Expand Energy (EXE) 10-Q 4 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 27, 2016
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
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		776,956,037

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
CURRENT ASSETS:
Cash and cash equivalents ($1 and $1 attributable to our VIE)	$ 4	$ 825
Accounts receivable, net	952	1,129
Short-term derivative assets	30	366
Other current assets	218	160
Total Current Assets	1,204	2,480
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)	64,547	63,843
Unproved properties	6,172	6,798
Other property and equipment	2,631	2,927
Total Property and Equipment, at Cost	73,350	73,568
Less: accumulated depreciation, depletion and amortization (($456) and ($428) attributable to our VIE)	(61,757)	(59,365)
Property and equipment held for sale, net	92	95
Total Property and Equipment, Net	11,685	14,298
LONG-TERM ASSETS:
Long-term derivative assets	250	246
Other long-term assets	348	290
TOTAL ASSETS	13,487	17,314
CURRENT LIABILITIES:
Accounts payable	702	944
Current maturities of long-term debt, net	1,028	381
Accrued interest	100	101
Short-term derivative liabilities	315	40
Other current liabilities ($0 and $8 attributable to our VIE)	1,632	2,219
Total Current Liabilities	3,777	3,685
LONG-TERM LIABILITIES:
Long-term debt, net	8,621	10,311
Long-term derivative liabilities	41	60
Asset retirement obligations, net of current portion	400	452
Other long-term liabilities	419	409
Total Long-Term Liabilities	9,481	11,232
Chesapeake Stockholders’ Equity:
Preferred stock, $0.01 par value, 20,000,000 shares authorized: 7,225,713 and 7,251,515 shares outstanding	3,036	3,062
Common stock, $0.01 par value, 1,500,000,000 and 1,000,000,000 shares authorized: 776,697,583 and 664,795,509 shares issued	8	7
Additional paid-in capital	12,930	12,403
Accumulated deficit	(15,873)	(13,202)
Accumulated other comprehensive loss	(104)	(99)
Less: treasury stock, at cost; 1,303,020 and 1,437,724 common shares	(29)	(33)
Total Chesapeake Stockholders’ Equity (Deficit)	(32)	2,138
Noncontrolling interests	261	259
Total Equity	229	2,397
TOTAL LIABILITIES AND EQUITY	$ 13,487	$ 17,314

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
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)	7,225,713	7,251,515
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common Stock, Shares Authorized	1,500,000,000	1,000,000,000
Common Stock, Shares, Issued	776,697,583	664,795,509
Treasury stock, shares	1,303,020	1,437,724
Cash and cash equivalents ($1 and $1 attributable to our VIE)	$ 4	$ 825
VIE. proved natural gas and oil properties	64,547	63,843
VIE. accumulated depreciation, depletion and amortization	(61,757)	(59,365)
VIE. other current liabilities	1,632	2,219
Variable Interest Entities, Primary Beneficiary [Member]
Cash and cash equivalents ($1 and $1 attributable to our VIE)	1	1
VIE. proved natural gas and oil properties	488	488
VIE. accumulated depreciation, depletion and amortization	(456)	(428)
VIE. other current liabilities	$ 0	$ 8

