ) $ (233 ) $ (4,116 ) Loss before income taxes $ (3,825 ) $ (233 ) $ (4,058 ) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Net loss attributable to Chesapeake $ (3,826 ) $ (233 ) $ (4,059 ) Net loss available to common stockholders $ (3,953 ) $ (233 ) $ (4,186 ) Loss per common share basic $ (5.47 ) $ (0.33 ) $ (5.80 ) Loss per common share diluted $ (5.47 ) $ (0.33 ) $ (5.80 ) Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564

Earnings Per Share (Notes)

Earnings Per Share (Notes)	9 Months Ended
	Sep. 30, 2017
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Earnings Per Share Disclosure	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 contingent convertible senior notes did not have a dilutive effect and therefore were excluded from the calculation of diluted EPS. See Note 3 for further discussion of our convertible senior notes and contingent convertible senior notes. Shares of common stock for the following dilutive securities were excluded from the calculation of diluted EPS as the effect was antidilutive. Three Months Ended Nine Months Ended 2017 2016 2017 2016 (in millions) Common stock equivalent of our preferred stock outstanding 60 112 60 112 Common stock equivalent of our convertible senior notes outstanding 146 — 146 — Participating securities — 1 1 1

Debt (Notes)

Debt (Notes)	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Debt Disclosure	Debt Our long-term debt consisted of the following as of September 30, 2017 and December 31, 2016: September 30, 2017 December 31, 2016 Principal Amount Carrying Principal Carrying ($ in millions) Term loan due 2021 $ 1,500 $ 1,500 $ 1,500 $ 1,500 6.25% euro-denominated senior notes due 2017 (a) — — 258 258 6.5% senior notes due 2017 — — 134 134 7.25% senior notes due 2018 44 44 64 64 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 572 572 780 780 6.875% senior notes due 2020 279 278 279 278 6.125% senior notes due 2021 550 550 550 550 5.375% senior notes due 2021 270 270 270 270 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 (b) 1,737 2,355 2,419 3,409 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,000 987 1,000 985 5.5% convertible senior notes due 2026 (c)(d) 1,250 831 1,250 811 8.00% senior notes due 2027 750 750 — — 2.75% contingent convertible senior notes due 2035 — — 2 2 2.5% contingent convertible senior notes due 2037 (d) — — 114 112 2.25% contingent convertible senior notes due 2038 (d) 9 8 200 180 Revolving credit facility 645 645 — — Debt issuance costs — (62 ) — (64 ) Interest rate derivatives (e) — 2 — 3 Total debt, net 9,775 9,899 9,989 10,441 Less current maturities of long-term debt, net — — (506 ) (503 ) Total long-term debt, net (f) $ 9,775 $ 9,899 $ 9,483 $ 9,938 ___________________________________________ (a) The principal and carrying amounts shown are based on the exchange rate of $1.0517 to €1.00 as of December 31, 2016. See Foreign Currency Derivatives in Note 8 for information on our related foreign currency derivatives. (b) The carrying amounts as of September 30, 2017 and December 31, 2016, include premium amounts of $618 million and $990 million , respectively, associated with a troubled debt restructuring. The premium is being amortized based on the effective yield method. (c) The conversion and redemption provisions of our convertible senior notes are as follows: Optional Conversion by Holders . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible into cash, our common stock, or a combination of cash and common stock, at our election. One triggering circumstance is when the price of our common stock exceeds a threshold amount during a specified period in a fiscal quarter. Convertibility based on common stock price is measured quarterly. During the Current Quarter, the price of our common stock was below the threshold level and, as a result, the holders do not have the option to convert their notes in the fourth quarter of 2017 under this provision. The notes are also convertible, at the holder’s option, during specified five-day periods if the trading price of the notes is below certain levels determined by reference to the trading price of our common stock. The notes were not convertible under this provision during the Current Quarter. Upon conversion of a convertible senior note, the holder will receive cash, common stock or a combination of cash and common stock, at our election, according to the conversion rate specified in the indenture. The common stock price conversion threshold amount for the convertible senior notes is 130% of the conversion price of $8.568 . Optional Redemption by the Company . We may redeem the convertible senior notes for cash on or after September 15, 2019 , if the price of our common stock exceeds 130% of the conversion price during a specified period at a redemption price of 100% of the principal amount of the notes. Holders’ Demand Repurchase Rights. The holders of our convertible senior notes may require us to repurchase, in cash, all or a portion of their notes at 100% of the principal amount of the notes upon certain fundamental changes. (d) The carrying amounts as of September 30, 2017 and December 31, 2016, are reflected net of discounts of $420 million and $461 million , respectively, associated with the equity component of our convertible and contingent convertible senior notes. This amount is being amortized based on the effective yield method through the first demand repurchase date as applicable. (e) See Interest Rate Derivatives in Note 8 for further discussion related to these instruments. (f) See Note 16 for information regarding debt transactions subsequent to September 30, 2017 . Debt Issuances and Retirements During the Current Period, we issued in a private placement $750 million aggregate principal amount of unsecured 8.00% Senior Notes due 2027 at par for net proceeds of approximately $742 million . Some or all of the notes may be redeemed at any time prior to June 15, 2022, subject to a make-whole premium. We also may redeem some or all of the notes at any time on or after June 15, 2022, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes . In addition, subject to certain conditions, we may redeem up to 35% of the aggregate principal amount of the notes at any time prior to June 15, 2020 , at a price equal to 108% of the principal amount of the notes to be redeemed using the net proceeds of certain equity offerings. In the Current Period, we retired $1.609 billion principal amount of our outstanding senior notes, senior secured second lien notes and contingent convertible notes through purchases in the open market, tender offers or repayment upon maturity for $1.751 billion . For the open market repurchases and tender offers, we recorded an aggregate loss of approximately $1 million in the Current Quarter and an aggregate gain of approximately $183 million in the Current Period including $260 million of premium associated with our 8.00% Senior Secured Second Lien Notes due 2022. In the Prior Period, we retired $2.192 billion principal amount of our outstanding senior notes and contingent convertible senior notes through purchases in the open market, tender offers or repayment upon maturity for $1.5 billion . Additionally, we privately negotiated an exchange of approximately $577 million principal amount of our outstanding senior notes and contingent convertible senior notes for 109,351,707 common shares. We recorded an aggregate gain of approximately $255 million associated with these repurchases and exchanges. Term Loan Facility We have a secured five -year term loan facility in an aggregate principal amount of $1.5 billion as of September 30, 2017 . Our obligations under the facility are unconditionally guaranteed on a joint and several basis by the same subsidiaries that guarantee our revolving credit facility, second lien notes and senior notes and are secured by first-priority liens on the same collateral securing our revolving credit facility (with a position in the collateral proceeds waterfall junior to the revolving credit facility). The term loan bears interest at a rate of London Interbank Offered Rate (LIBOR) plus 7.50% per annum, subject to a 1.00% LIBOR floor, or the Alternative Base Rate (ABR) plus 6.50% per annum, subject to a 2.00% ABR floor, at our option. The term loan matures in August 2021 and voluntary prepayments are subject to a make-whole premium prior to the second anniversary of the closing of the term loan, a premium to par of 4.25% from the second anniversary until but excluding the third anniversary, a premium to par of 2.125% from the third anniversary until but excluding the fourth anniversary and at par beginning on the fourth anniversary. The term loan may be subject to mandatory prepayments and offers to purchase with net cash proceeds of certain issuances of debt, certain asset sales and other dispositions of collateral and upon a change of control. Senior Secured Second Lien Notes Our second lien notes are secured second lien obligations and are effectively junior to our current and future secured first lien indebtedness, including indebtedness incurred under our revolving credit facility and our term loan facility, to the extent of the value of the collateral securing such indebtedness, effectively senior to all of our existing and future unsecured indebtedness, including our outstanding senior notes, to the extent of the value of the collateral, and senior to any future subordinated indebtedness that we may incur. We have the option to redeem the second lien notes, in whole or in part, at specified make-whole or redemption prices. Our second lien notes are governed by an indenture containing covenants that may limit our ability and our subsidiaries’ ability to create liens securing certain indebtedness, enter into certain sale-leaseback transactions, consolidate, merge or transfer assets and dispose of certain collateral and use proceeds from dispositions of certain collateral. As a holding company, Chesapeake owns no operating assets and has no significant operations independent of its subsidiaries. Chesapeake’s obligations under the second lien notes are fully and unconditionally guaranteed, jointly and severally, by certain of our direct and indirect wholly owned subsidiaries. In December 2015, certain of the existing notes that were exchanged for the second lien notes were accounted for as a troubled debt restructuring (TDR). For the exchanges classified as a TDR, if the future undiscounted cash flows of the newly issued debt are less than the net carrying value of the original debt, a gain is recorded for the difference and the carrying value of the newly issued debt is adjusted to the future undiscounted cash flow amount and no future interest expense is recorded. All future interest payments on the newly issued debt reduce the carrying value. Senior Notes, Contingent Convertible Senior Notes and Convertible Senior Notes Our obligations under our outstanding senior notes and convertible senior notes are fully and unconditionally guaranteed, jointly and severally, by certain of our 100% owned subsidiaries on a senior unsecured basis. Our non-guarantor subsidiaries are minor and, as such, we have not included condensed consolidating financial information in the notes to our condensed consolidated financial statements. We are required to account for the liability and equity components of our convertible debt instruments 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 rates for our 2.25% Contingent Convertible Senior Notes due 2038 and our 5.5% Convertible Senior Notes due 2026 are 8.0% and 11.5% , respectively. Revolving Credit Facility We have a senior secured revolving credit facility currently subject to a $3.8 billion borrowing base that matures in December 2019. Our borrowing base may be reduced in certain circumstances, including if we dispose of a certain percentage of the value of collateral securing the revolving credit facility. As of September 30, 2017 , we had outstanding borrowings of $645 million under the revolving credit facility and had used $97 million of the revolving credit facility for various letters of credit. Borrowings under the revolving credit facility bear interest at a variable rate. The terms of the revolving credit facility include covenants limiting, among other things, our ability to incur additional indebtedness, make investments or loans, create liens, consummate mergers and similar fundamental changes, make restricted payments, make investments in unrestricted subsidiaries and enter into transactions with affiliates. As of September 30, 2017 , we were in compliance with all applicable financial covenants under the agreement and we were able to borrow the full availability under the revolving credit facility. As discussed in Note 16, on October 30, 2017, we completed a scheduled borrowing base redetermination review and our lenders reaffirmed our $3.8 billion borrowing base. Our next scheduled borrowing base redetermination is scheduled for the second quarter of 2018. During 2016, we entered into the third amendment to our revolving credit facility. The amendment granted temporary financial covenant relief, with the revolving credit facility’s existing first lien secured leverage ratio and net debt to capitalization ratio suspended until September 30, 2017 (at which point the maximum first lien secured leverage ratio became 3.50 to 1.0 through the period ending December 31, 2017 and 3.00 to 1.0 thereafter and the maximum net debt to capitalization ratio for each period will be 65% ) and the interest coverage ratio maintenance covenant reduced as noted below. In addition, we agreed to grant liens and security interests on a majority of our assets, as well as maintain a minimum liquidity amount (defined as cash and cash equivalents and availability under our revolving credit facility) of $500 million until the suspension of the existing maintenance covenants ends. The third amendment increased the interest coverage ratio to 1.2 to 1.0 for the third quarter of 2017 and 1.25 to 1.0 thereafter. The amendment also gives us the ability to incur up to $2.5 billion of first lien indebtedness secured on a pari passu basis with the existing obligations under the credit agreement, subject to a position in the collateral proceeds waterfall in favor of the revolving lenders and affiliated hedge providers and the other limitations on junior lien debt set forth in the credit agreement. After taking into account the term loan repurchases discussed in Note 16, the amount of additional first lien indebtedness permitted by the revolving credit facility is $1.2 billion . Fair Value of Debt We estimate the fair value of our senior notes based on the market value of our publicly traded debt as determined based on the yield of our senior notes (Level 1). The fair value of all other debt is based on a market approach using estimates provided by an independent investment financial data services firm (Level 2). Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below. September 30, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ — $ — $ 503 $ 511 Long-term debt (Level 1) $ 2,876 $ 2,861 $ 3,271 $ 3,216 Long-term debt (Level 2) $ 7,021 $ 7,035 $ 6,664 $ 6,654

Contingencies and Commitments (

Contingencies and Commitments (Notes)	9 Months Ended
	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies Litigation and Regulatory Proceedings The Company is 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. We estimate and provide for potential losses that may arise out of litigation and regulatory proceedings to the extent that such losses are probable and can be reasonably estimated. Significant judgment is required in making these estimates and our final liabilities may ultimately be materially different. 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. We account for legal defense costs in the period the costs are incurred. Regulatory and Related Proceedings. The Company has received DOJ, U.S. Postal Service and state subpoenas seeking information on the Company’s royalty payment practices. On September 19, 2017, the DOJ informed Chesapeake that it had concluded its investigation with no action taken on these matters and matters related to the purchase and lease of oil and natural gas rights. Chesapeake has engaged in discussions with the U.S. Postal Service and state agency representatives and continues to respond to related subpoenas and demands. On July 10, 2017, Chesapeake, its Benefits Committee, its Investment Committee and certain employees were named as defendants in a purported Employee Retirement Income Security Act of 1974 (ERISA) class action filed in the United States District Court for the Western District of Oklahoma (the “ERISA Lawsuit”). The ERISA Lawsuit alleges violations of Sections 404, 405, 409 and 502 of ERISA with respect to the Company’s common stock held in its Savings and Incentive Stock Bonus Plan (the “Plan”). The lawsuit was dismissed on August 8, 2017. Business Operations. Chesapeake is involved in various other lawsuits and disputes incidental to its business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions. Regarding royalty claims, Chesapeake and other natural gas producers have been named in various lawsuits alleging royalty underpayment. The suits against us allege, among other things, that we used below-market prices, made improper deductions, used improper measurement techniques and/or entered into arrangements with affiliates that resulted in underpayment of royalties in connection with the production and sale of natural gas and NGL. Plaintiffs have varying royalty 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. The Company has resolved a number of these claims through negotiated settlements of past and future royalties and has prevailed in various other lawsuits. We are currently defending lawsuits seeking damages with respect to underpayment of royalties in various states, including, but not limited to, Texas, Pennsylvania, Ohio, Oklahoma, Kentucky, Louisiana and Arkansas. These lawsuits include cases filed by individual royalty owners and putative class actions, some of which seek to certify a statewide class. Chesapeake is defending numerous lawsuits filed by individual royalty owners alleging royalty underpayment with respect to properties in Texas. These lawsuits, organized for pre-trial proceedings with respect to the Barnett Shale and Eagle Ford Shale, respectively, generally allege that Chesapeake underpaid royalties by making improper deductions, using incorrect production volumes and similar theories. Chesapeake expects that additional lawsuits will continue to be pursued and that new plaintiffs will file other lawsuits making similar allegations. 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 Chesapeake 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 Chesapeake is a party established unlawful market allocation for the acquisition of leases. The lawsuit seeks statutory restitution, civil penalties and costs, as well as 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 Company’s divestiture of substantially all of its midstream business and most of its 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. One of the cases includes claims of intentional interference with contractual relations and violations of antitrust laws related to purported markets for gas mineral rights, operating rights and gas gathering sources. 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. The Company is also defending lawsuits alleging various violations of the Sherman Antitrust Act and state antitrust laws. In 2016, putative class action lawsuits were filed in the U.S. District Court for the Western District of Oklahoma and in Oklahoma state courts, and an individual lawsuit was filed in the U.S. District Court of Kansas, in each case against the Company and other defendants. The lawsuits generally allege that, since 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 lawsuits seek 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 lawsuits. Other Matters Based on management’s current assessment, we are of the opinion that no pending or threatened lawsuit or dispute relating to the Company’s business operations is likely to have a material adverse effect on its 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. Environmental Contingencies The nature of the oil and gas business carries with it certain environmental risks for Chesapeake and its subsidiaries. Chesapeake has implemented various policies, programs, procedures, training and audits to reduce and mitigate such environmental risks. Chesapeake conducts 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, Chesapeake 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
Commitments	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. 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. September 30, ($ in millions) 2017 $ 331 2018 1,096 2019 1,062 2020 990 2021 894 2022 – 2035 5,214 Total $ 9,587 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. Drilling Contracts We have contracts with various drilling contractors to utilize drilling services at market-based pricing. These commitments are not recorded as obligations in the accompanying condensed consolidated balance sheets. As of September 30, 2017 , the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $31 million . Oil, Natural Gas and NGL Purchase Commitments We commit to purchase oil, natural gas and NGL from other owners in the properties we operate, including owners associated with our remaining volumetric production payment (VPP) transaction. Production purchases under these arrangements are based on market prices at the time of production, and the purchased oil, natural gas and NGL are resold at market prices. See Volumetric Production Payments in Note 9 for further discussion of our VPP transactions. Net Acreage Maintenance Commitments Under the terms of our Utica Shale joint venture agreements with Total S.A., we are obligated to extend, renew or replace certain expiring joint leasehold, at our cost, to ensure that the net acreage maintenance level is met as of the December 31, 2017 measurement date. Other Commitments As part of our normal course of business, we enter into various agreements providing, or otherwise arranging for, financial or performance assurances to third parties on behalf of our wholly owned guarantor subsidiaries. These agreements may include future payment obligations or commitments regarding operational performance that effectively guarantee our subsidiaries’ future performance. In connection with acquisitions and divestitures, our purchase and sale agreements generally provide indemnification to the counterparty for liabilities incurred as a result of a breach of a representation or warranty by the indemnifying party and/or other specified matters. These indemnifications generally have a discrete term and are intended to protect the parties against risks that are difficult to predict or cannot be quantified at the time of entering into or consummating a particular transaction. For divestitures of oil and natural gas properties, our purchase and sale agreements may require the return of a portion of the proceeds we receive as a result of uncured title or environmental defects. Certain of our oil and natural gas properties are burdened by non-operating interests, such as royalty and overriding royalty interests, including overriding royalty interests sold through our VPP transactions. As the holder of the working interest from which these interests have been created, we have the responsibility to bear the cost of developing and producing the reserves attributable to these interests. See Volumetric Production Payments in Note 9 for further discussion of our VPP transactions. While executing our strategic priorities, we have incurred certain cash charges, including contract termination charges, financing extinguishment costs and charges for unused natural gas transportation and gathering capacity. As we continue to focus on our strategic priorities, we may take certain actions that reduce financial leverage and complexity, and we may incur additional cash and noncash charges.

Other Liabilities (Notes)

Other Liabilities (Notes)	9 Months Ended
	Sep. 30, 2017
Other Liabilities Disclosure [Abstract]
Other Liabilities Disclosure	Other Liabilities Other current liabilities as of September 30, 2017 and December 31, 2016 are detailed below. September 30, December 31, ($ in millions) Revenues and royalties due others $ 474 $ 543 Accrued drilling and production costs 313 169 Joint interest prepayments received 72 71 Accrued compensation and benefits 195 239 Other accrued taxes 73 32 Bank of New York Mellon legal accrual (a) — 440 Other 270 304 Total other current liabilities $ 1,397 $ 1,798 ____________________________________________ (a) In the Current Period, we received notice from the U.S. Supreme Court that it would not review our appeal of the decision by the U.S. District Court for the Southern District of New York regarding the redemption at par value of our 6.775% Senior Notes due 2019. As a result of the decision, we paid $441 million with cash on hand and borrowings under the credit facility, and the related supersedeas bond was released. Other long-term liabilities as of September 30, 2017 and December 31, 2016 are detailed below. September 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 159 $ 160 Unrecognized tax benefits 99 97 Other 102 126 Total other long-term liabilities $ 360 $ 383 ____________________________________________ (a) The CHK Utica L.L.C. investors’ right to receive proportionately a 3% overriding royalty interest (ORRI) in the first 1,500 net wells drilled on our Utica Shale leasehold is subject to an increase to 4% on net wells earned in any year following a year in which we do not meet our net well commitment under the ORRI obligation, which runs through 2023. The liability represents the obligation to deliver future ORRIs. As of September 30, 2017 and December 31, 2016, approximately $30 million and $43 million of the total ORRI obligations are recorded in other current liabilities, respectively.

Equity (Notes)

Equity (Notes)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Stockholders' Equity Note Disclosure	Equity Common Stock A summary of the changes in our common shares issued for the Current Period and the Prior Period is detailed below. Nine Months Ended 2017 2016 (in thousands) Shares issued as of January 1 896,279 664,796 Exchange of convertible notes — 55,428 Exchange of senior notes — 53,924 Exchange/conversion of preferred stock 9,966 1,021 Restricted stock issuances (net of forfeitures and cancellations) 2,417 1,852 Shares issued as of September 30 908,662 777,021 During the Current Period, our shareholders approved an amendment to our certificate of incorporation to increase our authorized common stock to 2,000,000,000 shares, par value $0.01 per share. Preferred Stock Outstanding shares and the liquidation price per share of our preferred stock for the Current Period and the Prior Period are detailed below. 5.75% 5.75% (A) 4.50% 5.00% (2005B) (in thousands) Shares outstanding as of January 1, 2017 843 476 2,559 1,962 Preferred stock conversions/exchanges (a) (73 ) (13 ) — (151 ) Shares outstanding as of September 30, 2017 770 463 2,559 1,811 Shares outstanding as of January 1, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions/exchanges (b) (25 ) (1 ) — — Shares outstanding as of September 30, 2016 1,472 1,099 2,559 2,096 Liquidation price per share $ 1,000 $ 1,000 $ 100 $ 100 ____________________________________________ (a) In the Current Period, holders of our 5.75% Cumulative Convertible Preferred Stock exchanged 72,600 shares into 7,442,156 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock exchanged 12,500 shares into 1,205,923 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged 150,948 shares into 1,317,756 shares of common stock. In connection with the exchanges, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $41 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share. (b) In the Prior Period, holders of our 5.75% Cumulative Convertible Preferred Stock converted 24,601 shares into 975,488 shares of common stock and holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 1,201 shares into 46,018 shares of common stock. Dividends Dividends declared on our preferred stock are reflected as adjustments to retained earnings to the extent a surplus of retained earnings exists after giving effect to the dividends. To the extent retained earnings are insufficient to fund the distributions, payments constitute a return of contributed capital rather than earnings and are accounted for as a reduction to paid-in capital. Dividends on our outstanding preferred stock are payable quarterly. We may pay dividends on our 5.00% Cumulative Convertible Preferred Stock (Series 2005B) and our 4.50% Cumulative Convertible Preferred Stock in cash, common stock or a combination thereof, at our option. Dividends on both series of our 5.75% Cumulative Convertible Non-Voting Preferred Stock are payable only in cash. In the Prior Period, we suspended dividend payments on our convertible preferred stock to provide additional liquidity in the depressed commodity price environment. In the Current Period, we reinstated the payment of dividends on each series of our outstanding convertible preferred stock and paid our dividends in arrears. Accumulated Other Comprehensive Income (Loss) For the Current Period and the Prior Period, changes in accumulated other comprehensive income (loss) for cash flow hedges, net of tax, are detailed below. Nine Months Ended 2017 2016 ($ in millions) Balance, as of January 1 $ (96 ) $ (99 ) Other comprehensive income (loss) before reclassifications 4 (23 ) Amounts reclassified from accumulated other comprehensive income 25 21 Net other comprehensive income (loss) 29 (2 ) Balance, as of September 30 $ (67 ) $ (101 ) For the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, net losses on cash flow hedges for commodity contracts reclassified from accumulated other comprehensive income (loss), net of tax, to oil, natural gas and NGL revenues in the condensed consolidated statements of operations were $8 million , $7 million , $25 million and $21 million , respectively.

Share-Based Compensation (Notes

Share-Based Compensation (Notes)	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments	Share-Based Compensation Chesapeake’s share-based compensation program consists of restricted stock, stock options and performance share units (PSUs) 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 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 (in thousands) Unvested restricted stock as of January 1, 2017 9,092 $ 11.39 Granted 9,872 $ 5.40 Vested (4,481 ) $ 13.63 Forfeited (942 ) $ 8.85 Unvested restricted stock as of September 30, 2017 13,541 $ 6.46 The aggregate intrinsic value of restricted stock that vested during the Current Period was approximately $25 million based on the stock price at the time of vesting. As of September 30, 2017 , there was approximately $59 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 1.97 years. Stock Options. In the Current Period and the Prior Period, we granted members of management stock options that vest ratably over a three -year period. Each stock option award has an exercise price equal to the closing price of the Company’s common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant. We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on an average of historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account the Company's dividend policy, over the expected life of the option. The Company used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period. Expected option life – years 6.0 Volatility 62.42 % Risk-free interest rate 2.17 % Dividend yield — % The following table provides information related to stock option activity in the Current Period. Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2017 8,593 $ 11.88 7.22 $ 14 Granted 9,226 $ 5.45 Exercised — $ — $ — Expired (524 ) $ 18.45 Forfeited (904 ) $ 9.91 Outstanding as of September 30, 2017 16,391 $ 8.16 8.04 $ 2 Exercisable as of September 30, 2017 4,490 $ 15.22 5.49 $ 1 ___________________________________________ (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 September 30, 2017 , there was $26 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 2.28 years . Restricted Stock and Stock Option Compensation. We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ 9 $ 10 $ 29 $ 28 Oil and natural gas properties 3 4 10 13 Oil, natural gas and NGL production expenses 2 4 9 10 Marketing, gathering and compression expenses — — — 1 Total restricted stock and stock option compensation $ 14 $ 18 $ 48 $ 52 Liability-Classified Awards Performance Share Units. We have granted PSUs to senior management that vest ratably over a three -year term and are settled in cash on the third anniversary of the awards. The ultimate amount earned is based on achievement of performance metrics established by the Compensation Committee of the Board of Directors, which include total shareholder return (TSR) and, for certain of the awards, operational performance goals, such as finding and development costs and production levels. For PSUs granted, the TSR component can range from 0% to 100% and the operational component can range from 0% to 100% , resulting in a maximum payout of 200% . Compensation expense associated with PSU grants 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 the Company’s estimates of the underlying performance measures. The payout percentage for all PSU grants is capped at 100% if the Company’s absolute TSR is less than zero . The Company utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 87.16 % Risk-free interest rate 1.51 % Dividend yield for value of awards — % The following table presents a summary of our 2017, 2016 and 2015 PSU awards. Grant Date Fair Value September 30, 2017 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2017 Awards: Payable 2020 1,217,774 $ 8 $ 6 $ 2 2016 Awards: Payable 2019 2,348,893 $ 10 $ 9 $ 8 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1 PSU Compensation. We recognized the following compensation costs (credits) related to PSUs for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ (2 ) $ 7 $ (4 ) $ 10 Restructuring and other termination costs — — — 1 Total PSU compensation $ (2 ) $ 7 $ (4 ) $ 11

Derivative and Hedging Activiti

Derivative and Hedging Activities (Notes)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Hedging Activities Disclosure	Derivative and Hedging Activities Chesapeake uses derivative instruments to reduce its exposure to fluctuations in future commodity prices and to protect its expected operating cash flow against significant market movements or volatility. All of our commodity 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 derivative instruments were designated for hedge accounting as of September 30, 2017 and December 31, 2016. Oil, Natural Gas and NGL Derivatives As of September 30, 2017 and December 31, 2016, our oil, natural gas and NGL derivative instruments consisted of the following types of instruments: • Swaps : Chesapeake receives a fixed price and pays 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 : Chesapeake sells, and occasionally buys, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, Chesapeake pays the counterparty the excess on sold call options and Chesapeake receives the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party. • Call Swaptions : Chesapeake sells call swaptions to counterparties that allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time. • 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, Chesapeake receives the fixed price and pays 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 Chesapeake 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. Chesapeake receives the fixed price differential and pays 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 September 30, 2017 and December 31, 2016 are provided below. September 30, 2017 December 31, 2016 Volume Fair Value Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 18 $ (17 ) 23 $ (140 ) Three Way Collars 2 (2 ) — — Call options 1 — 5 (1 ) Call swaptions 2 (7 ) — — Basis protection swaps 3 (1 ) — — Total oil 26 (27 ) 28 (141 ) Natural gas (tbtu): Fixed-price swaps 696 38 719 (349 ) Collars 71 8 60 (9 ) Call options 121 (7 ) 114 — Basis protection swaps 26 (1 ) 31 (5 ) Total natural gas 914 38 924 (363 ) NGL (mmgal): Fixed-price swaps 15 (2 ) 53 — Total estimated fair value $ 9 $ (504 ) 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) . Interest Rate Derivatives As of September 30, 2017 and December 31, 2016, there were no interest rate derivatives outstanding. We have terminated fair value hedges related to certain of our senior notes. Gains and losses related to these terminated hedges will be amortized as an adjustment to interest expense over the remaining term of the related senior notes. Over the next three years , we will recognize $2 million in net gains related to these transactions. Foreign Currency Derivatives During the Current Period, both our 6.25% Euro-denominated Senior Notes due 2017 and cross currency swaps for the same principal amount matured. Upon maturity of the notes, t he counterparties paid us €246 million and we paid the counterparties $327 million . The terms of the cross currency swaps were based on the dollar/euro exchange rate on the issuance date of $1.3325 to €1.00. The swaps were designated as cash flow hedges and, because they were entirely effective in having eliminated any potential variability in our expected cash flows related to changes in foreign exchange rates, changes in their fair value did not impact earnings. The fair values of the cross currency swaps were recorded on the condensed consolidated balance sheet as a liability of $73 million as of December 31, 2016. Supply Contract Derivatives From time to time and in the normal course of business, our marketing subsidiary enters into supply contracts under which we commit to deliver a predetermined quantity of natural gas to certain counterparties in an attempt to earn attractive margins. Under certain contracts, we receive a sales price that is based on the price of a product other than natural gas, thereby creating an embedded derivative requiring bifurcation. In the Prior Quarter, we sold a long-term natural gas supply contract to a third party for cash proceeds of $146 million , which is included in marketing, gathering and compression revenues as a realized gain. We reversed the cumulative unrealized gains, resulting in an unrealized loss of $280 million in the Prior Quarter and $297 million in Prior Period, respectively. Effect of Derivative Instruments – Condensed Consolidated Balance Sheets The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of September 30, 2017 and December 31, 2016 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Condensed Consolidated Balance Sheets Net Fair Value Presented in the Condensed Consolidated Balance Sheet ($ in millions) As of September 30, 2017 Commodity Contracts: Short-term derivative asset $ 57 $ (29 ) $ 28 Short-term derivative liability (37 ) 29 (8 ) Long-term derivative asset 1 (1 ) — Long-term derivative liability (11 ) — (11 ) Total commodity contracts 10 (1 ) 9 Total derivatives $ 10 $ (1 ) $ 9 As of December 31, 2016 Commodity Contracts: Short-term derivative asset $ 1 $ (1 ) $ — Short-term derivative liability (490 ) 1 (489 ) Long-term derivative liability (15 ) — (15 ) Total commodity contracts (504 ) — (504 ) Foreign Currency Contracts: (a) Short-term derivative liability (73 ) — (73 ) Total foreign currency contracts (73 ) — (73 ) Total derivatives $ (577 ) $ — $ (577 ) ____________________________________________ (a) Designated as cash flow hedging instruments. As of September 30, 2017 and December 31, 2016, we did not have any cash collateral balances for these derivatives. 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 Nine Months Ended 2017 2016 2017 2016 ($ in millions) Oil, natural gas and NGL revenues $ 1,049 $ 1,048 $ 3,275 $ 2,744 Gains (losses) on undesignated oil, natural gas and NGL derivatives (62 ) 136 477 (110 ) Losses on terminated cash flow hedges (8 ) (7 ) (25 ) (24 ) Total oil, natural gas and NGL revenues $ 979 $ 1,177 $ 3,727 $ 2,610 The components of marketing, gathering and compression revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Marketing, gathering and compression revenues $ 964 $ 1,379 $ 3,250 $ 3,538 Losses on undesignated supply contract derivatives — (280 ) — (297 ) Total marketing, gathering and compression revenues $ 964 $ 1,099 $ 3,250 $ 3,241 The components of interest expense for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Interest expense on senior notes $ 135 $ 141 $ 407 $ 446 Interest expense on term loan 34 14 98 14 Amortization of loan discount, issuance costs and other 13 9 28 27 Amortization of premium associated with troubled debt restructuring (29 ) (41 ) (112 ) (124 ) Interest expense on revolving credit facility 11 10 28 27 Gains on terminated fair value hedges (1 ) (1 ) (1 ) (2 ) Losses on undesignated interest rate derivatives — — 1 — Capitalized interest (49 ) (59 ) (147 ) (191 ) Total interest expense $ 114 $ 73 $ 302 $ 197 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 September 30, 2017 2016 Before After Before After ($ in millions) Balance, beginning of period $ (132 ) $ (75 ) $ (163 ) $ (104 ) Net change in fair value — — (4 ) (4 ) Losses reclassified to income 8 8 7 7 Balance, end of period $ (124 ) $ (67 ) $ (160 ) $ (101 ) Nine Months Ended September 30, 2017 2016 Before After Before After ($ in millions) Balance, beginning of period $ (153 ) $ (96 ) $ (160 ) $ (99 ) Net change in fair value 4 4 (23 ) (23 ) Losses reclassified to income 25 25 23 21 Balance, end of period $ (124 ) $ (67 ) $ (160 ) $ (101 ) The accumulated other comprehensive loss, as of September 30, 2017 , 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 September 30, 2017 , we expect to transfer approximately $19 million of net loss included in accumulated other comprehensive income 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 are highly rated or deemed by the Company to have acceptable credit strength and 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 September 30, 2017 , our oil, natural gas and NGL derivative instruments were spread among 10 counterparties. Hedging Arrangements Certain of our hedging arrangements are with counterparties that are also lenders (or affiliates of lenders) under our revolving credit facility. The contracts entered into with these counterparties are secured by the same collateral that secures our revolving credit facility, which allows us to reduce any letters of credit posted as security with those counterparties. 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. 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, NGL and cross currency 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 September 30, 2017 and December 31, 2016: 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 September 30, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ 55 $ 2 $ 57 Commodity liabilities — (38 ) (10 ) (48 ) Total derivatives $ — $ 17 $ (8 ) $ 9 As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of Chesapeake’s financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below. Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 1 — Total purchases, issuances, sales and settlements: Settlements 1 — Balance, as of September 30, 2017 $ (8 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 12 (118 ) Total purchases, issuances, sales and settlements: Settlements 49 (33 ) Sales — (146 ) Balance, as of September 30, 2016 $ (30 ) $ — ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 1 $ 12 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (7 ) $ (1 ) $ — $ — Qualitative and Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements The significant unobservable inputs for Level 3 derivative contracts include unpublished forward prices of natural gas, market volatility and credit risk of counterparties. Changes in these inputs 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, and adverse changes to our counterparties’ creditworthiness decreases the fair value of our 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 September 30, 2017 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 15.30% – 26.67% 23.43% $ (9 ) Natural gas trades Natural gas price volatility curves 19.58% – 63.01% 38.24% $ 1