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
REVENUES:
Oil, natural gas and NGL	$ 440	$ 1,216	$ 1,433	$ 2,759
Marketing, gathering and compression	1,182	2,305	2,142	3,980
Total Revenues	1,622	3,521	3,575	6,739
OPERATING EXPENSES:
Oil, natural gas and NGL production	182	276	388	575
Oil, natural gas and NGL gathering, processing and transportation	481	488	963	946
Production taxes	19	34	37	62
Marketing, gathering and compression	1,207	2,096	2,149	3,796
General and administrative	61	69	109	125
Restructuring and other termination costs	3	(4)	3	(14)
Provision for legal contingencies	82	334	104	359
Oil, natural gas and NGL depreciation, depletion and amortization	265	601	536	1,285
Depreciation and amortization of other assets	29	34	58	69
Impairment of oil and natural gas properties	1,045	5,015	1,898	9,991
Impairments of fixed assets and other	6	84	44	88
Net (gains) losses on sales of fixed assets	(1)	1	(5)	4
Total Operating Expenses	3,379	9,028	6,284	17,286
LOSS FROM OPERATIONS	(1,757)	(5,507)	(2,709)	(10,547)
OTHER INCOME (EXPENSE):
Interest expense	(62)	(71)	(124)	(122)
Losses on investments	(2)	(17)	(2)	(24)
Loss on sale of investment	0	0	(10)	0
Gains on purchases or exchanges of debt	68	0	168	0
Other income (expense)	3	(1)	6	5
Total Other Income (Expense)	7	(89)	38	(141)
LOSS BEFORE INCOME TAXES	(1,750)	(5,596)	(2,671)	(10,688)
INCOME TAX BENEFIT:
Current income taxes	0	(6)		(6)
Deferred income taxes	0	(1,500)	0	(2,872)
Total Income Tax Benefit	0	(1,506)	0	(2,878)
NET LOSS	(1,750)	(4,090)	(2,671)	(7,810)
Net income attributable to noncontrolling interests	0	(18)	0	(37)
NET LOSS ATTRIBUTABLE TO CHESAPEAKE	(1,750)	(4,108)	(2,671)	(7,847)
Preferred stock dividends	(42)	(43)	(85)	(86)
NET LOSS AVAILABLE TO COMMON STOCKHOLDERS	$ (1,792)	$ (4,151)	$ (2,756)	$ (7,933)
LOSS PER COMMON SHARE:
Earnings Per Share, Basic	$ (2.48)	$ (6.27)	$ (3.97)	$ (11.99)
Earnings Per Share, Diluted	(2.48)	(6.27)	(3.97)	(11.99)
CASH DIVIDEND DECLARED PER COMMON SHARE	$ 0	$ 0	$ 0	$ 0.0875
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Weighted Average Number of Shares Outstanding, Basic	724	662	695	662
Weighted Average Number of Shares Outstanding, Diluted	724	662	695	662

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
NET LOSS	$ (1,750)	$ (4,090)	$ (2,671)	$ (7,810)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF INCOME TAX:
Unrealized gains (losses) on derivative instruments, net of income tax expense (benefit) of $2, $0, ($1) and ($1)	(15)	0	(19)	(1)
Reclassification of (gains) losses on settled derivative instruments, net of income tax expense (benefit) of ($4), $2, $3 and $9	10	3	14	13
Other Comprehensive Income (Loss)	(5)	3	(5)	12
COMPREHENSIVE LOSS	(1,755)	(4,087)	(2,676)	(7,798)
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS	0	(18)	0	(37)
COMPREHENSIVE LOSS ATTRIBUTABLE TO CHESAPEAKE	$ (1,755)	$ (4,105)	$ (2,676)	$ (7,835)

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Unrealized gains (losses) on derivative instruments, net of income tax expense (benefit) of $2, $0, ($1) and ($1)	$ 2	$ 0	$ (1)	$ (1)
Reclassification of (gains) losses on settled derivative instruments, net of income tax expense (benefit) of ($4), $2, $3 and $9	$ (4)	$ 2	$ 3	$ 9

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
CASH FLOWS FROM OPERATING ACTIVITIES:
NET LOSS	$ (2,671)	$ (7,810)
ADJUSTMENTS TO RECONCILE NET LOSS TO CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES:
Depreciation, depletion and amortization	594	1,354
Deferred income tax expense (benefit)	0	(2,872)
Derivative (gains) losses, net	278	(344)
Cash receipts on derivative settlements, net	386	631
Stock-based compensation	25	43
Impairment of oil and natural gas properties	1,898	9,991
Net (gains) losses on sales of fixed assets	(5)	4
Impairments of fixed assets and other	34	81
Losses on investments	2	24
Loss on sale of investment	10	0
Gains on purchases or exchanges of debt	(168)	0
Restructuring and other termination costs	3	(14)
Provision for legal contingencies	104	359
Other	(51)	9
Changes in assets and liabilities	(765)	(719)
Net Cash Provided By (Used In) Operating Activities	(326)	737
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(609)	(2,168)
Acquisitions of proved and unproved properties	(426)	(266)
Proceeds from divestitures of proved and unproved properties	964	14
Additions to other property and equipment	25	93
Proceeds from sales of other property and equipment	70	7
Cash paid for title defects	(69)	0
Additions to investments	0	(1)
Other	(4)	(5)
Net Cash Used In Investing Activities	(99)	(2,512)
CASH FLOWS FROM FINANCING ACTIVITIES:
Cash paid to purchase debt	(472)	0
Proceeds from credit facilities borrowings	2,477	0
Payments on credit facilities borrowings	(2,377)	0
Cash paid for common stock dividends	0	(118)
Cash paid for preferred stock dividends	0	(86)
Distributions to noncontrolling interest owners	(6)	(57)
Other	(18)	(21)
Net Cash Used In Financing Activities	(396)	(282)
Net decrease in cash and cash equivalents	(821)	(2,057)
Cash and cash equivalents, beginning of period	825	4,108
Cash and cash equivalents, end of period	4	2,051
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid, net of capitalized interest	154	65
Income taxes paid, net of refunds received	(20)	60
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	(13)	(46)
Debt exchanged for common stock	$ 471	$ 0