Oil and Natural Gas Property Tr

Oil and Natural Gas Property Transactions (Notes)	9 Months Ended
	Sep. 30, 2017
Property, Plant and Equipment [Abstract]
Mergers, Acquisitions and Dispositions Disclosure	Oil and Natural Gas Property Transactions Under full cost accounting rules, we accounted for the sales of oil and natural gas properties discussed below as adjustments to capitalized costs, with no recognition of gain or loss as the sales did not involve a significant change in proved reserves or significantly alter the relationship between costs and proved reserves. In the Current Period, we sold portions of our acreage and producing properties in our Haynesville Shale operating area in northern Louisiana for approximately $915 million , subject to certain customary closing adjustments. Included in the sales were approximately 119,500 net acres and interests in 576 wells that were producing approximately 80 mmcf of gas per day at the time of closing. Also in the Current Quarter and the Current Period, we received proceeds of $248 million and $331 million , respectively, net of post-closing adjustments, for the sale of other oil and natural gas properties covering various operating areas. In the Prior Quarter, we acquired oil and natural gas properties in the Haynesville Shale for approximately $85 million . In the Prior Quarter and the Prior Period, we sold certain of our noncore oil and natural gas properties for net proceeds of approximately $26 million and $988 million , respectively, after post-closing adjustments. In conjunction with certain of these sales, we purchased oil and natural gas interests previously sold to third parties in connection with four of our VPP transactions for approximately $259 million . A majority of the acquired interests were sold in the asset divestitures discussed above and we no longer have any further commitments or obligations related to these VPPs. The asset divestitures cover various operating areas. Volumetric Production Payments From time to time, we have sold certain of our producing assets located in more mature producing regions through the sale of VPPs. A VPP is a limited-term overriding royalty interest in oil and natural gas reserves that (i) entitles the purchaser to receive scheduled production volumes over a period of time from specific lease interests; (ii) is free and clear of all associated future production costs and capital expenditures; (iii) is non-recourse to the seller (i.e., the purchaser’s only recourse is to the reserves acquired); (iv) transfers title of the reserves to the purchaser; and (v) allows the seller to retain all production beyond the specified volumes, if any, after the scheduled production volumes have been delivered. For all of our VPP transactions, we novated to each of the respective VPP buyers hedges that covered all VPP volumes sold. If contractually scheduled volumes exceed the actual volumes produced from the VPP wellbores that are attributable to the ORRI conveyed, either the shortfall will be made up from future production from these wellbores (or, at our option, from our retained interest in the wellbores) through an adjustment mechanism, or the initial term of the VPP will be extended until all scheduled volumes, to the extent produced, are delivered from the VPP wellbores to the VPP buyer. We retain drilling rights on the properties below currently producing intervals and outside of producing wellbores. As the operator of the properties from which the VPP volumes have been sold, we bear the cost of producing the reserves attributable to these interests, which we include as a component of production expenses and production taxes in our condensed consolidated statements of operations in the periods these costs are incurred. As with all non-expense-bearing royalty interests, volumes conveyed in a VPP transaction are excluded from our estimated proved reserves; however, the estimated production expenses and taxes associated with VPP volumes expected to be delivered in future periods are included as a reduction of the future net cash flows attributable to our proved reserves for purposes of determining our full cost ceiling test for impairment purposes and in determining our standardized measure. Pursuant to SEC guidelines, the estimates used for purposes of determining the cost center ceiling and the standardized measure are based on current costs. Our commitment to bear the costs on any future production of VPP volumes is not reflected as a liability on our balance sheet. Future costs will depend on the actual production volumes as well as the production costs and taxes in effect during the periods in which the production actually occurs, which could differ materially from our current and historical costs, and production may not occur at the times or in the quantities projected, or at all. For accounting purposes, cash proceeds from the sale of VPPs were reflected as a reduction of oil and natural gas properties with no gain or loss recognized, and our proved reserves were reduced accordingly. We have also committed to purchase natural gas and liquids associated with our VPP transactions. Production purchased under these arrangements is based on market prices at the time of production, and the purchased natural gas and liquids are resold at market prices. As of September 30, 2017 , we had the following VPP outstanding: Volume Sold VPP # Date of VPP Location Proceeds Oil Natural Gas NGL Total ($ in millions) (mmbbl) (bcf) (mmbbl) (bcfe) 9 May 2011 Mid-Continent $ 853 1.7 138 4.8 177 The volumes produced on behalf of our VPP buyers during the Current Quarter, the Prior Quarter, the Current Period and the Prior Period were as follows: Three Months Ended September 30, 2017 Three Months Ended September 30, 2016 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 9 34.4 2.9 79.9 3.6 37.6 3.2 85.9 4.0 1 (a) — — — — — 3.1 — 3.1 34.4 2.9 79.9 3.6 37.6 6.3 85.9 7.1 Nine Months Ended September 30, 2017 Nine Months Ended September 30, 2016 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 10 (a) — — — — 108.0 3.0 368.7 5.8 9 105.5 9.0 243.9 11.0 115.5 9.9 262.8 12.2 4 (a) — — — — 20.0 3.8 — 3.9 3 (a) — — — — — 2.5 — 2.5 2 (a) — — — — — 1.5 — 1.5 1 (a) — — — — — 9.5 — 9.5 105.5 9.0 243.9 11.0 243.5 30.2 631.5 35.4 ____________________________________________ (a) In connection with certain asset divestitures in 2016, we purchased the remaining oil and natural gas interests previously sold in connection with VPP #10, VPP #4, VPP #3, VPP #2 and VPP #1. A majority of the oil and natural gas interests purchased were subsequently sold to the buyers of the assets. The volumes remaining to be delivered on behalf of our VPP buyers as of September 30, 2017 were as follows: Volume Remaining as of September 30, 2017 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 41 0.4 36.8 1.0 45.1

Variable Interest Entities (Not

Variable Interest Entities (Notes)	9 Months Ended
	Sep. 30, 2017
Variable Interest Entity, Measure of Activity [Abstract]
Variable Interest Entity Disclosure	Variable Interest Entities We consolidate the activities of VIEs for which we are the primary beneficiary. To determine whether we own a variable interest in a VIE, we perform a qualitative analysis of the entity’s design, organizational structure, primary decision makers and relevant agreements. Chesapeake Granite Wash Trust (the “Trust”) is considered a VIE due to the lack of voting or similar decision-making rights by its equity holders regarding activities that have a significant effect on the economic success of the Trust and because the royalty interest owners, other than Chesapeake, do not have the ability to exercise substantial liquidation rights. Our ownership in the Trust and our previous obligations under the development agreement constitute variable interests. On June 30, 2017, the Trust’s subordinated units, all of which were held by Chesapeake, converted to common units. We continue to consolidate the activities of the Trust as we are the primary beneficiary of the Trust because (i) we have the power to direct the activities that most significantly impact the economic performance of the Trust via our operation of the majority of the producing wells and the completed development wells, and (ii) we have the obligation to absorb losses that potentially could be significant to the Trust. As a result, we consolidate the Trust in our financial statements, and the common units of the Trust owned by third parties are reflected as a noncontrolling interest. As of September 30, 2017 and December 31, 2016 , we had $253 million and $257 million , respectively, of noncontrolling interests on our condensed consolidated balance sheets attributable to the Trust. In the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, we had $1 million , $1 million , $3 million and $1 million , respectively, of net income attributable to the Trust’s noncontrolling interests recorded in our condensed consolidated statements of operations. The Trust is a consolidated entity whose legal existence is separate from Chesapeake and our other consolidated subsidiaries, and the Trust is not a guarantor of any of Chesapeake’s debt. The creditors or beneficial holders of the Trust have no recourse to the general credit of Chesapeake. In consolidation, as of September 30, 2017 , $1 million of cash and cash equivalents, $488 million of proved oil and natural gas properties, $460 million of accumulated depreciation, depletion and amortization and $4 million of other current liabilities were attributable to the Trust. We have presented parenthetically on the face of the condensed consolidated balance sheets the assets of the Trust that can be used only to settle obligations of the Trust and the liabilities of the Trust for which creditors do not have recourse to the general credit of Chesapeake.

Impairments (Notes)

Impairments (Notes)	9 Months Ended
	Sep. 30, 2017
Asset Impairment Charges [Abstract]
Asset Impairment Charges Disclosure	Impairments Impairments of Oil and Natural Gas Properties Our proved oil and natural gas properties are subject to quarterly full cost ceiling tests. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. Estimated future net revenues for the quarterly ceiling limit are calculated using the average of commodity prices on the first day of the month over the trailing 12-month period. In the Prior Quarter and the Prior Period, capitalized costs of oil and natural gas properties exceeded the ceiling, resulting in an impairment in the carrying value of our oil and natural gas properties of $497 million and $2.564 billion , respectively. Impairments of Fixed Assets and Other We review our long-lived assets, other than oil and natural gas properties, for recoverability whenever events or changes in circumstances indicate that carrying amounts may not be recoverable. We recognize an impairment if the carrying amount of a long-lived asset is not recoverable and exceeds its fair value. A summary of our impairments of fixed assets by asset class and other charges for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period is as follows: Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Barnett Shale exit costs $ — $ 616 $ — $ 616 Gathering systems — 96 — 96 Natural gas compressors — 32 — 52 Buildings and land 1 7 3 14 Other 8 — 423 17 Total impairments of fixed assets and other $ 9 $ 751 $ 426 $ 795 Barnett Shale Exit Costs. In October 2016, we conveyed our interests in the Barnett Shale operating area located in north central Texas and simultaneously terminated most of our future commitments associated with this asset. As a result of this transaction, we accrued $334 million of charges in the Prior Quarter related to the termination of a natural gas gathering agreement associated with the Barnett Shale assets. We recognized an impairment charge of $282 million in the Prior Quarter related to these assets representing the difference between the carrying amount and the fair value of the assets, less the anticipated costs to sell. Gathering Systems, Natural Gas Compressors, Buildings and Land. In the Prior Quarter we entered into a purchase and sale agreement to sell the majority of our upstream and midstream assets in the Devonian Shale located in West Virginia and Kentucky. We recognized an impairment charge of $134 million in the Prior Quarter for these assets for the difference between the carrying amount and the fair value of the assets, less the anticipated costs to sell. Other. In the Current Period, we terminated future natural gas transportation commitments related to divested assets for cash payments of $126 million . In the Current Period, we also paid $290 million to assign an oil transportation agreement to a third party. Nonrecurring Fair Value Measurements. Fair value measurements for certain of the impairments were based on recent sales information for comparable assets. As the fair value was estimated using the market approach based on recent prices from orderly sales transactions for comparable assets between market participants, these values were classified as Level 2 in the fair value hierarchy. Other inputs used were not observable in the market; these values were classified as Level 3 in the fair value hierarchy.

Income Taxes (Notes)

Income Taxes (Notes)	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Income Tax Disclosure	Income Taxes A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. To assess that likelihood, we use estimates and judgment regarding our future taxable income, and we consider the tax consequences in the jurisdiction where taxable income is generated, to determine whether a valuation allowance is required. The evidence can include our current financial position, our results of operations (both actual and forecasted), the expected reversal of our deferred tax liabilities, and various tax planning strategies as well as the current and forecasted business economics of our industry. Based on our estimated operating results for the subsequent quarter, we project being in a net deferred tax asset position as of December 31, 2017. We believe it is more likely than not that these deferred tax assets will not be realized. Management assesses the available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. A significant piece of objective negative evidence evaluated is the projected cumulative loss incurred over the three-year period ending December 31, 2017. The objective negative evidence limits our ability to consider other subjective positive evidence, such as our projections for future growth. The amount of the deferred tax asset considered realizable, however, could be adjusted if objective negative evidence in the form of cumulative losses is no longer present or if estimates of future taxable income are increased and additional weight is given to subjective evidence, such as future expected growth. A valuation allowance was recorded against our net deferred tax asset as of both December 31, 2016 and September 30, 2017 .

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements Disclosure	Fair Value Measurements Recurring Fair Value Measurements Other Current Assets. Assets related to Chesapeake’s 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 Chesapeake’s 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 September 30, 2017 and December 31, 2016 : 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 September 30, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (58 ) — — (58 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 ) See Note 3 for information regarding fair value measurement of our debt instruments. See Note 8 for information regarding fair value measurement of our derivatives. Nonrecurring Fair Value Measurements See Note 11 regarding nonrecurring fair value measurements.

Segment Information (Notes)

Segment Information (Notes)	9 Months Ended
	Sep. 30, 2017
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Segment Information Disclosure	Segment Information As of September 30, 2017 , we have two reportable operating segments. Our exploration and production operating segment is responsible for finding and producing oil, natural gas and NGL, while our marketing, gathering and compression operating segment is responsible for marketing, gathering and compression of oil, natural gas and NGL. Revenues from the sale of oil, natural gas and NGL related to Chesapeake’s ownership interests by our marketing, gathering and compression operating segment are reflected as revenues within our exploration and production operating segment. These amounts totaled $1.030 billion , $1.025 billion , $3.200 billion and $2.656 billion for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, respectively. The following table presents selected financial information for Chesapeake’s operating segments: Exploration and Production Marketing, Gathering and Compression Other Intercompany Eliminations Consolidated Total ($ in millions) Three Months Ended September 30, 2017 Revenues $ 979 $ 1,994 $ — $ (1,030 ) $ 1,943 Intersegment revenues — (1,030 ) — 1,030 — Total Revenues $ 979 $ 964 $ — $ — $ 1,943 Income (Loss) Before Income Taxes $ (14 ) $ 7 $ (10 ) $ — $ (17 ) Three Months Ended September 30, 2016 Revenues $ 1,177 $ 2,124 $ — $ (1,025 ) $ 2,276 Intersegment revenues — (1,025 ) — 1,025 — Total Revenues $ 1,177 $ 1,099 $ — $ — $ 2,276 Income (Loss) Before (as previously reported) $ (710 ) $ (211 ) $ (231 ) $ (2 ) $ (1,154 ) Income (Loss) Before Income Taxes (as revised) (a) $ (642 ) $ (339 ) $ (231 ) $ (2 ) $ (1,214 ) Nine Months Ended September 30, 2017 Revenues $ 3,727 $ 6,450 $ — $ (3,200 ) $ 6,977 Intersegment revenues — (3,200 ) — 3,200 — Total Revenues $ 3,727 $ 3,250 $ — $ — $ 6,977 Income (Loss) Before Income Taxes $ 1,094 $ (440 ) $ (32 ) $ (1 ) $ 621 Exploration and Production Marketing, Gathering and Compression Other Intercompany Eliminations Consolidated Total ($ in millions) Nine Months Ended September 30, 2016 Revenues $ 2,610 $ 5,897 $ — $ (2,656 ) $ 5,851 Intersegment revenues — (2,656 ) — 2,656 — Total Revenues $ 2,610 $ 3,241 $ — $ — $ 5,851 Income (Loss) Before (as previously reported) $ (3,360 ) $ (215 ) $ (248 ) $ (2 ) $ (3,825 ) Income (Loss) Before Income Taxes (as revised) (a) $ (3,465 ) $ (343 ) $ (248 ) $ (2 ) $ (4,058 ) As of September 30, 2017 Total Assets $ 10,451 $ 923 $ 994 $ (387 ) $ 11,981 As of December 31, 2016 Total Assets $ 11,249 $ 1,118 $ 1,059 $ (398 ) $ 13,028 _________________________________________ (a) We have revised the amounts presented in the Prior Quarter and the Prior Period. The impact of the errors was not material to any previously issued financial statements.