CONDENSED CONSOLIDATED STATEME8

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Convertible 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]Convertible Preferred 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, 2014		$ 3,062	$ 7	$ 12,531				$ 1,483	$ (143)	$ (37)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Conversions/exchanges during period, value		0	0		$ 0	$ 0	$ 0
Stock-based compensation				40
Dividends on common stock				(59)
Dividends on preferred stock				(86)
Decrease in tax benefit from stock-based compensation				(6)
Net loss attributable to Chesapeake	$ (7,847)
Hedging activity									12
Purchase of 22,810 and 28,298 shares for company benefit plans										0
Treasury Stock, Retired, Cost Method, Amount										1
Chesapeake stockholders’ equity, end of period at Jun. 30, 2015		3,062	7	12,420				(6,364)	(131)	(36)	$ 8,958
Stockholders' Equity Attributable to Noncontrolling Interest, Beginning of Period at Dec. 31, 2014												$ 1,302
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	37
Distributions to noncontrolling interest owners												(54)
Stockholders' Equity Attributable to Noncontrolling Interest, End of Period at Jun. 30, 2015												1,285
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY	10,243
TOTAL EQUITY	2,397
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2015	2,138	3,062	7	12,403				(13,202)	(99)	(33)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Conversions/exchanges during period, value		26	1		$ 241	$ 229	$ 26
Stock-based compensation				31
Dividends on common stock				0
Dividends on preferred stock				0
Decrease in tax benefit from stock-based compensation				0
Net loss attributable to Chesapeake	(2,671)
Hedging activity									(5)
Purchase of 22,810 and 28,298 shares for company benefit plans										0
Treasury Stock, Retired, Cost Method, Amount										4
Chesapeake stockholders’ equity, end of period at Jun. 30, 2016	(32)	$ 3,036	$ 8	$ 12,930				$ (15,873)	$ (104)	$ (29)	$ (32)
Stockholders' Equity Attributable to Noncontrolling Interest, Beginning of Period at Dec. 31, 2015	259											259
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	0
Distributions to noncontrolling interest owners												2
Stockholders' Equity Attributable to Noncontrolling Interest, End of Period at Jun. 30, 2016	261											$ 261
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY	$ 229

CONDENSED CONSOLIDATED STATEME9

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - shares	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Treasury Stock - Common [Member]
Purchase of shares for company benefit plans, shares	22,810	28,298
Release of shares from company benefit plans, shares	157,514	56,305
Preferred Stock, Exchanged for Shares of Common Stock [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	1,021,000	0
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Preferred Stock [Member]
Conversion of Stock, Shares Converted	25,802	0
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	1,021,506	0
Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	55,428,000	0
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	55,427,782	0
Senior Notes Exchanged for Shares of Common Stock [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	53,924,000	0
Senior Notes Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	53,923,925	0

Basis of Presentation (Note)