Recently Issued Accounting Stan

Recently Issued Accounting Standards (Notes)	9 Months Ended
	Sep. 30, 2017
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of Adoption of New Accounting Pronouncements	Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (FASB) issued updated revenue recognition guidance to clarify the principles for recognizing revenue and to develop a common revenue standard for U.S. GAAP and international financial reporting standards. The new standard requires the recognition of revenue to depict the transfer of promised goods to customers in an amount reflecting the consideration the Company expects to receive in the exchange. In March 2016, the FASB issued an update clarifying the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued an update clarifying the identification of performance obligations and licensing implementations guidance. In May 2016, the FASB issued an update clarifying guidance in a few narrow areas and added some practical expedients to the guidance. In September 2017, the FASB issued an update clarifying the definition of a public business entity for the application of the new revenue recognition standards. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017, with early application permitted after December 31, 2016. The standard is required to be adopted using either the full retrospective approach or the modified retrospective approach. While early adoption is permitted, we plan to adopt this new standard in the first quarter of 2018 using the modified retrospective approach. Through September 30, 2017, we have made progress on contract reviews, drafting accounting policies and evaluating the additional information required to be accumulated and analyzed to complete new disclosure requirements. We expect that enhanced disclosures will be required under the new standard. Further analysis is planned in the fourth quarter of 2017 to complete our evaluation of the impact of the new standard. In February 2016, the FASB issued updated lease accounting guidance requiring companies to recognize the assets and liabilities for the rights and obligations created by long-term leases of assets on the balance sheet. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2018. In September 2017, the FASB issued an update clarifying the definition of a public business entity for the application of the new leasing standards. The standard will not apply to our leases of mineral rights. We are continuing to further evaluate the impact of this guidance on our consolidated financial statements and related disclosures. In August 2017, the FASB issued derivatives and hedging guidance which makes significant changes to the current hedge accounting rules. The new guidance impacts the designation of hedging relationships, measurement of hedging relationships, presentation of the effects of hedging relationships, assessment of hedge effectiveness and disclosures. The accounting standards update is effective for annual interim periods beginning after December 15, 2018, including interim periods within those annual periods. We are evaluating the impact of this guidance on our consolidated financial statements.

Subsequent Events (Notes)

Subsequent Events (Notes)	9 Months Ended
	Sep. 30, 2017
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events On October 12, 2017, we issued in a private placement $300 million aggregate principal amount of 8.00% Senior Notes due 2025 (New 2025 Notes) at 101.25% of par, plus accrued interest from July 15, 2017, and $550 million aggregate principal amount of 8.00% Senior Notes due 2027 (New 2027 Notes) at 99.75% of par, plus accrued interest from June 6, 2017. The New 2025 Notes are an additional issuance of our outstanding 8.00% Senior Notes due 2025, which we issued in December 2016 in an original aggregate principal amount of $1.0 billion . The New 2025 Notes issued and the previously issued senior notes due 2025 will be treated as a single class of notes under the indenture. The New 2027 Notes are an additional issuance of our outstanding 8.00% Senior Notes due 2027, which we issued in June 2017 in an original aggregate principal amount of $750 million . The New 2027 Notes issued and the previously issued senior notes due 2027 will be treated as a single class of notes under the indenture. Aggregate net proceeds from the issuance of the New 2025 Notes and New 2027 Notes, excluding the accrued interest received, were approximately $842 million . On October 13, 2017, we used a portion of the net proceeds from the offering discussed above to finance $550 million in tender offers for certain of our senior notes. We repurchased approximately $320 million principal amount of our 8.00% Senior Secured Second Lien Notes due 2022 for $350 million plus accrued and unpaid interest, approximately $136 million principal amount of our 6.625% Senior Notes due 2020 for $141 million plus accrued and unpaid interest, approximately $51 million principal amount of our 6.875% Senior Notes due 2020 for $53 million plus accrued and unpaid interest, approximately $3 million principal amount of our 6.125% Senior Notes due 2021 for $3 million plus accrued and unpaid interest and approximately $3 million principal amount of our 5.375% Senior Notes due 2021 for $3 million plus accrued and unpaid interest. In addition, in October 2017, we used additional proceeds from the issuances described above to repurchase approximately $237 million principal amount of our secured term loan due 2021 for $258 million . On October 30, 2017, the administrative agent under our senior revolving credit facility, in addition to other lenders under the agreement, notified us that the borrowing base had been reaffirmed at $3.8 billion .

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Basis of Accounting	The accompanying condensed consolidated financial statements of Chesapeake Energy Corporation (“Chesapeake” or the “Company”) were prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) and include the accounts of our direct and indirect wholly owned subsidiaries and entities in which Chesapeake has a controlling financial interest. Intercompany accounts and balances have been eliminated.

Variable Interest Entities Vari

Variable Interest Entities Variable Interest Entities (Policies)	9 Months Ended
	Sep. 30, 2017
Variable Interest Entity, Measure of Activity [Abstract]
Variable Interest Entity	We consolidate the activities of VIEs for which we are the primary beneficiary. To determine whether we own a variable interest in a VIE, we perform a qualitative analysis of the entity’s design, organizational structure, primary decision makers and relevant agreements.

Impairments (Policies)

Impairments (Policies)	9 Months Ended
	Sep. 30, 2017
Asset Impairment Charges [Abstract]
Impairments of Proved Oil and Natural Gas Properties	Our proved oil and natural gas properties are subject to quarterly full cost ceiling tests. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. Estimated future net revenues for the quarterly ceiling limit are calculated using the average of commodity prices on the first day of the month over the trailing 12-month period.

Income Taxes Income Taxes (Poli

Income Taxes Income Taxes (Policy)	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Income Taxes	A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. To assess that likelihood, we use estimates and judgment regarding our future taxable income, and we consider the tax consequences in the jurisdiction where taxable income is generated, to determine whether a valuation allowance is required. The evidence can include our current financial position, our results of operations (both actual and forecasted), the expected reversal of our deferred tax liabilities, and various tax planning strategies as well as the current and forecasted business economics of our industry.

Recently Issued Accounting St30

Recently Issued Accounting Standards (Policies)	9 Months Ended
	Sep. 30, 2017
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements	In May 2014, the Financial Accounting Standards Board (FASB) issued updated revenue recognition guidance to clarify the principles for recognizing revenue and to develop a common revenue standard for U.S. GAAP and international financial reporting standards. The new standard requires the recognition of revenue to depict the transfer of promised goods to customers in an amount reflecting the consideration the Company expects to receive in the exchange. In March 2016, the FASB issued an update clarifying the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued an update clarifying the identification of performance obligations and licensing implementations guidance. In May 2016, the FASB issued an update clarifying guidance in a few narrow areas and added some practical expedients to the guidance. In September 2017, the FASB issued an update clarifying the definition of a public business entity for the application of the new revenue recognition standards. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017, with early application permitted after December 31, 2016. The standard is required to be adopted using either the full retrospective approach or the modified retrospective approach. While early adoption is permitted, we plan to adopt this new standard in the first quarter of 2018 using the modified retrospective approach. Through September 30, 2017, we have made progress on contract reviews, drafting accounting policies and evaluating the additional information required to be accumulated and analyzed to complete new disclosure requirements. We expect that enhanced disclosures will be required under the new standard. Further analysis is planned in the fourth quarter of 2017 to complete our evaluation of the impact of the new standard. In February 2016, the FASB issued updated lease accounting guidance requiring companies to recognize the assets and liabilities for the rights and obligations created by long-term leases of assets on the balance sheet. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2018. In September 2017, the FASB issued an update clarifying the definition of a public business entity for the application of the new leasing standards. The standard will not apply to our leases of mineral rights. We are continuing to further evaluate the impact of this guidance on our consolidated financial statements and related disclosures. In August 2017, the FASB issued derivatives and hedging guidance which makes significant changes to the current hedge accounting rules. The new guidance impacts the designation of hedging relationships, measurement of hedging relationships, presentation of the effects of hedging relationships, assessment of hedge effectiveness and disclosures. The accounting standards update is effective for annual interim periods beginning after December 15, 2018, including interim periods within those annual periods. We are evaluating the impact of this guidance on our consolidated financial statements.

Basis of Presentation (Tables)

Basis of Presentation (Tables)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Schedule of Error Corrections and Prior Period Adjustments, Condensed Consolidated Income Statement	Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 These revisions have been reflected in the comparative 2016 condensed consolidated financi al statements presented herein. See Evaluation of Disclosure Controls and Procedure s in Item 4 of this Form 10-Q. The following table reconciles the amounts as previously reported in the applicable financial statement to the corresponding revised amounts: Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Revision Adjustment As Revised ($ in millions except per share data) Oil, natural gas and NGL depreciation, depletion and amortization $ 255 $ (4 ) $ 251 Impairment of oil and natural gas properties $ 433 $ 64 $ 497 Total operating expenses $ 3,450 $ 60 $ 3,510 Loss from operations $ (1,174 ) $ (60 ) $ (1,234 ) Loss before income taxes $ (1,154 ) $ (60 ) $ (1,214 ) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Net loss attributable to Chesapeake $ (1,155 ) $ (60 ) $ (1,215 ) Net loss available to common stockholders $ (1,197 ) $ (60 ) $ (1,257 ) Loss per common share basic $ (1.54 ) $ (0.08 ) $ (1.62 ) Loss per common share diluted $ (1.54 ) $ (0.08 ) $ (1.62 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 Total operating expenses $ 9,734 $ 233 $ 9,967 Loss from operations $ (3,883 ) $ (233 ) $ (4,116 ) Loss before income taxes $ (3,825 ) $ (233 ) $ (4,058 ) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Net loss attributable to Chesapeake $ (3,826 ) $ (233 ) $ (4,059 ) Net loss available to common stockholders $ (3,953 ) $ (233 ) $ (4,186 ) Loss per common share basic $ (5.47 ) $ (0.33 ) $ (5.80 ) Loss per common share diluted $ (5.47 ) $ (0.33 ) $ (5.80 ) Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564
Schedule of Error Corrections and Prior Period Adjustments, Condensed Consolidated Statements of Comprehensive Income (Loss)	Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 These revisions have been reflected in the comparative 2016 condensed consolidated financi al statements presented herein. See Evaluation of Disclosure Controls and Procedure s in Item 4 of this Form 10-Q. The following table reconciles the amounts as previously reported in the applicable financial statement to the corresponding revised amounts: Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Revision Adjustment As Revised ($ in millions except per share data) Oil, natural gas and NGL depreciation, depletion and amortization $ 255 $ (4 ) $ 251 Impairment of oil and natural gas properties $ 433 $ 64 $ 497 Total operating expenses $ 3,450 $ 60 $ 3,510 Loss from operations $ (1,174 ) $ (60 ) $ (1,234 ) Loss before income taxes $ (1,154 ) $ (60 ) $ (1,214 ) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Net loss attributable to Chesapeake $ (1,155 ) $ (60 ) $ (1,215 ) Net loss available to common stockholders $ (1,197 ) $ (60 ) $ (1,257 ) Loss per common share basic $ (1.54 ) $ (0.08 ) $ (1.62 ) Loss per common share diluted $ (1.54 ) $ (0.08 ) $ (1.62 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 Total operating expenses $ 9,734 $ 233 $ 9,967 Loss from operations $ (3,883 ) $ (233 ) $ (4,116 ) Loss before income taxes $ (3,825 ) $ (233 ) $ (4,058 ) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Net loss attributable to Chesapeake $ (3,826 ) $ (233 ) $ (4,059 ) Net loss available to common stockholders $ (3,953 ) $ (233 ) $ (4,186 ) Loss per common share basic $ (5.47 ) $ (0.33 ) $ (5.80 ) Loss per common share diluted $ (5.47 ) $ (0.33 ) $ (5.80 ) Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564
Schedule of Error Corrections and Prior Period Adjustments, Condensed Consolidated Statements of Cash Flows	Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 These revisions have been reflected in the comparative 2016 condensed consolidated financi al statements presented herein. See Evaluation of Disclosure Controls and Procedure s in Item 4 of this Form 10-Q. The following table reconciles the amounts as previously reported in the applicable financial statement to the corresponding revised amounts: Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Revision Adjustment As Revised ($ in millions except per share data) Oil, natural gas and NGL depreciation, depletion and amortization $ 255 $ (4 ) $ 251 Impairment of oil and natural gas properties $ 433 $ 64 $ 497 Total operating expenses $ 3,450 $ 60 $ 3,510 Loss from operations $ (1,174 ) $ (60 ) $ (1,234 ) Loss before income taxes $ (1,154 ) $ (60 ) $ (1,214 ) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Net loss attributable to Chesapeake $ (1,155 ) $ (60 ) $ (1,215 ) Net loss available to common stockholders $ (1,197 ) $ (60 ) $ (1,257 ) Loss per common share basic $ (1.54 ) $ (0.08 ) $ (1.62 ) Loss per common share diluted $ (1.54 ) $ (0.08 ) $ (1.62 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564 Total operating expenses $ 9,734 $ 233 $ 9,967 Loss from operations $ (3,883 ) $ (233 ) $ (4,116 ) Loss before income taxes $ (3,825 ) $ (233 ) $ (4,058 ) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Net loss attributable to Chesapeake $ (3,826 ) $ (233 ) $ (4,059 ) Net loss available to common stockholders $ (3,953 ) $ (233 ) $ (4,186 ) Loss per common share basic $ (5.47 ) $ (0.33 ) $ (5.80 ) Loss per common share diluted $ (5.47 ) $ (0.33 ) $ (5.80 ) Three Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) As Previously Reported Revision Adjustment As Revised ($ in millions) Net loss $ (1,154 ) $ (60 ) $ (1,214 ) Comprehensive loss $ (1,151 ) $ (60 ) $ (1,211 ) Comprehensive loss attributable to Chesapeake $ (1,152 ) $ (60 ) $ (1,212 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Comprehensive loss $ (3,827 ) $ (233 ) $ (4,060 ) Comprehensive loss attributable to Chesapeake $ (3,828 ) $ (233 ) $ (4,061 ) Nine Months Ended September 30, 2016 CONDENSED CONSOLIDATED STATEMENTS As Previously Revision As ($ in millions) Net loss $ (3,825 ) $ (233 ) $ (4,058 ) Impairment of oil and natural gas properties $ 2,331 $ 233 $ 2,564

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2017
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Antidilutive Securities Excluded From Computation Of Earnings Per Share	hares of common stock for the following dilutive securities were excluded from the calculation of diluted EPS as the effect was antidilutive. Three Months Ended Nine Months Ended 2017 2016 2017 2016 (in millions) Common stock equivalent of our preferred stock outstanding 60 112 60 112 Common stock equivalent of our convertible senior notes outstanding 146 — 146 — Participating securities — 1 1 1

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Schedule of Debt	Our long-term debt consisted of the following as of September 30, 2017 and December 31, 2016: September 30, 2017 December 31, 2016 Principal Amount Carrying Principal Carrying ($ in millions) Term loan due 2021 $ 1,500 $ 1,500 $ 1,500 $ 1,500 6.25% euro-denominated senior notes due 2017 (a) — — 258 258 6.5% senior notes due 2017 — — 134 134 7.25% senior notes due 2018 44 44 64 64 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 572 572 780 780 6.875% senior notes due 2020 279 278 279 278 6.125% senior notes due 2021 550 550 550 550 5.375% senior notes due 2021 270 270 270 270 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 (b) 1,737 2,355 2,419 3,409 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,000 987 1,000 985 5.5% convertible senior notes due 2026 (c)(d) 1,250 831 1,250 811 8.00% senior notes due 2027 750 750 — — 2.75% contingent convertible senior notes due 2035 — — 2 2 2.5% contingent convertible senior notes due 2037 (d) — — 114 112 2.25% contingent convertible senior notes due 2038 (d) 9 8 200 180 Revolving credit facility 645 645 — — Debt issuance costs — (62 ) — (64 ) Interest rate derivatives (e) — 2 — 3 Total debt, net 9,775 9,899 9,989 10,441 Less current maturities of long-term debt, net — — (506 ) (503 ) Total long-term debt, net (f) $ 9,775 $ 9,899 $ 9,483 $ 9,938 ___________________________________________ (a) The principal and carrying amounts shown are based on the exchange rate of $1.0517 to €1.00 as of December 31, 2016. See Foreign Currency Derivatives in Note 8 for information on our related foreign currency derivatives. (b) The carrying amounts as of September 30, 2017 and December 31, 2016, include premium amounts of $618 million and $990 million , respectively, associated with a troubled debt restructuring. The premium is being amortized based on the effective yield method. (c) The conversion and redemption provisions of our convertible senior notes are as follows: Optional Conversion by Holders . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible into cash, our common stock, or a combination of cash and common stock, at our election. One triggering circumstance is when the price of our common stock exceeds a threshold amount during a specified period in a fiscal quarter. Convertibility based on common stock price is measured quarterly. During the Current Quarter, the price of our common stock was below the threshold level and, as a result, the holders do not have the option to convert their notes in the fourth quarter of 2017 under this provision. The notes are also convertible, at the holder’s option, during specified five-day periods if the trading price of the notes is below certain levels determined by reference to the trading price of our common stock. The notes were not convertible under this provision during the Current Quarter. Upon conversion of a convertible senior note, the holder will receive cash, common stock or a combination of cash and common stock, at our election, according to the conversion rate specified in the indenture. The common stock price conversion threshold amount for the convertible senior notes is 130% of the conversion price of $8.568 . Optional Redemption by the Company . We may redeem the convertible senior notes for cash on or after September 15, 2019 , if the price of our common stock exceeds 130% of the conversion price during a specified period at a redemption price of 100% of the principal amount of the notes. Holders’ Demand Repurchase Rights. The holders of our convertible senior notes may require us to repurchase, in cash, all or a portion of their notes at 100% of the principal amount of the notes upon certain fundamental changes. (d) The carrying amounts as of September 30, 2017 and December 31, 2016, are reflected net of discounts of $420 million and $461 million , respectively, associated with the equity component of our convertible and contingent convertible senior notes. This amount is being amortized based on the effective yield method through the first demand repurchase date as applicable. (e) See Interest Rate Derivatives in Note 8 for further discussion related to these instruments. (f) See Note 16 for information regarding debt transactions subsequent to September 30, 2017 .
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below. September 30, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ — $ — $ 503 $ 511 Long-term debt (Level 1) $ 2,876 $ 2,861 $ 3,271 $ 3,216 Long-term debt (Level 2) $ 7,021 $ 7,035 $ 6,664 $ 6,654

Contingencies and Commitments34

Contingencies and Commitments (Tables)	9 Months Ended
	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Gathering, Processing and Transportation Commitments	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. September 30, ($ in millions) 2017 $ 331 2018 1,096 2019 1,062 2020 990 2021 894 2022 – 2035 5,214 Total $ 9,587

Other Liabilities (Tables)

Other Liabilities (Tables)	9 Months Ended
	Sep. 30, 2017
Other Liabilities Disclosure [Abstract]
Other Current Liabilities	Other current liabilities as of September 30, 2017 and December 31, 2016 are detailed below. September 30, December 31, ($ in millions) Revenues and royalties due others $ 474 $ 543 Accrued drilling and production costs 313 169 Joint interest prepayments received 72 71 Accrued compensation and benefits 195 239 Other accrued taxes 73 32 Bank of New York Mellon legal accrual (a) — 440 Other 270 304 Total other current liabilities $ 1,397 $ 1,798 ____________________________________________ (a) In the Current Period, we received notice from the U.S. Supreme Court that it would not review our appeal of the decision by the U.S. District Court for the Southern District of New York regarding the redemption at par value of our 6.775% Senior Notes due 2019. As a result of the decision, we paid $441 million with cash on hand and borrowings under the credit facility, and the related supersedeas bond was released.
Other Long-Term Liabilities	Other long-term liabilities as of September 30, 2017 and December 31, 2016 are detailed below. September 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 159 $ 160 Unrecognized tax benefits 99 97 Other 102 126 Total other long-term liabilities $ 360 $ 383 ____________________________________________ (a) The CHK Utica L.L.C. investors’ right to receive proportionately a 3% overriding royalty interest (ORRI) in the first 1,500 net wells drilled on our Utica Shale leasehold is subject to an increase to 4% on net wells earned in any year following a year in which we do not meet our net well commitment under the ORRI obligation, which runs through 2023. The liability represents the obligation to deliver future ORRIs. As of September 30, 2017 and December 31, 2016, approximately $30 million and $43 million of the total ORRI obligations are recorded in other current liabilities, respectively.

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2017
Equity [Abstract]
Schedule of Common Stock Outstanding Roll Forward	A summary of the changes in our common shares issued for the Current Period and the Prior Period is detailed below. Nine Months Ended 2017 2016 (in thousands) Shares issued as of January 1 896,279 664,796 Exchange of convertible notes — 55,428 Exchange of senior notes — 53,924 Exchange/conversion of preferred stock 9,966 1,021 Restricted stock issuances (net of forfeitures and cancellations) 2,417 1,852 Shares issued as of September 30 908,662 777,021
Schedule of Preferred Stock Outstanding Roll Forward	Outstanding shares and the liquidation price per share of our preferred stock for the Current Period and the Prior Period are detailed below. 5.75% 5.75% (A) 4.50% 5.00% (2005B) (in thousands) Shares outstanding as of January 1, 2017 843 476 2,559 1,962 Preferred stock conversions/exchanges (a) (73 ) (13 ) — (151 ) Shares outstanding as of September 30, 2017 770 463 2,559 1,811 Shares outstanding as of January 1, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions/exchanges (b) (25 ) (1 ) — — Shares outstanding as of September 30, 2016 1,472 1,099 2,559 2,096 Liquidation price per share $ 1,000 $ 1,000 $ 100 $ 100 ____________________________________________ (a) In the Current Period, holders of our 5.75% Cumulative Convertible Preferred Stock exchanged 72,600 shares into 7,442,156 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock exchanged 12,500 shares into 1,205,923 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged 150,948 shares into 1,317,756 shares of common stock. In connection with the exchanges, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $41 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share. (b) In the Prior Period, holders of our 5.75% Cumulative Convertible Preferred Stock converted 24,601 shares into 975,488 shares of common stock and holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 1,201 shares into 46,018 shares of common stock.
Schedule of Accumulated Other Comprehensive Income (Loss)	For the Current Period and the Prior Period, changes in accumulated other comprehensive income (loss) for cash flow hedges, net of tax, are detailed below. Nine Months Ended 2017 2016 ($ in millions) Balance, as of January 1 $ (96 ) $ (99 ) Other comprehensive income (loss) before reclassifications 4 (23 ) Amounts reclassified from accumulated other comprehensive income 25 21 Net other comprehensive income (loss) 29 (2 ) Balance, as of September 30 $ (67 ) $ (101 )

Share-Based Compensation (Table

Share-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Share-Based Compensation, Restricted Stock and Restricted Stock Units Activity	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 (in thousands) Unvested restricted stock as of January 1, 2017 9,092 $ 11.39 Granted 9,872 $ 5.40 Vested (4,481 ) $ 13.63 Forfeited (942 ) $ 8.85 Unvested restricted stock as of September 30, 2017 13,541 $ 6.46
Equity-Classified Share-Based Payment Award Valuation Assumptions	The Company utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 87.16 % Risk-free interest rate 1.51 % Dividend yield for value of awards — % The Company 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 62.42 % Risk-free interest rate 2.17 % Dividend yield — %
Schedule of Share-Based Compensation, Stock Options, 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, 2017 8,593 $ 11.88 7.22 $ 14 Granted 9,226 $ 5.45 Exercised — $ — $ — Expired (524 ) $ 18.45 Forfeited (904 ) $ 9.91 Outstanding as of September 30, 2017 16,391 $ 8.16 8.04 $ 2 Exercisable as of September 30, 2017 4,490 $ 15.22 5.49 $ 1 ___________________________________________ (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.
Equity-Classified Stock-Based 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 Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ 9 $ 10 $ 29 $ 28 Oil and natural gas properties 3 4 10 13 Oil, natural gas and NGL production expenses 2 4 9 10 Marketing, gathering and compression expenses — — — 1 Total restricted stock and stock option compensation $ 14 $ 18 $ 48 $ 52 We recognized the following compensation costs (credits) related to PSUs for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ (2 ) $ 7 $ (4 ) $ 10 Restructuring and other termination costs — — — 1 Total PSU compensation $ (2 ) $ 7 $ (4 ) $ 11
Liability-Classified Share-Based Payment Award Valuation Assumptions	The Company utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 87.16 % Risk-free interest rate 1.51 % Dividend yield for value of awards — % The Company 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 62.42 % Risk-free interest rate 2.17 % Dividend yield — %
Schedule of Nonvested Performance-based Units Activity	The following table presents a summary of our 2017, 2016 and 2015 PSU awards. Grant Date Fair Value September 30, 2017 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2017 Awards: Payable 2020 1,217,774 $ 8 $ 6 $ 2 2016 Awards: Payable 2019 2,348,893 $ 10 $ 9 $ 8 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1
Liability-Classified Stock-Based 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 Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ 9 $ 10 $ 29 $ 28 Oil and natural gas properties 3 4 10 13 Oil, natural gas and NGL production expenses 2 4 9 10 Marketing, gathering and compression expenses — — — 1 Total restricted stock and stock option compensation $ 14 $ 18 $ 48 $ 52 We recognized the following compensation costs (credits) related to PSUs for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) General and administrative expenses $ (2 ) $ 7 $ (4 ) $ 10 Restructuring and other termination costs — — — 1 Total PSU compensation $ (2 ) $ 7 $ (4 ) $ 11

Derivative and Hedging Activi38

Derivative and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts of Outstanding Derivative Positions	The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of September 30, 2017 and December 31, 2016 are provided below. September 30, 2017 December 31, 2016 Volume Fair Value Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 18 $ (17 ) 23 $ (140 ) Three Way Collars 2 (2 ) — — Call options 1 — 5 (1 ) Call swaptions 2 (7 ) — — Basis protection swaps 3 (1 ) — — Total oil 26 (27 ) 28 (141 ) Natural gas (tbtu): Fixed-price swaps 696 38 719 (349 ) Collars 71 8 60 (9 ) Call options 121 (7 ) 114 — Basis protection swaps 26 (1 ) 31 (5 ) Total natural gas 914 38 924 (363 ) NGL (mmgal): Fixed-price swaps 15 (2 ) 53 — Total estimated fair value $ 9 $ (504 )
Schedule Of Derivative Instruments In 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 September 30, 2017 and December 31, 2016 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Condensed Consolidated Balance Sheets Net Fair Value Presented in the Condensed Consolidated Balance Sheet ($ in millions) As of September 30, 2017 Commodity Contracts: Short-term derivative asset $ 57 $ (29 ) $ 28 Short-term derivative liability (37 ) 29 (8 ) Long-term derivative asset 1 (1 ) — Long-term derivative liability (11 ) — (11 ) Total commodity contracts 10 (1 ) 9 Total derivatives $ 10 $ (1 ) $ 9 As of December 31, 2016 Commodity Contracts: Short-term derivative asset $ 1 $ (1 ) $ — Short-term derivative liability (490 ) 1 (489 ) Long-term derivative liability (15 ) — (15 ) Total commodity contracts (504 ) — (504 ) Foreign Currency Contracts: (a) Short-term derivative liability (73 ) — (73 ) Total foreign currency contracts (73 ) — (73 ) Total derivatives $ (577 ) $ — $ (577 ) ____________________________________________ (a) Designated as cash flow hedging instruments
Schedule of Derivative Instruments, Oil, Natural Gas and NGL Revenues	The components of marketing, gathering and compression revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Marketing, gathering and compression revenues $ 964 $ 1,379 $ 3,250 $ 3,538 Losses on undesignated supply contract derivatives — (280 ) — (297 ) Total marketing, gathering and compression revenues $ 964 $ 1,099 $ 3,250 $ 3,241 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 Nine Months Ended 2017 2016 2017 2016 ($ in millions) Oil, natural gas and NGL revenues $ 1,049 $ 1,048 $ 3,275 $ 2,744 Gains (losses) on undesignated oil, natural gas and NGL derivatives (62 ) 136 477 (110 ) Losses on terminated cash flow hedges (8 ) (7 ) (25 ) (24 ) Total oil, natural gas and NGL revenues $ 979 $ 1,177 $ 3,727 $ 2,610
Schedule of Derivative Instruments, Marketing, Gathering and Compression Revenues	The components of marketing, gathering and compression revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Marketing, gathering and compression revenues $ 964 $ 1,379 $ 3,250 $ 3,538 Losses on undesignated supply contract derivatives — (280 ) — (297 ) Total marketing, gathering and compression revenues $ 964 $ 1,099 $ 3,250 $ 3,241 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 Nine Months Ended 2017 2016 2017 2016 ($ in millions) Oil, natural gas and NGL revenues $ 1,049 $ 1,048 $ 3,275 $ 2,744 Gains (losses) on undesignated oil, natural gas and NGL derivatives (62 ) 136 477 (110 ) Losses on terminated cash flow hedges (8 ) (7 ) (25 ) (24 ) Total oil, natural gas and NGL revenues $ 979 $ 1,177 $ 3,727 $ 2,610
Interest Income And Interest Expense Disclosure	The components of interest expense for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Interest expense on senior notes $ 135 $ 141 $ 407 $ 446 Interest expense on term loan 34 14 98 14 Amortization of loan discount, issuance costs and other 13 9 28 27 Amortization of premium associated with troubled debt restructuring (29 ) (41 ) (112 ) (124 ) Interest expense on revolving credit facility 11 10 28 27 Gains on terminated fair value hedges (1 ) (1 ) (1 ) (2 ) Losses on undesignated interest rate derivatives — — 1 — Capitalized interest (49 ) (59 ) (147 ) (191 ) Total interest expense $ 114 $ 73 $ 302 $ 197
Schedule of Cash Flow Hedges Included in 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 September 30, 2017 2016 Before After Before After ($ in millions) Balance, beginning of period $ (132 ) $ (75 ) $ (163 ) $ (104 ) Net change in fair value — — (4 ) (4 ) Losses reclassified to income 8 8 7 7 Balance, end of period $ (124 ) $ (67 ) $ (160 ) $ (101 ) Nine Months Ended September 30, 2017 2016 Before After Before After ($ in millions) Balance, beginning of period $ (153 ) $ (96 ) $ (160 ) $ (99 ) Net change in fair value 4 4 (23 ) (23 ) Losses reclassified to income 25 25 23 21 Balance, end of period $ (124 ) $ (67 ) $ (160 ) $ (101 )
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of September 30, 2017 and December 31, 2016: 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 September 30, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ 55 $ 2 $ 57 Commodity liabilities — (38 ) (10 ) (48 ) Total derivatives $ — $ 17 $ (8 ) $ 9 As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of Chesapeake’s financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below. Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 1 — Total purchases, issuances, sales and settlements: Settlements 1 — Balance, as of September 30, 2017 $ (8 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 12 (118 ) Total purchases, issuances, sales and settlements: Settlements 49 (33 ) Sales — (146 ) Balance, as of September 30, 2016 $ (30 ) $ — ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 1 $ 12 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (7 ) $ (1 ) $ — $ — 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 September 30, 2017 and December 31, 2016 : 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 September 30, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (58 ) — — (58 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 )
Fair Value Inputs, Assets, Quantitative Information	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 September 30, 2017 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 15.30% – 26.67% 23.43% $ (9 ) Natural gas trades Natural gas price volatility curves 19.58% – 63.01% 38.24% $ 1

Oil and Natural Gas Property 39

Oil and Natural Gas Property Transactions (Tables)	9 Months Ended
	Sep. 30, 2017
Property, Plant and Equipment [Abstract]
VPP Transactions	As of September 30, 2017 , we had the following VPP outstanding: Volume Sold VPP # Date of VPP Location Proceeds Oil Natural Gas NGL Total ($ in millions) (mmbbl) (bcf) (mmbbl) (bcfe) 9 May 2011 Mid-Continent $ 853 1.7 138 4.8 177
VPP Volumes Produced During Period	The volumes produced on behalf of our VPP buyers during the Current Quarter, the Prior Quarter, the Current Period and the Prior Period were as follows: Three Months Ended September 30, 2017 Three Months Ended September 30, 2016 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 9 34.4 2.9 79.9 3.6 37.6 3.2 85.9 4.0 1 (a) — — — — — 3.1 — 3.1 34.4 2.9 79.9 3.6 37.6 6.3 85.9 7.1 Nine Months Ended September 30, 2017 Nine Months Ended September 30, 2016 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 10 (a) — — — — 108.0 3.0 368.7 5.8 9 105.5 9.0 243.9 11.0 115.5 9.9 262.8 12.2 4 (a) — — — — 20.0 3.8 — 3.9 3 (a) — — — — — 2.5 — 2.5 2 (a) — — — — — 1.5 — 1.5 1 (a) — — — — — 9.5 — 9.5 105.5 9.0 243.9 11.0 243.5 30.2 631.5 35.4 ____________________________________________ (a) In connection with certain asset divestitures in 2016, we purchased the remaining oil and natural gas interests previously sold in connection with VPP #10, VPP #4, VPP #3, VPP #2 and VPP #1. A majority of the oil and natural gas interests purchased were subsequently sold to the buyers of the assets.
VPP Volumes Remaining to Be Delivered	The volumes remaining to be delivered on behalf of our VPP buyers as of September 30, 2017 were as follows: Volume Remaining as of September 30, 2017 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 41 0.4 36.8 1.0 45.1