Basis of Presentation (Note)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies Disclosure	Basis of Presentation Basis of Presentation The accompanying unaudited condensed consolidated financial statements of Chesapeake Energy Corporation ("Chesapeake" or the "Company") and its subsidiaries 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 six months ended June 30, 2016 (the "Current Quarter" and the “Current Period”, respectively) and the three and six months ended June 30, 2015 (the "Prior Quarter" and the “Prior Period”, respectively). Chesapeake's annual report on Form 10-K for the year ended December 31, 2015 ("2015 Form 10-K") includes certain definitions and a summary of significant accounting policies that 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. Risks and Uncertainties Our ability to grow, make capital expenditures and service our debt depends primarily upon the prices we receive for the oil, natural gas and natural gas liquids (NGL) we sell. Substantial expenditures are required to replace reserves, sustain production and fund our business plans. Historically, oil and natural gas prices have been very volatile, and may be subject to wide fluctuations in the future. The substantial decline in oil, natural gas and NGL prices from 2014 levels has negatively affected the amount of cash we have available for capital expenditures and debt service. We face other significant risks to our business, including: • In the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, capitalized costs of oil and natural gas properties exceeded our full cost ceiling, resulting in an impairment in the carrying value of our oil and natural gas properties of $1.045 billion , $5.015 billion , $1.898 billion and $9.991 billion , respectively. Based on the first-day-of-the-month prices we have received over the 11 months ended August 1, 2016 , as well as the current strip price for September 2016 , we expect to record downward reserve revisions and another write-down in the carrying value of our oil and natural gas properties in the third quarter of 2016 , although the amount of impairment could be mitigated by the impact of anticipated divestitures in the third quarter of 2016 or other factors. • Oil, natural gas and NGL prices have a material impact on our financial position, results of operations, cash flows and quantities of reserves that may be economically produced. If depressed prices persist throughout 2017 and we are unable to restructure or refinance our debt or generate additional liquidity through other actions, our ability to comply with the financial covenants under our revolving credit facility and to make scheduled debt payments could be adversely impacted. • As of June 30, 2016 , we had approximately $8.679 billion principal amount of debt outstanding, of which $1.382 billion matures or can be put to us in 2017 (including $337 million of maturities in January 2017, $730 million which can be put to us in May 2017 and $315 million that matures in August 2017) and $846 million that matures or can be put to us in 2018. See Note 3 for further discussion of our debt obligations, including principal and carrying amounts of our notes. As of June 30, 2016 , we had $100 million of outstanding borrowings under our revolving credit facility and $3.087 billion of borrowing capacity available under our revolving credit facility. • Since December 2015, Moody’s Investor Services, Inc. and Standard & Poor’s Rating Services have significantly lowered our credit ratings. Some of our counterparties have requested or required us to post collateral as financial assurance of our performance under certain contractual arrangements, such as gathering, processing, transportation and hedging agreements. As of August 1, 2016 , we have received requests and posted approximately $274 million in collateral under such arrangements (excluding the supersedeas bond with respect to the 6.775% Senior Notes due 2019 (the 2019 Notes) litigation discussed in Note 4). We may be requested or required by other counterparties to post additional collateral in an aggregate amount of approximately $664 million , which may be in the form of additional letters of credit, cash or other acceptable collateral. Any posting of additional collateral consisting of cash or letters of credit, which would reduce availability under our revolving credit facility, will negatively impact our liquidity. • We may seek to access the capital markets or otherwise incur debt to refinance a portion of our outstanding indebtedness and improve our li q uidity. We have taken measures to mitigate the risks and uncertainties facing us for the next 12 months, including mitigating a portion of our downside exposure to lower commodity prices through derivative contracts, the suspension of dividend payments on our convertible preferred stock, the April 2016 amendment to our revolving credit facility (discussed in Note 3) and divesting assets to increase our liquidity; however, there can be no assurance that these measures will satisfy our needs. Reclassifications In April 2015, the Financial Accounting Standards Board (FASB) issued guidance that requires debt issuance costs related to term debt to be presented in the balance sheet as a direct deduction from the associated debt liability. This standard requires retrospective application and is effective for annual reporting periods beginning after December 15, 2015. This change in accounting principle is preferable since it allows debt issuance costs and debt issuance discounts to be presented similarly in the consolidated balance sheets as a reduction to the face amount of our debt balances. A retrospective change to our consolidated balance sheet as of December 31, 2015, as previously presented, is required pursuant to the guidance. The retrospective adjustment to the December 31, 2015 consolidated balance sheet is shown below. As Previously Reported December 31, 2015 Adjustment Effect As Adjusted $ in millions Other long-term assets $ 333 $ (43 ) $ 290 Long-term debt, net $ 10,354 $ (43 ) $ 10,311 Beginning in the fourth quarter of 2015, we began presenting third party transportation and gathering costs as a component of operating expenses in our statement of operations. Previously, these costs were reflected as deductions to oil, natural gas and NGL sales. These costs have been reclassified in our condensed consolidated statement of operations for the Prior Quarter and the Prior Period to conform to the presentation used for the Current Quarter and the Current Period. The net effect of this reclassification did not impact our previously reported net loss, stockholders’ equity or cash flows; however, previously reported oil, natural gas and NGL sales have increased from the amounts previously reported, and total operating expenses have increased by those same amounts.

Earnings Per Share (Note)

Earnings Per Share (Note)	6 Months Ended
	Jun. 30, 2016
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 the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, 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 contingent convertible senior notes. For the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, shares of the following securities and associated adjustments to net income, representing dividends on preferred stock and allocated earnings on participating securities, were excluded from the calculation of diluted EPS as the effect was antidilutive. Net Income Adjustments Shares ($ in millions) (in millions) Three Months Ended June 30, 2016 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 21 58 5.75% cumulative convertible preferred stock (series A) $ 16 42 5.00% cumulative convertible preferred stock (series 2005B) $ 2 6 4.50% cumulative convertible preferred stock $ 3 6 Participating securities $ — 1 Three Months Ended June 30, 2015 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 21 59 5.75% cumulative convertible preferred stock (series A) $ 16 42 5.00% cumulative convertible preferred stock (series 2005B) $ 3 6 4.50% cumulative convertible preferred stock $ 3 6 Participating securities $ — 1 Six Months Ended June 30, 2016 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 42 58 5.75% cumulative convertible preferred stock (series A) $ 32 42 5.00% cumulative convertible preferred stock (series 2005B) $ 5 6 4.50% cumulative convertible preferred stock $ 6 6 Participating securities $ — 1 Six Months Ended June 30, 2015 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 43 59 5.75% cumulative convertible preferred stock (series A) $ 32 42 5.00% cumulative convertible preferred stock (series 2005B) $ 5 6 4.50% cumulative convertible preferred stock $ 6 6 Participating securities $ — 2

Debt (Note)