Impairments (Tables)

Impairments (Tables)	9 Months Ended
	Sep. 30, 2017
Asset Impairment Charges [Abstract]
Details of Impairment of Long-Lived Assets Held and Used by Asset	A summary of our impairments of fixed assets by asset class and other charges for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period is as follows: Three Months Ended Nine Months Ended 2017 2016 2017 2016 ($ in millions) Barnett Shale exit costs $ — $ 616 $ — $ 616 Gathering systems — 96 — 96 Natural gas compressors — 32 — 52 Buildings and land 1 7 3 14 Other 8 — 423 17 Total impairments of fixed assets and other $ 9 $ 751 $ 426 $ 795

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of September 30, 2017 and December 31, 2016: 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 September 30, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ 55 $ 2 $ 57 Commodity liabilities — (38 ) (10 ) (48 ) Total derivatives $ — $ 17 $ (8 ) $ 9 As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of Chesapeake’s financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below. Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 1 — Total purchases, issuances, sales and settlements: Settlements 1 — Balance, as of September 30, 2017 $ (8 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 12 (118 ) Total purchases, issuances, sales and settlements: Settlements 49 (33 ) Sales — (146 ) Balance, as of September 30, 2016 $ (30 ) $ — ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 1 $ 12 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (7 ) $ (1 ) $ — $ — 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 September 30, 2017 and December 31, 2016 : 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 September 30, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (58 ) — — (58 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 )

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2017
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Schedule of Segment Reporting Information, by Segment	The following table presents selected financial information for Chesapeake’s operating segments: Exploration and Production Marketing, Gathering and Compression Other Intercompany Eliminations Consolidated Total ($ in millions) Three Months Ended September 30, 2017 Revenues $ 979 $ 1,994 $ — $ (1,030 ) $ 1,943 Intersegment revenues — (1,030 ) — 1,030 — Total Revenues $ 979 $ 964 $ — $ — $ 1,943 Income (Loss) Before Income Taxes $ (14 ) $ 7 $ (10 ) $ — $ (17 ) Three Months Ended September 30, 2016 Revenues $ 1,177 $ 2,124 $ — $ (1,025 ) $ 2,276 Intersegment revenues — (1,025 ) — 1,025 — Total Revenues $ 1,177 $ 1,099 $ — $ — $ 2,276 Income (Loss) Before (as previously reported) $ (710 ) $ (211 ) $ (231 ) $ (2 ) $ (1,154 ) Income (Loss) Before Income Taxes (as revised) (a) $ (642 ) $ (339 ) $ (231 ) $ (2 ) $ (1,214 ) Nine Months Ended September 30, 2017 Revenues $ 3,727 $ 6,450 $ — $ (3,200 ) $ 6,977 Intersegment revenues — (3,200 ) — 3,200 — Total Revenues $ 3,727 $ 3,250 $ — $ — $ 6,977 Income (Loss) Before Income Taxes $ 1,094 $ (440 ) $ (32 ) $ (1 ) $ 621 Exploration and Production Marketing, Gathering and Compression Other Intercompany Eliminations Consolidated Total ($ in millions) Nine Months Ended September 30, 2016 Revenues $ 2,610 $ 5,897 $ — $ (2,656 ) $ 5,851 Intersegment revenues — (2,656 ) — 2,656 — Total Revenues $ 2,610 $ 3,241 $ — $ — $ 5,851 Income (Loss) Before (as previously reported) $ (3,360 ) $ (215 ) $ (248 ) $ (2 ) $ (3,825 ) Income (Loss) Before Income Taxes (as revised) (a) $ (3,465 ) $ (343 ) $ (248 ) $ (2 ) $ (4,058 ) As of September 30, 2017 Total Assets $ 10,451 $ 923 $ 994 $ (387 ) $ 11,981 As of December 31, 2016 Total Assets $ 11,249 $ 1,118 $ 1,059 $ (398 ) $ 13,028 _________________________________________ (a) We have revised the amounts presented in the Prior Quarter and the Prior Period. The impact of the errors was not material to any previously issued financial statements.

Basis of Presentation Basis of

Basis of Presentation Basis of Presentation, Condensed Consolidated Income Statement Restatements Table (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Oil, natural gas and NGL depreciation, depletion and amortization	$ 228	$ 251	$ 627	$ 791
Impairment of oil and natural gas properties	0	497	0	2,564
Total operating expenses	1,849	3,510	6,243	9,967
Loss from operations	94	(1,234)	734	(4,116)
Loss before income taxes	(17)	(1,214)	621	(4,058)
Net loss	(17)	(1,214)	619	(4,058)
Net loss attributable to Chesapeake	(18)	(1,215)	616	(4,059)
Net loss available to common stockholders	$ (41)	$ (1,257)	$ 506	$ (4,186)
Loss per common share basic	$ (0.05)	$ (1.62)	$ 0.56	$ (5.80)
Loss per common share diluted	$ (0.05)	$ (1.62)	$ 0.56	$ (5.80)
Scenario, Previously Reported [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Oil, natural gas and NGL depreciation, depletion and amortization		$ 255
Impairment of oil and natural gas properties		433		$ 2,331
Total operating expenses		3,450		9,734
Loss from operations		(1,174)		(3,883)
Loss before income taxes		(1,154)		(3,825)
Net loss		(1,154)		(3,825)
Net loss attributable to Chesapeake		(1,155)		(3,826)
Net loss available to common stockholders		$ (1,197)		$ (3,953)
Loss per common share basic		$ (1.54)		$ (5.47)
Loss per common share diluted		$ (1.54)		$ (5.47)
Restatement Adjustment [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Oil, natural gas and NGL depreciation, depletion and amortization		$ (4)
Impairment of oil and natural gas properties		64		$ 233
Total operating expenses		60		233
Loss from operations		(60)		(233)
Loss before income taxes		(60)		(233)
Net loss		(60)		(233)
Net loss attributable to Chesapeake		(60)		(233)
Net loss available to common stockholders		$ (60)		$ (233)
Loss per common share basic		$ (0.08)		$ (0.33)
Loss per common share diluted		$ (0.08)		$ (0.33)

Basis of Presentation Basis o44

Basis of Presentation Basis of Presentation, Condensed Consolidated Statements of Comprehensive Income (Loss) Restatements Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss	$ (17)	$ (1,214)	$ 619	$ (4,058)
Comprehensive loss	(9)	(1,211)	648	(4,060)
Comprehensive loss attributable to Chesapeake	$ (10)	(1,212)	$ 645	(4,061)
Scenario, Previously Reported [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss		(1,154)		(3,825)
Comprehensive loss		(1,151)		(3,827)
Comprehensive loss attributable to Chesapeake		(1,152)		(3,828)
Restatement Adjustment [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss		(60)		(233)
Comprehensive loss		(60)		(233)
Comprehensive loss attributable to Chesapeake		$ (60)		$ (233)

Basis of Presentation Basis o45

Basis of Presentation Basis of Presentation, Condensed Consolidated Statements of Cash Flows Restatements Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss	$ (17)	$ (1,214)	$ 619	$ (4,058)
Impairment of oil and natural gas properties	$ 0	497	$ 0	2,564
Scenario, Previously Reported [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss		(1,154)		(3,825)
Impairment of oil and natural gas properties		433		2,331
Restatement Adjustment [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net loss		(60)		(233)
Impairment of oil and natural gas properties		$ 64		$ 233

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities Excluded from Computation of EPS Table (Details) - shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Convertible Debt Securities [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	146	0	146	0
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	1	1	1
Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	60	112	60	112

Debt - Long-Term Debt Table (De

Debt - Long-Term Debt Table (Details) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)day$ / shares	Jun. 30, 2017USD ($)	Dec. 31, 2016USD ($)$ / €	Dec. 31, 2006$ / €
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 9,775		$ 9,989
Long-term Debt, Gross	9,899		10,441
Deferred Long-term Liability Charges	(62)		(64)
Debt, Current	0		506
Current Maturities of Long-term Debt, Net	0		(503)
Long-term Debt, Fair Value	9,775		9,483
Long-term Debt, Net	9,899		9,938
Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	0		0
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge	2		3
8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Premium	618		990
Term Loan [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,500		1,500
Long-term Debt, Gross	1,500		1,500
Senior Notes [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	0		258
Long-term Debt, Gross	0		$ 258
Senior Notes [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Cross Currency Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Derivative, Forward Exchange Rate | $ / €			1.0517	1.3325
Senior Notes [Member] | 6.5% Senior Notes Due 2017 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	0		$ 134
Long-term Debt, Gross	0		134
Senior Notes [Member] | 7.25% Senior Notes Due 2018 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	44		64
Long-term Debt, Gross	44		64
Senior Notes [Member] | Floating Rate Senior Notes Due 2019 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	380		380
Long-term Debt, Gross	380		380
Senior Notes [Member] | 6.625% Senior Notes Due 2020 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	572		780
Long-term Debt, Gross	572		780
Senior Notes [Member] | 6.875% Senior Notes Due 2020 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	279		279
Long-term Debt, Gross	278		278
Senior Notes [Member] | 6.125% Senior Notes Due 2021 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	550		550
Long-term Debt, Gross	550		550
Senior Notes [Member] | 5.375% Senior Notes Due 2021 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	270		270
Long-term Debt, Gross	270		270
Senior Notes [Member] | 4.875% Senior Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	451		451
Long-term Debt, Gross	451		451
Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,737		2,419
Long-term Debt, Gross	2,355		3,409
Debt Instrument, Unamortized Premium	260
Senior Notes [Member] | 5.75% Senior Notes Due 2023 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	338		338
Long-term Debt, Gross	338		338
Senior Notes [Member] | 8.00% Senior Notes Due 2025 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,000		1,000
Long-term Debt, Gross	987		985
Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	750	$ 750	0
Long-term Debt, Gross	$ 750		0
Debt Instrument, Redemption Price, Percentage	108.00%
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	35.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,250		1,250
Long-term Debt, Gross	$ 831		811
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member] | Optional Conversion by Holders [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Convertible, Terms of Conversion Feature | day	5
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger	130.00%
Debt Instrument, Convertible, Conversion Price | $ / shares	$ 8.568
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	100.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member] | Optional Redemption by the Company [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger	130.00%
Debt Instrument, Date of First Required Payment	Sep. 15, 2019
Debt Instrument, Redemption Price, Percentage	100.00%
Convertible Debt [Member] | 2.75% Contingent Convertible Senior Notes Due 2035 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 0		2
Long-term Debt, Gross	0		2
Convertible Debt [Member] | 2.5% Contingent Convertible Senior Notes Due 2037 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	0		114
Long-term Debt, Gross	0		112
Convertible Debt [Member] | 2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	9		200
Long-term Debt, Gross	8		180
Convertible Debt [Member] | All Convertible and All Contingent Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	(420)		(461)
Line of Credit [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	645		0
Long-term Line of Credit	$ 645		$ 0

Debt - Long Term Debt Table (Ph

Debt - Long Term Debt Table (Phantom) (Details)	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Term Loan [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument Maturity Date	Aug. 23, 2021
6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member] | Cross Currency Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.25%				6.25%
Debt Instrument Maturity Date	Jan. 15, 2017
6.5% Senior Notes Due 2017 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Debt Instrument Maturity Date	Aug. 15, 2017
7.25% Senior Notes Due 2018 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.25%
Debt Instrument Maturity Date	Dec. 15, 2018
Floating Rate Senior Notes Due 2019 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument Maturity Date	Apr. 15, 2019
6.625% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.625%
Debt Instrument Maturity Date	Aug. 15, 2020
6.875% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.875%
Debt Instrument Maturity Date	Nov. 15, 2020
6.125% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.125%
Debt Instrument Maturity Date	Feb. 15, 2021
5.375% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.375%
Debt Instrument Maturity Date	Jun. 15, 2021
4.875% Senior Notes Due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.875%
Debt Instrument Maturity Date	Apr. 15, 2022
8.00% Senior Secured Second Lien Notes Due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%
Debt Instrument Maturity Date	Dec. 15, 2022
5.75% Senior Notes Due 2023 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Debt Instrument Maturity Date	Mar. 15, 2023
8.00% Senior Notes Due 2025 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%				8.00%
Debt Instrument Maturity Date	Jan. 15, 2025
5.5% Convertible Senior Notes Due 2026 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument Maturity Date	Jun. 15, 2026
8.00% Senior Notes Due 2027 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%			8.00%
Debt Instrument Maturity Date	Jun. 15, 2027
2.75% Contingent Convertible Senior Notes Due 2035 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.75%
Debt Instrument Maturity Date	Nov. 15, 2035
2.5% Contingent Convertible Senior Notes Due 2037 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Debt Instrument Maturity Date	May 15, 2037
2.25% Contingent Convertible Senior Notes Due 2038 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument Maturity Date	Dec. 15, 2038
Maximum [Member] | Scenario, Forecast [Member] | First Lien [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		0.65	0.65

Debt Debt - Debt Issuances and

Debt Debt - Debt Issuances and Retirements (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Jun. 30, 2017	Dec. 31, 2016
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 9,775		$ 9,775			$ 9,989
Cash Paid to Purchase Debt			1,751	$ 1,979
Gains (Losses) on Purchases or Exchanges of Debt	(1)	$ 87	183	255
8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Premium	618		618			990
Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 750		$ 750		$ 750	0
Debt Instrument, Interest Rate, Stated Percentage	8.00%		8.00%		8.00%
Proceeds from Issuance of Senior Long-term Debt			$ 742
Debt Instrument, Redemption, Description			Some or all of the notes may be redeemed at any time prior to June 15, 2022, subject to a make-whole premium. We also may redeem some or all of the notes at any time on or after June 15, 2022, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed			35.00%
Debt Instrument, Redemption Period, Start Date			Jun. 15, 2020
Debt Instrument, Redemption Price, Percentage			108.00%
Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,737		$ 1,737			$ 2,419
Debt Instrument, Interest Rate, Stated Percentage	8.00%		8.00%
Debt Instrument, Unamortized Premium	$ 260		$ 260
Senior Notes, Sr. Secured Notes, Contingent Convertible Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 1,609		1,609
Cash Paid to Purchase Debt			$ 1,751
Senior Notes and Contingent Convertible Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount		2,192		2,192
Cash Paid to Purchase Debt				1,500
Senior Notes and Contingent Convertible Senior Notes [Member] | Privately Negotiated Exchanges for Common Stock [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchase Amount		$ 577		$ 577
Debt Conversion, Converted Instrument, Shares Issued				109,351,707

Debt Debt - Term Loan (Details)

Debt Debt - Term Loan (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Aug. 22, 2019	Aug. 22, 2018	Dec. 31, 2016
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Face Amount	$ 9,775			$ 9,989
Term Loan [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Term	5 years
Debt Instrument, Face Amount	$ 1,500			$ 1,500
Term Loan [Member] | Scenario, Forecast [Member]
Debt Instrument, Term Loan [Line Items]
Premium to Par Percentage, Prior to 3rd Anniversary			4.25%
Premium to Par Percentage Prior to 4th Anniversary		2.125%
Term Loan [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Basis Spread on Variable Rate	7.50%
Debt Instrument, Floor Rate	1.00%
Term Loan [Member] | Alternative Base Rate (ABR) [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Basis Spread on Variable Rate	6.50%
Debt Instrument, Floor Rate	2.00%

Debt - Senior Notes, Contingent

Debt - Senior Notes, Contingent Convertible Senior Notes and Convertible Senior Notes Narrative (Details)	Sep. 30, 2017
Long-Term Debt Instrument [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent	100.00%
Convertible Debt [Member] | 2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument, Interest Rate, Effective Percentage	8.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument, Interest Rate, Effective Percentage	11.50%