Debt (Note)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Debt Disclosure	Debt Our long-term debt consisted of the following as of June 30, 2016 and December 31, 2015: June 30, 2016 December 31, 2015 Principal Amount Carrying Principal Carrying ($ in millions) 3.25% senior notes due 2016 $ — $ — $ 381 $ 381 6.25% euro-denominated senior notes due 2017 (a) 337 337 329 329 6.5% senior notes due 2017 315 315 453 453 7.25% senior notes due 2018 531 531 538 538 Floating rate senior notes due 2019 949 949 1,104 1,104 6.625% senior notes due 2020 822 822 822 822 6.875% senior notes due 2020 302 302 304 304 6.125% senior notes due 2021 584 584 589 589 5.375% senior notes due 2021 276 276 286 286 4.875% senior notes due 2022 607 607 639 639 8.00% senior secured second lien notes due 2022 2,425 3,501 2,425 3,584 5.75% senior notes due 2023 384 384 384 384 2.75% contingent convertible senior notes due 2035 (b) 2 2 2 2 2.5% contingent convertible senior notes due 2037 (b)(c) 730 694 1,110 1,027 2.25% contingent convertible senior notes due 2038 (b)(c) 315 276 340 290 Revolving credit facility 100 100 — — Debt issuance costs — (35 ) — (43 ) Discount on senior notes — (2 ) — (4 ) Interest rate derivatives (d) — 6 — 7 Total debt, net 8,679 9,649 9,706 10,692 Less current maturities of long-term debt, net (e) (1,066 ) (1,028 ) (381 ) (381 ) Total long-term debt, net $ 7,613 $ 8,621 $ 9,325 $ 10,311 ___________________________________________ (a) The principal and carrying amounts shown are based on the exchange rate of $1.1106 to €1.00 and $1.0862 to €1.00 as of June 30, 2016 and December 31, 2015, respectively. See Foreign Currency Derivatives in Note 8 for information on our related foreign currency derivatives. (b) The repurchase, conversion, contingent interest and redemption provisions of our contingent convertible senior notes are as follows: Holders’ Demand Repurchase Rights . The holders of our contingent 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 on any of four dates that are five , ten , fifteen and twenty years before the maturity date. Optional Conversion by Holders . At the holder’s option, prior to maturity under certain circumstances, the notes are convertible into cash and, if applicable, shares of our common stock using a net share settlement process. 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 specified period in the Current Quarter, the price of our common stock was below the threshold level for each series of the contingent convertible senior notes and, as a result, the holders do not have the option to convert their notes into cash and common stock in the third quarter of 2016 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 and the Prior Quarter. In general, upon conversion of a contingent convertible senior note, the holder will receive cash equal to the principal amount of the note and common stock for the note’s conversion value in excess of the principal amount. Contingent Interest. We will pay contingent interest on the convertible senior notes after they have been outstanding at least ten years during certain periods if the average trading price of the notes exceeds the threshold defined in the indenture. The holders’ demand repurchase dates, the common stock price conversion threshold amounts (as adjusted to give effect to cash dividends on our common stock) and the ending date of the first six-month period in which contingent interest may be payable for the contingent convertible senior notes are as follows: Contingent Convertible Senior Notes Holders' Demand Repurchase Dates Common Stock Price Conversion Thresholds Contingent Interest First Payable (if applicable) 2.75% due 2035 November 15, 2020, 2025, 2030 $ 45.02 May 14, 2016 2.5% due 2037 May 15, 2017, 2022, 2027, 2032 $ 59.44 November 14, 2017 2.25% due 2038 December 15, 2018, 2023, 2028, 2033 $ 100.20 June 14, 2019 Optional Redemption by the Company. We may redeem the contingent convertible senior notes once they have been outstanding for ten years at a redemption price of 100% of the principal amount of the notes, payable in cash. In addition, we may redeem our 2.75% Contingent Convertible Senior Notes due 2035 at any time. (c) The carrying amount associated with the equity component of our contingent convertible senior notes as of June 30, 2016 and December 31, 2015 is net of $75 million and $133 million , respectively. This amount is amortized based on an effective yield method. (d) See Interest Rate Derivatives in Note 8 for further discussion related to these instruments. (e) As of June 30, 2016 , current maturities of long-term debt net includes our 6.25% Euro-denominated Senior Notes due 2017 and our 2.5% Contingent Convertible Senior Notes due 2037 (the 2037 Notes). As discussed in footnote (b) above, the holders of our 2037 Notes could exercise their individual demand repurchase rights on May 15, 2017 , which would require us to repurchase all or a portion of the principal amount of the notes. As of June 30, 2016 , there was $36 million associated with the equity component of the 2037 Notes. Chesapeake Senior Notes and Contingent Convertible Senior Notes In the Current Period, in addition to the repayment upon maturity of $259 million principal amount of our 3.25% Senior Notes due 2016, we repurchased in the open market approximately $181 million principal amount of our outstanding senior notes for $151 million and $118 million principal amount of our outstanding contingent convertible senior notes for $63 million . Additionally, we privately negotiated exchanges of approximately $290 million principal amount of our outstanding senior notes for 53,923,925 shares of common stock and $287 million principal amount of our outstanding contingent convertible senior notes for 55,427,782 shares of common stock. In the Current Period, we recorded an aggregate gain of approximately $168 million associated with the repurchases and exchanges (including $68 million in the Current Quarter). Chesapeake Energy Corporation is a holding company and has no independent assets or operations. Our obligations under our outstanding senior notes and contingent 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. Revolving Credit Facility We have a $4.0 billion senior secured revolving credit facility that matures in December 2019. As of June 30, 2016 , we had outstanding borrowings of $100 million under the credit facility and had used $813 million of the credit facility for various letters of credit (including the $461 million supersedeas bond with respect to the 2019 Notes litigation discussed in Note 4). The terms of the 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. We were in compliance with all financial covenants under the agreement as of June 30, 2016 . In April 2016, we entered into the third amendment to our senior revolving credit facility. Pursuant to the amendment, our borrowing base was reaffirmed in the amount of $4.0 billion and the next scheduled borrowing base redetermination review was postponed until June 15, 2017, with the consenting lenders agreeing not to exercise their interim redetermination right prior to that date. The amendment also provides temporary financial covenant relief, with the credit facility’s existing first lien secured leverage ratio and net debt to capitalization ratio suspended until September 30, 2017 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 amendment reduces the interest coverage ratio from 1.1 to 1.0 to 0.65 to 1.0 through the first quarter of 2017, after which it will increase to 0.70 to 1.0 through the second quarter of 2017, 1.2 to 1.0 through the third quarter of 2017 and 1.25 to 1.0 thereafter. The amendment also includes a collateral value coverage test whereby if the collateral value coverage ratio, tested as of December 31, 2016, falls below 1.1 to 1.0, the $500 million minimum liquidity covenant increases to $750 million, and if the collateral value coverage ratio, tested as of March 31, 2017, falls below 1.25 to 1.0, our borrowing ability will be reduced in order to satisfy such ratio. The amendment also gives us the ability to incur up to $2.5 billion of first lien indebtedness secured on a pari passu basis with the existing obligations under the credit agreement, subject to payment priority in favor of the existing lenders and the other limitations on junior lien debt set forth in the credit agreement. Fair Value of Debt We estimate the fair value of our exchange-traded debt using quoted market prices (Level 1). The fair value of all other debt, including borrowings under our revolving credit facility, is estimated using our credit default swap rate (Level 2). Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below. June 30, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 1,028 $ 984 $ 381 $ 366 Long-term debt (Level 1) $ 8,515 $ 5,793 $ 10,304 $ 3,735 Long-term debt (Level 2) $ 100 $ 83 $ — $ —