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility Narrative (Details) $ in Millions	3 Months Ended		9 Months Ended	12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2018	Oct. 30, 2017USD ($)	Oct. 13, 2017USD ($)	Dec. 31, 2016USD ($)
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 9,775	$ 9,775				$ 9,989
Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity							3,800
Letters of Credit Outstanding, Amount		$ 97	97
Minimum Liquidity Requirement When Covenant Ratio Is At Or Above 1.1 to 1.0			500
Interest Coverage Ratio		1.2 to 1.0
Revolving Credit Facility [Member] | Subsequent Event [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity					$ 3,800
Revolving Credit Facility [Member] | Maximum [Member] | Subsequent Event [Member]
Long-Term Debt Instrument [Line Items]
Additional Indebtedness After Term Loan						$ 1,200
Revolving Credit Facility [Member] | First Lien [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Additional Indebtedness		$ 2,500	2,500
Revolving Credit Facility [Member] | Scenario, Forecast [Member]
Long-Term Debt Instrument [Line Items]
Interest Coverage Ratio	1.25 to 1.0
Revolving Credit Facility [Member] | Scenario, Forecast [Member] | First Lien [Member]
Long-Term Debt Instrument [Line Items]
Leverage Ratio	3.50 to 1.0			3.00 to 1.0
Revolving Credit Facility [Member] | Scenario, Forecast [Member] | First Lien [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital	0.65			0.65
Revolving Credit Facility [Member] | Line of Credit [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 645	$ 645				$ 0

Debt - Fair Value of Other Fina

Debt - Fair Value of Other Financial Instruments (Table) (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 9,775	$ 9,483
Fair Value, Inputs, Level 1 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term Debt, Fair Value	0	503
Long-term Debt, Fair Value	2,876	3,271
Fair Value, Inputs, Level 1 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term Debt, Fair Value	0	511
Long-term Debt, Fair Value	2,861	3,216
Fair Value, Inputs, Level 2 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	7,021	6,664
Fair Value, Inputs, Level 2 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 7,035	$ 6,654

Commitments - Undiscounted Gath

Commitments - Undiscounted Gathering Processing and Transportation Agreements Commitments Table (Details) - Gathering, Processing and Transportation Agreement [Member] $ in Millions	Sep. 30, 2017USD ($)
Other Commitments [Line Items]
Gathering, Processing and Transportation Commitment, Due Remainder of Fiscal Year	$ 331
Gathering, Processing and Transportation Commitment, Due in Second Year	1,096
Gathering, Processing and Transportation Commitment, Due in Third Year	1,062
Gathering, Processing and Transportation Commitment, Due in Fourth Year	990
Gathering, Processing and Transportation Commitment, Due in Fifth Year	894
Gathering, Processing and Transportation Commitment, Due after Fifth Year	5,214
Gathering, Processing and Transportation Commitment	$ 9,587

Commitments - Narrative (Detail

Commitments - Narrative (Details) $ in Millions	Sep. 30, 2017USD ($)
Drilling Rig Leases [Member]
Long-term Purchase Commitment [Line Items]
Contractual Obligation	$ 31

Other Liabilities - Current Tab

Other Liabilities - Current Table (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Other Current Liabilities [Line Items]
Current revenues and royalties due others	$ 474	$ 543
Accrued drilling and production costs	313	169
Joint interest prepayments received	72	71
Accrued compensation and benefits	195	239
Other accrued taxes	73	32
Bank of New York Mellon legal accrual(a)	0	440
Other	270	304
Total other current liabilities	$ 1,397	$ 1,798
Senior Notes [Member] | 6.775 Senior Notes due 2019 [Member]
Other Current Liabilities [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.775%
Redemption of 2019 Notes [Member] | Senior Notes [Member] | 6.775 Senior Notes due 2019 [Member]
Other Current Liabilities [Line Items]
Payments for Legal Settlements	$ 441

Other Liabilities - Long-Term T

Other Liabilities - Long-Term Table (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)well	Dec. 31, 2016USD ($)
Other Long-Term Liabilities [Line Items]
CHK Utica ORRI conveyance obligation	$ 159	$ 160
Unrecognized tax benefits	99	97
Other	102	126
Total other long-term liabilities	360	383
Current revenues and royalties due others	$ 474	543
Noncontrolling Interest, Chesapeake Utica L L C [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Overriding royalty interest percentage	3.00%
Number of wells, net | well	1,500
Percentage of increase In leasehold in which commitment to drill Is not met	4.00%
Current revenues and royalties due others	$ 30	$ 43

Equity Equity - Common Stock Ta

Equity Equity - Common Stock Table (Details) - shares	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	896,279,353
Common Stock, Shares, Issued End of Period	908,662,243
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	896,279,000	664,796,000
Restricted stock issuances (net of forfeitures and cancellations)	2,417,000	1,852,000
Common Stock, Shares, Issued End of Period	908,662,000	777,021,000
Common Stock [Member] | Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	55,428,000
Common Stock [Member] | Senior Notes Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	53,924,000
Common Stock [Member] | Preferred Stock, Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	9,966,000	1,021,000

Equity - Preferred Stock Table

Equity - Preferred Stock Table (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period			5,839,506
Preferred Stock, Shares Outstanding, End of Period	5,603,458		5,603,458
Loss on Exchange of Preferred Stock	$ 0	$ 0	$ (41)	$ 0
5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage			5.75%
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage			5.75%
4.50% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage			4.50%
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage			5.00%
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period			843,000	1,497,000
Conversion of Stock, Shares Converted			(72,600)	(24,601)
Preferred Stock, Liquidation Preference Per Share	$ 1,000		$ 1,000
Preferred Stock, Shares Outstanding, End of Period	770,000	1,472,000	770,000	1,472,000
Preferred Stock, Dividend Rate, Percentage			5.75%
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period			476,000	1,100,000
Conversion of Stock, Shares Converted			(12,500)	(1,201)
Preferred Stock, Liquidation Preference Per Share	$ 1,000		$ 1,000
Preferred Stock, Shares Outstanding, End of Period	463,000	1,099,000	463,000	1,099,000
Preferred Stock, Dividend Rate, Percentage			5.75%
Preferred Stock [Member] | 4.50% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period			2,559,000	2,559,000
Conversion of Stock, Shares Converted			0	0
Preferred Stock, Liquidation Preference Per Share	$ 100		$ 100
Preferred Stock, Shares Outstanding, End of Period	2,559,000	2,559,000	2,559,000	2,559,000
Preferred Stock [Member] | 5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period			1,962,000	2,096,000
Conversion of Stock, Shares Converted			(150,948)	0
Preferred Stock, Liquidation Preference Per Share	$ 100		$ 100
Preferred Stock, Shares Outstanding, End of Period	1,811,000	2,096,000	1,811,000	2,096,000
Common Stock [Member] | 5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities			7,442,156	975,488
Common Stock [Member] | 5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities			1,205,923	46,018
Common Stock [Member] | 5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities			1,317,756

Equity - AOCI Changes Net of Ta

Equity - AOCI Changes Net of Tax Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period			$ (96)
Other Comprehensive Income (Loss)	$ 8	$ 3	29	$ (2)
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	(67)		(67)
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period			(96)	(99)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			4	(23)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	8	7	25	21
Other Comprehensive Income (Loss)			29	(2)
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	$ (67)	$ (101)	$ (67)	$ (101)

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Schedule of Capitalization, Equity [Line Items]
Common Stock, Shares Authorized	2,000,000,000		2,000,000,000		1,500,000,000
Common Stock, Par Value (usd per share)	$ 0.01		$ 0.01		$ 0.01
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest [Member]
Schedule of Capitalization, Equity [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	$ 8	$ 7	$ 25	$ 21
5.75% Cumulative Convertible Preferred Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage			5.75%
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage			5.75%
4.50% Cumulative Convertible Preferred Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage			4.50%
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage			5.00%

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock Table (Details) - Restricted Stock [Member] shares in Thousands	9 Months Ended
	Sep. 30, 2017$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Shares, Period Start | shares	9,092
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | shares	9,872
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period | shares	(4,481)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period | shares	(942)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Shares, Period End | shares	13,541
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Period Start | $ / shares	$ 11.39
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ / shares	5.40
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ / shares	13.63
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ / shares	8.85
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Period End | $ / shares	$ 6.46

Share-Based Compensation - Equi

Share-Based Compensation - Equity-Classified Valuation Table (Details) - Employee Stock Option [Member]	9 Months Ended
	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	6 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	62.42%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	2.17%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%

Share-Based Compensation - Stoc

Share-Based Compensation - Stock Option Activity Table (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number Period Start	8,593
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	9,226
Share Based Compensation Arrangement By Share Based Payment Award Shares Underlying Options Exercised In Period	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Expirations in Period	(524)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested Options Forfeited, Number of Shares	(904)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number Period End	16,391	8,593
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	4,490
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price Period Start	$ 11.88
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price	5.45
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price	0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Expirations in Period, Weighted Average Exercise Price	18.45
Share-based Compensation Arrangements by Share-based Payment Award, Options, Forfeitures in Period, Weighted Average Exercise Price	9.91
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price Period End	8.16	$ 11.88
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 15.22
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	8 years 14 days	7 years 2 months 18 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	5 years 5 months 26 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value Period Start	$ 14
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Intrinsic Value	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value Period End	2	$ 14
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value	$ 1

Share-Based Compensation - Eq65

Share-Based Compensation - Equity-Classified Compensation Table (Details) - Restricted Stock and Stock Options [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 14	$ 18	$ 48	$ 52
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	9	10	29	28
Oil and Natural Gas Properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	3	4	10	13
Oil, Natural Gas and NGL Production Expenses Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	2	4	9	10
Marketing, Gathering and Compression Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 0	$ 0	$ 0	$ 1

Share-Based Compensation - Liab

Share-Based Compensation - Liability Classified Valuation Table (Details) - Performance Shares [Member]	9 Months Ended
	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	87.16%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.51%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%

Share-Based Compensation - Perf

Share-Based Compensation - Performance Share Unit Breakout (Details) - Performance Shares [Member] - USD ($) $ in Millions	Sep. 30, 2017	Jan. 01, 2017	Jan. 01, 2016	Jan. 01, 2015
Award Year 2017, Payable 2020 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	1,217,774
Fair Value of Share Based Award	$ 6	$ 8
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 2
Award Year 2016, Payable 2019 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	2,348,893
Fair Value of Share Based Award	$ 9		$ 10
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 8
Award Year 2015, Payable 2018 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	629,694
Fair Value of Share Based Award	$ 1			$ 13
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 1

Share-Based Compensation - Li68

Share-Based Compensation - Liability-Classified Compensation Table (Details) - Performance Shares [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ (2)	$ 7	$ (4)	$ 11
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	(2)	7	(4)	10
Restructuring and Other Termination Costs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 0	$ 0	$ 0	$ 1

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$ 25
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 59
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	1 year 11 months 21 days
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	2 years 3 months 11 days
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Black-Scholes option pricing model
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Stock Options	$ 26
Employee Stock Option [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	33.30%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Employee Stock Option [Member] | Management [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	7 years
Employee Stock Option [Member] | Management [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	10 years
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Monte Carlo simulation
Performance Shares [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Performance Share Units Maximum Payout Percentage	200.00%
Performance Share Grant Maximum Payout Percentage	100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	less than zero
Performance Shares [Member] | Management [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	0.00%
Operational Component Percentage Performance Share Units	0.00%
Performance Shares [Member] | Management [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	100.00%
Operational Component Percentage Performance Share Units	100.00%

Derivative and Hedging Activi70

Derivative and Hedging Activities - Derivative Instruments Table (Details) gal in Millions, MMBbls in Millions, $ in Millions, MMBTU in Trillions	9 Months Ended	12 Months Ended
	Sep. 30, 2017USD ($)MMBTUgalMMBbls	Dec. 31, 2016USD ($)MMBTUgalMMBbls
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 9	$ (577)
Energy Related Derivative [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 9	$ (504)
Energy Related Derivative [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	26	28
Derivative Assets (Liabilities), at Fair Value, Net	$ (27)	$ (141)
Energy Related Derivative [Member] | Oil [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	18	23
Derivative Assets (Liabilities), at Fair Value, Net	$ (17)	$ (140)
Energy Related Derivative [Member] | Oil [Member] | Three Way Collar [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	2	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (2)	$ 0
Energy Related Derivative [Member] | Oil [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	1	5
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ (1)
Energy Related Derivative [Member] | Oil [Member] | Call Swaption [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	2	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (7)	$ 0
Energy Related Derivative [Member] | Oil [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	3	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (1)	$ 0
Energy Related Derivative [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	914	924
Derivative Assets (Liabilities), at Fair Value, Net	$ 38	$ (363)
Energy Related Derivative [Member] | Natural Gas [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	696	719
Derivative Assets (Liabilities), at Fair Value, Net	$ 38	$ (349)
Energy Related Derivative [Member] | Natural Gas [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	121	114
Derivative Assets (Liabilities), at Fair Value, Net	$ (7)	$ 0
Energy Related Derivative [Member] | Natural Gas [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	26	31
Derivative Assets (Liabilities), at Fair Value, Net	$ (1)	$ (5)
Energy Related Derivative [Member] | Natural Gas [Member] | Collar [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	71	60
Derivative Assets (Liabilities), at Fair Value, Net	$ 8	$ (9)
Energy Related Derivative [Member] | NGL [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	15	53
Derivative Assets (Liabilities), at Fair Value, Net	$ (2)	$ 0

Derivative and Hedging Activi71

Derivative and Hedging Activities - Derivative Instruments in Balance Sheet Table (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		$ (577)
Derivative Asset, Fair Value, Gross Liability		0
Derivative, Fair Value, Net	$ 9	(577)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	10
Derivative Liability, Fair Value, Gross Asset	(1)
Derivative, Fair Value, Net	9
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	10	(504)
Derivative Liability, Fair Value, Gross Asset	(1)	0
Derivative, Fair Value, Net	9	(504)
Designated as Hedging Instrument [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		(73)
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net		(73)
Other Current Assets [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	57	1
Derivative Asset, Fair Value, Gross Liability	(29)	(1)
Derivative, Fair Value, Net	28	0
Other Current Liabilities [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(37)	(490)
Derivative Liability, Fair Value, Gross Asset	29	1
Derivative, Fair Value, Net	(8)	(489)
Other Current Liabilities [Member] | Designated as Hedging Instrument [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		(73)
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net		(73)
Other Noncurrent Assets [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1
Derivative Asset, Fair Value, Gross Liability	(1)
Derivative, Fair Value, Net	0
Other Noncurrent Liabilities [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(11)	(15)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	$ (11)	$ (15)

Derivative and Hedging Activi72

Derivative and Hedging Activities Derivative and Hedging Activities - Oil, Natural Gas and NGL Revenues Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative [Line Items]
Oil and Gas Revenue	$ 1,049	$ 1,048	$ 3,275	$ 2,744
Oil and Gas Sales Revenue	979	1,177	3,727	2,610
Oil, Natural Gas and NGL Sales [Member]
Derivative [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	(8)	(7)	(25)	(24)
Oil, Natural Gas and NGL Sales [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (62)	$ 136	$ 477	$ (110)

Derivative and Hedging Activi73

Derivative and Hedging Activities Derivative and Hedging Actitities - Marketing, Gathering and Compression Revenues Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative [Line Items]
Revenues	$ 1,943	$ 2,276	$ 6,977	$ 5,851
Marketing, gathering and compression	964	1,099	3,250	3,241
Marketing, Gathering And Compression [Member]
Derivative [Line Items]
Revenues	964	1,379	3,250	3,538
Marketing, Gathering And Compression [Member] | Supply Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ (280)	$ 0	$ (297)

Derivative and Hedging Activi74

Derivative and Hedging Activities - Components of Interest Income and Interest Expense Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Interest expense on senior notes	$ 135	$ 141	$ 407	$ 446
Interest expense on term loan	34	14	98	14
Amortization of loan discount, issuance costs and other	13	9	28	27
Amortization of premium associated with troubled debt restructuring	(29)	(41)	(112)	(124)
Interest expense on revolving credit facility	11	10	28	27
Gains on terminated fair value hedges	(1)	(1)	(1)	(2)
Losses on undesignated interest rate derivatives	0	0	1	0
Capitalized interest	(49)	(59)	(147)	(191)
Total interest expense	$ 114	$ 73	$ 302	$ 197

Derivative and Hedging Activi75

Derivative and Hedging Activities - Cash Flow Hedges Components of AOCI Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period			$ (96)
Other Comprehensive Income (Loss), Net Change in Fair Value, Net of Tax	$ 0	$ (4)	4	$ (23)
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	8	7	25	21
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	(67)		(67)
Cash Flow Hedging [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Before Tax, Beginning of Periodt	(132)	(163)	(153)	(160)
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period	(75)	(104)	(96)	(99)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Before Tax	0	(4)	4	(23)
Other Comprehensive Income (Loss), Losses Reclassified to Income, Before Tax	8	7	25	23
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	8	7	25	21
Accumulated Other Comprehensive Income (Loss), Before Tax, End of Period	(124)	(160)	(124)	(160)
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	$ (67)	$ (101)	$ (67)	$ (101)