Contingencies and Commitments (

Contingencies and Commitments (Note)	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Legal Matters and 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 estimated 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. 2016 Shareholder Litigation . On April 19, 2016, a derivative action was filed in the U.S. District Court for the Western District of Oklahoma against the Company and current and former directors and officers of the Company alleging, among other things, violation of and conspiracy to violate the federal Racketeer Influenced and Corrupt Organizations Act, breach of fiduciary duties, waste of corporate assets, gross mismanagement and violations of Sections 10(b) and Rule 10b-5 of the Exchange Act related to actions allegedly taken by such persons since 2008. The lawsuit seeks certification as a class action, damages, attorneys’ fees and other costs. Regulatory Proceedings. The Company has received, from the U.S. Department of Justice (DOJ) and certain state governmental agencies and authorities, subpoenas and demands for documents, information and testimony in connection with investigations into possible violations of federal and state antitrust laws relating to our purchase and lease of oil and natural gas rights in various states. The Company also has received DOJ, U.S. Postal Service and state subpoenas seeking information on the Company’s royalty payment practices. Chesapeake has engaged in discussions with the DOJ, U.S. Postal Service and state agency representatives and continues to respond to such subpoenas and demands. Redemption of 2019 Notes . As previously disclosed in the 2015 Form 10-K, in connection with the litigation related to the Company’s notice issued on March 15, 2013 to redeem all of the 2019 Notes at par (plus accrued interest through the redemption date) pursuant to the special early redemption provision of the supplemental indenture governing the 2019 Notes, the Company filed a notice of appeal on July 27, 2015 of an amended judgment entered on July 17, 2015 by the U.S. District Court for the Southern District of New York awarding the Trustee for the 2019 Notes $380 million plus prejudgment interest in the amount of $59 million . The Company posted a supersedeas bond in the amount of $461 million (reflected as an outstanding letter of credit under the Company’s credit facility) to stay execution of the judgment while appellate proceedings are pending. We accrued a loss contingency of $100 million for this matter in 2014, and we accrued an additional $339 million in 2015. 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. With regard to contract actions, various mineral or leasehold owners have filed lawsuits against us seeking specific performance to require us to acquire their oil and natural gas interests and pay acreage bonus payments, damages based on breach of contract and/or, in certain cases, punitive damages based on alleged fraud. The Company has successfully defended a number of these failure-to-close cases in various courts, has settled and resolved other such cases and disputes and believes that its remaining loss exposure for these claims will not have a material adverse effect on the Company’s consolidated financial position, results of operations or cash flows. 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 royalty underpayment in various states, including, but not limited to, Texas, Pennsylvania, Ohio, Louisiana, Oklahoma and Arkansas. These lawsuits include cases filed by individual royalty owners and putative class actions, some of which seek to certify a statewide class. The Company also has received DOJ, U.S. Postal Service and state subpoenas seeking information on the Company’s royalty payment practices. Chesapeake is defending numerous lawsuits filed by individual royalty owners alleging royalty underpayment with respect to properties in Texas. On April 8, 2015, Chesapeake obtained a transfer order from the Texas Multidistrict Litigation Panel to transfer a substantial portion of these lawsuits filed since June 2014 to the 348th District Court of Tarrant County for pre-trial purposes (the “MDL”). These lawsuits, which primarily relate to the Barnett Shale, generally allege that Chesapeake underpaid royalties by making improper deductions and using incorrect production volumes. In addition to allegations of breach of contract, a number of these lawsuits allege fraud, conspiracy, joint venture and antitrust violations by Chesapeake. The lawsuits seek direct damages in varying amounts, together with exemplary damages, attorneys’ fees, costs and interest. Chesapeake entered into a settlement agreement with MDL plaintiffs representing over 97% of the hydrocarbons at issue by volume and, on July 22, 2016, the plaintiffs who accepted the settlement filed to dismiss such lawsuits. Chesapeake funded the settlement amount of approximately $29 million in cash and signed a $10 million , three -year promissory note in July 2016, which is accrued for as of June 30, 2016 . Additional plaintiffs are continuing to accept the settlement on a rolling basis. Chesapeake expects that additional lawsuits filed by plaintiffs not participating in the settlement 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 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 permanent injunction from further violations of the UTPCPL. On February 8, 2016, the Office of Attorney General amended the complaint to, among other things, add an additional UTPCPL claim and antitrust claim alleging that a joint exploration agreement to which Chesapeake is a party established unlawful market allocation for the acquisition of leases. In response to Chesapeake’s preliminary objections, the Office of Attorney General filed a second amended complaint on May 3, 2016, alleging further violations of the UTPCPL based upon alleged predicate violations of the federal Sherman Act and the Federal Trade Commission Act. Chesapeake removed the case to the United States District Court for the Middle District of Pennsylvania on May 27, 2016. 