Derivative and Hedging Activi76

Derivative and Hedging Activities - Fair Value of Recurring Assets and Liabilities Table (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 9	$ (577)
Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	57	1
Derivative Liability	(48)	(505)
Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		(73)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Fair Value, Inputs, Level 1 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	0	0
Derivative Liability	0	0
Fair Value, Inputs, Level 1 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	17	(567)
Fair Value, Inputs, Level 2 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	55	1
Derivative Liability	(38)	(495)
Fair Value, Inputs, Level 2 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		(73)
Fair Value, Inputs, Level 3 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(8)	(10)
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	2	0
Derivative Liability	(10)	(10)
Derivative Assets (Liabilities), at Fair Value, Net	$ (8)	(10)	$ (30)	$ (91)
Fair Value, Inputs, Level 3 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		$ 0

Derivative and Hedging Activi77

Derivative and Hedging Activities - Fair Value Level 3 Measurements Table (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	$ (577)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	9
Energy Related Derivative [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(504)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	9
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(10)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(8)
Fair Value, Inputs, Level 3 [Member] | Oil, Natural Gas and NGL Sales [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	1	$ 12
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	(7)	(1)
Fair Value, Inputs, Level 3 [Member] | Marketing, Gathering and Compression Revenue [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	(118)
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	0	0
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(10)	(91)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	1	12
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	1	49
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Sales		0
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(8)	(30)
Fair Value, Inputs, Level 3 [Member] | Supply Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	0	297
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	(118)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	0	(33)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Sales		(146)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	$ 0	$ 0

Derivative and Hedging Activi78

Derivative and Hedging Activities - Quantitative Disclosures Level 3 Table (Details) - Energy Related Derivative [Member] $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)
Oil [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	23.43%
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (9)
Oil [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	0.153%
Oil [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	0.2667%
Natural Gas [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	38.24%
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 1
Natural Gas [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	0.1958%
Natural Gas [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	0.6301%

Derivative and Hedging Activi79

Derivative and Hedging Activities - Narrative (Details) € in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)counterpartyDerivatives	Sep. 30, 2016USD ($)	Sep. 30, 2017EUR (€)counterpartyDerivatives	Dec. 31, 2016USD ($)Derivatives$ / €	Dec. 31, 2006$ / €
Derivative [Line Items]
Number of Interest Rate Derivatives Held | Derivatives		0		0	0
Derivative Liability, Fair Value, Gross Liability					$ 577,000,000
Losses on Undesignated Supply Contract Derivatives	$ (280,000,000)		$ (297,000,000)
Cash Collateral for Borrowed Securities		$ 0			$ 0
Expected Amount to be Transferred of During the Next 12 Months		$ 19,000,000
Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Number of Instruments Held | Derivatives		0		0	0
Interest Rate Contract [Member]
Derivative [Line Items]
Amortization Period of Deferred Gain (Loss) on Discontinuation of Fair Value Hedge		3 years
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		$ 2,000,000			$ 3,000,000
Cross Currency Interest Rate Contract [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.25%		6.25%	6.25%
Semi Annual Interest Rate Swap Payments By Counterparty | €				€ 246
Semi Annual Interest Rate Swap Payments by Chesapeake		$ 327,000,000
Derivative, Forward Exchange Rate | $ / €					1.0517	1.3325
Foreign Exchange Contract [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability					$ 73,000,000
Supply Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative [Line Items]
Gain (Loss) on Sale of Derivatives	$ 146,000,000
Credit Risk [Member]
Derivative [Line Items]
Number of counterparties in hedge facility | counterparty		10		10

Oil and Natural Gas Property 80

Oil and Natural Gas Property Transactions - VPP Transactions Table (Details) - VPP 9 Mid-Continent [Member] MMBbls in Millions, $ in Millions, Bcfe in Billions, Bcf in Billions	May 31, 2011USD ($)BcfeBcfMMBbls
VPP Transactions [Line Items]
Cash Proceeds from Volumetric Production Payment (VPP) | $	$ 853
Proved Developed Reserves (Energy) | Bcfe	177
Oil [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)	1.7
Natural Gas [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume) | Bcf	138
NGL [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)	4.8

Oil and Natural Gas Property 81

Oil and Natural Gas Property Transactions - VPP Volumes Produced During Period Table (Details) Bcfe in Billions, Bcf in Billions	3 Months Ended		9 Months Ended
	Sep. 30, 2017BcfeMBblsBcf	Sep. 30, 2016BcfeMBblsBcf	Sep. 30, 2017BcfeMBblsBcf	Sep. 30, 2016BcfeMBblsBcf
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe	3.6	7.1	11	35.4
Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	34,400	37,600	105,500	243,500
Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf	2.9	6.3	9	30.2
NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	79,900	85,900	243,900	631,500
VPP 10 Anadarko Basin Granite Wash [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe			0	5.8
VPP 10 Anadarko Basin Granite Wash [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	108,000
VPP 10 Anadarko Basin Granite Wash [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf			0	3
VPP 10 Anadarko Basin Granite Wash [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	368,700
VPP 9 Mid-Continent [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe	3.6	4	11	12.2
VPP 9 Mid-Continent [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	34,400	37,600	105,500	115,500
VPP 9 Mid-Continent [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf	2.9	3.2	9	9.9
VPP 9 Mid-Continent [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	79,900	85,900	243,900	262,800
VPP 4 Anadarko and Arkoma Basins [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe			0	3.9
VPP 4 Anadarko and Arkoma Basins [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	20,000
VPP 4 Anadarko and Arkoma Basins [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf			0	3.8
VPP 4 Anadarko and Arkoma Basins [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	0
VPP 3 Anadarko Basin [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe			0	2.5
VPP 3 Anadarko Basin [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	0
VPP 3 Anadarko Basin [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf			0	2.5
VPP 3 Anadarko Basin [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	0
VPP 2 Texas, Oklahoma and Kansas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe			0	1.5
VPP 2 Texas, Oklahoma and Kansas [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	0
VPP 2 Texas, Oklahoma and Kansas [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf			0	1.5
VPP 2 Texas, Oklahoma and Kansas [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production			0	0
VPP 1 Kentucky and West Virginia [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Bcfe	0	3.1	0	9.5
VPP 1 Kentucky and West Virginia [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0
VPP 1 Kentucky and West Virginia [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Bcf	0	3.1	0	9.5
VPP 1 Kentucky and West Virginia [Member] | NGL [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0

Oil and Natural Gas Property 82

Oil and Natural Gas Property Transactions - VPP Volume Remaining to Be Delivered Table (Details) - VPP 9 Mid-Continent [Member] MMBbls in Millions, Bcf in Millions, Bcfe in Billions	9 Months Ended
	Sep. 30, 2017BcfeBcfMMBbls	May 31, 2011BcfeBcfMMBbls
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Bcfe		177
Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Term Remaining (in Months)	41 months
Proved Developed Reserves (Energy) | Bcfe	45.1
Oil [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)		1.7
Oil [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)	0.4
Natural Gas [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Bcf		138,000
Natural Gas [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Bcf	36.8
NGL [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)		4.8
NGL [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)	1

Oil and Natural Gas Property 83

Oil and Natural Gas Property Transactions - Narrative (Details) MMcf in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017USD ($)wellMMcf	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)awellMMcf	Sep. 30, 2016USD ($)
Business Acquisition [Line Items]
Proceeds From Divestitures of Proved and Unproved Properties			$ 1,193,000,000	$ 988,000,000
Corporate VPP [Member]
Business Acquisition [Line Items]
Payments to Acquire Oil and Gas Property				259,000,000
Gain (Loss) on Disposition of Other Assets			0
Haynesville Shale [Member]
Business Acquisition [Line Items]
Proceeds From Divestitures of Proved and Unproved Properties			$ 915,000,000
Number Of Net Acres | a			119,500
Productive Gas Wells, Number of Wells, Net | well	576		576
Payments to Acquire Oil and Gas Property		$ 85,000,000
Haynesville Shale [Member] | Natural Gas [Member]
Business Acquisition [Line Items]
Proved Developed Reserves (Volume) | MMcf	80		80
Other Properties [Member]
Business Acquisition [Line Items]
Proceeds From Divestitures of Proved and Unproved Properties	$ 248,000,000	$ 26,000,000	$ 331,000,000	$ 988,000,000

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Variable Interest Entity [Line Items]
Noncontrolling interests on condensed consolidated balance sheets	$ 253		$ 253		$ 257
Net income attributable to noncontrolling interests, Trust	1	$ 1	3	$ 1
VIE, cash and cash equivalents	5		5		882
VIE. proved oil and natural gas properties	68,095		68,095		66,451
VIE. accumulated depreciation, depletion and amortization	63,375		63,375		62,726
VIE, other current liabilities	1,397		1,397
Variable Interest Entities, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
VIE, cash and cash equivalents	1		1		1
VIE. proved oil and natural gas properties	488		488		488
VIE. accumulated depreciation, depletion and amortization	460		460		$ 458
VIE, other current liabilities	$ 4		$ 4

Impairments Impairments - Fixed

Impairments Impairments - Fixed Assets and Other Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	$ 9	$ 751	$ 426	$ 795
Other, Barnett Shale Exit Costs [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	616	0	616
Exploration and Production Equipment [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	96	0	96
Natural Gas Compressor [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	32	0	52
Buildings and Land [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	1	7	3	14
Other [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	$ 8	$ 0	$ 423	$ 17

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Impairment of Oil and Natural Gas Properties	$ 0	$ 497	$ 0	$ 2,564
Impairments of Fixed Assets and Other	9	751	426	795
Loss on Transportation Agreement	$ 978	1,261	3,333	$ 3,410
Other, Barnett Shale Exit Costs,Termination of Gathering Agreement [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		334
Other, Barnett Shale Exit Costs, Other Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		282
Exploration and Production Equipment, Buildings and Land, Devonian Shale [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		$ 134
Transportation Equipment [Member] | Natural Gas [Member]
Property, Plant and Equipment [Line Items]
Loss on Contract Termination			126
Transportation Equipment [Member] | Oil [Member]
Property, Plant and Equipment [Line Items]
Loss on Transportation Agreement			$ 290

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Table (Details) - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	$ (1)	$ (2)
Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	57	49
Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	(58)	(51)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	(1)	(2)
Fair Value, Inputs, Level 1 [Member] | Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	57	49
Fair Value, Inputs, Level 1 [Member] | Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	(58)	(51)
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	0	0
Fair Value, Inputs, Level 2 [Member] | Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	0	0
Fair Value, Inputs, Level 3 [Member] | Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	$ 0	$ 0

Segment Information - Table (De

Segment Information - Table (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Segment Reporting Information [Line Items]
Operating Revenues	$ 979	$ 1,177	$ 3,727	$ 2,610
Revenues	1,943	2,276	6,977	5,851
Income (Loss) Before Income Taxes	(17)	(1,214)	621	(4,058)
TOTAL ASSETS	11,981		11,981		$ 13,028
Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
Income (Loss) Before Income Taxes		(1,154)		(3,825)
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating Revenues	(1,030)	(1,025)	(3,200)	(2,656)
Intersegment Revenues	1,030	1,025	3,200	2,656
Revenues	0	0	0	0
Income (Loss) Before Income Taxes	0	(2)	(1)	(2)
TOTAL ASSETS	(387)		(387)		(398)
Intersegment Eliminations [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
Income (Loss) Before Income Taxes		(2)		(2)
Segment Reconciling Items [Member]
Segment Reporting Information [Line Items]
Operating Revenues	1,943	2,276	6,977	5,851
Intersegment Revenues	0	0	0	0
Exploration And Production [Member]
Segment Reporting Information [Line Items]
Revenues	979	1,177	3,727	2,610
Exploration And Production [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating Revenues	979	1,177	3,727	2,610
Intersegment Revenues	0	0	0	0
Income (Loss) Before Income Taxes	(14)	(642)	1,094	(3,465)
TOTAL ASSETS	10,451		10,451		11,249
Exploration And Production [Member] | Operating Segments [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
Income (Loss) Before Income Taxes		(710)		(3,360)
Marketing, Gathering And Compression [Member]
Segment Reporting Information [Line Items]
Revenues	964	1,099	3,250	3,241
Marketing, Gathering And Compression [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating Revenues	1,994	2,124	6,450	5,897
Intersegment Revenues	(1,030)	(1,025)	(3,200)	(2,656)
Income (Loss) Before Income Taxes	7	(339)	(440)	(343)
TOTAL ASSETS	923		923		1,118
Marketing, Gathering And Compression [Member] | Operating Segments [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
Income (Loss) Before Income Taxes		(211)		(215)
Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Other Segments [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	0	0	0	0
Intersegment Revenues	0	0	0	0
Income (Loss) Before Income Taxes	(10)	(231)	(32)	(248)
TOTAL ASSETS	$ 994		$ 994		$ 1,059
Other Segments [Member] | Corporate, Non-Segment [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
Income (Loss) Before Income Taxes		$ (231)		$ (248)

Segment Information - Narrative

Segment Information - Narrative (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2017USD ($)Segment	Sep. 30, 2016USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | Segment			2
Marketing, Gathering And Compression [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Intersegment Revenues | $	$ 1,030	$ 1,025	$ 3,200	$ 2,656

Subsequent Events Subsequent Ev

Subsequent Events Subsequent Events - Narrative (Details) - USD ($) $ in Millions	Oct. 16, 2017	Oct. 13, 2017	Oct. 12, 2017	Sep. 30, 2017	Sep. 30, 2016	Oct. 30, 2017	Jun. 30, 2017	Dec. 31, 2016
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 9,775				$ 9,989
Proceeds from issuance of senior notes, net				742	$ 0
Cash Paid to Purchase Debt				1,751	$ 1,979
Revolving Credit Facility [Member]
Subsequent Event [Line Items]
Line of Credit Facility, Current Borrowing Capacity								3,800
Senior Notes [Member] | 8.00% Senior Notes Due 2025 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 1,000				$ 1,000
Debt Instrument, Interest Rate, Stated Percentage				8.00%				8.00%
Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 750			$ 750	$ 0
Debt Instrument, Interest Rate, Stated Percentage				8.00%			8.00%
Debt Instrument, Redemption Price, Percentage				108.00%
Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 1,737				2,419
Debt Instrument, Interest Rate, Stated Percentage				8.00%
Senior Notes [Member] | 6.625% Senior Notes Due 2020 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 572				780
Debt Instrument, Interest Rate, Stated Percentage				6.625%
Senior Notes [Member] | 6.875% Senior Notes Due 2020 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 279				279
Debt Instrument, Interest Rate, Stated Percentage				6.875%
Senior Notes [Member] | 6.125% Senior Notes Due 2021 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 550				550
Debt Instrument, Interest Rate, Stated Percentage				6.125%
Senior Notes [Member] | 5.375% Senior Notes Due 2021 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 270				270
Debt Instrument, Interest Rate, Stated Percentage				5.375%
Term Loan [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount				$ 1,500				$ 1,500
Subsequent Event [Member]
Subsequent Event [Line Items]
Proceeds from issuance of senior notes, net			$ 842
Subsequent Event [Member] | Revolving Credit Facility [Member]
Subsequent Event [Line Items]
Line of Credit Facility, Current Borrowing Capacity						$ 3,800
Subsequent Event [Member] | Senior Notes [Member]
Subsequent Event [Line Items]
Cash Paid to Purchase Debt		$ 550
Subsequent Event [Member] | Senior Notes [Member] | 8.00% Senior Notes Due 2025 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount			$ 300
Debt Instrument, Interest Rate, Stated Percentage			8.00%
Debt Instrument, Redemption Price, Percentage			101.25%
Subsequent Event [Member] | Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Subsequent Event [Line Items]
Debt Instrument, Face Amount			$ 550
Debt Instrument, Interest Rate, Stated Percentage			8.00%
Debt Instrument, Redemption Price, Percentage			99.75%
Subsequent Event [Member] | Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Cash Paid to Purchase Debt		$ 350
Debt Instrument, Repurchase Amount		$ 320
Subsequent Event [Member] | Senior Notes [Member] | 6.625% Senior Notes Due 2020 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.625%
Cash Paid to Purchase Debt		$ 141
Debt Instrument, Repurchase Amount		$ 136
Subsequent Event [Member] | Senior Notes [Member] | 6.875% Senior Notes Due 2020 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.875%
Cash Paid to Purchase Debt		$ 53
Debt Instrument, Repurchase Amount		$ 51
Subsequent Event [Member] | Senior Notes [Member] | 6.125% Senior Notes Due 2021 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.125%
Cash Paid to Purchase Debt		$ 3
Debt Instrument, Repurchase Amount		$ 3
Subsequent Event [Member] | Senior Notes [Member] | 5.375% Senior Notes Due 2021 [Member]
Subsequent Event [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.375%
Cash Paid to Purchase Debt		$ 3
Debt Instrument, Repurchase Amount		$ 3
Subsequent Event [Member] | Term Loan [Member]
Subsequent Event [Line Items]
Cash Paid to Purchase Debt	$ 258
Debt Instrument, Repurchase Amount	$ 237