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 have not accrued a loss contingency for any of the Pennsylvania and Ohio matters seeking class certification. 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 have been filed in the United States District Court for the Western District of Oklahoma and in Oklahoma state courts, and an individual lawsuit was filed in the United States 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 which would restrain competition in a similar manner as alleged in the lawsuits. In April 2016, a class action lawsuit on behalf of holders of the Company’s 6.875% Senior Notes due 2020 (the 2020 Notes) and 6.125% Senior Notes due 2021 (the 2021 Notes) was filed in the U.S. District Court for the Southern District of New York relating to the Company’s December 2015 debt exchange, whereby the Company privately exchanged newly issued 8.00% Senior Secured Second Lien Notes due 2022 (Second Lien Notes) for certain outstanding senior unsecured notes and contingent convertible notes. The lawsuit alleges that the Company violated the Trust Indenture Act of 1939 and the implied covenant of good faith and fair dealing by benefiting themselves and a minority of noteholders who are qualified institutional buyers (QIBs). According to the lawsuit, as a result of the Company’s private debt exchange in which only QIBs (and non-U.S. persons under Regulation S) were eligible to participate, the Company unjustly enriched itself at the expense of class members by reducing indebtedness and reducing the value of the 2020 Notes and the 2022 Notes. The lawsuit seeks damages and attorney’s fees, in addition to declaratory relief that the debt exchange and the liens created for the benefit of the Second Lien Notes are null and void and that the debt exchange effectively resulted in a default under the indentures for the 2020 Notes and the 2021 Notes. In June 2016, the lawsuit was transferred to the United States District Court for the Western District of Oklahoma. 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 auditing 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 Contingencies and Guarantees	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 in the accompanying condensed consolidated balance sheets; however, they are reflected in our estimates of proved reserves. The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below. June 30, ($ in millions) 2016 $ 925 2017 1,874 2018 1,670 2019 1,374 2020 1,046 2021 – 2099 6,572 Total $ 13,461 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 vary with the applicable agreement. One of these agreements (in the Anadarko Basin in northwestern Oklahoma) contains cost-of-service based fees that are redetermined annually through 2019. The annual upward or downward fee adjustment for this contract is capped at 15% of the then-current fees at the time of redetermination. To the extent the actual rate of return on capital expended by the counterparty over the term of the agreement differs from the applicable rate of return, a payment is due to (from) the midstream service company. Drilling Contracts We have contracts with various drilling contractors to utilize drilling services with terms ranging from three months to three years at market-based pricing. These commitments are not recorded in the accompanying condensed consolidated balance sheets. As of June 30, 2016 , the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $177 million . Pressure Pumping Contracts We have an agreement for pressure pumping services. Throughout the term of the agreement, which expires in June 2017, the services agreement requires us to utilize, at market-based pricing, the lesser of (i) three pressure pumping crews through June 30, 2017 or (ii) 50% of the total number of all pressure pumping crews working for us in all of our operating regions during the respective year. We are also required to utilize the pressure pumping services for a minimum number of fracture stages as set forth in the agreement. We are entitled to terminate the agreement in certain situations, including if the contractor fails to provide the overall quality of service provided by similar service providers. As of June 30, 2016 , the aggregate undiscounted minimum future payments under this agreement were approximately $155 million . Drilling Commitments We previously committed to drill wells for the benefit of Chesapeake Granite Wash Trust (the Trust). In connection with the Trust’s initial public offering, we conveyed royalty interests to the Trust that entitle the Trust to receive certain proceeds from the production of 69 then-producing wells, and 118 development wells that have been drilled in the Colony Granite Wash play in Washita County in the Anadarko Basin of western Oklahoma. Pursuant to the terms of a development agreement with the Trust, we were obligated to drill and complete, or cause to be drilled and completed, the development wells at our own expense prior to June 30, 2016. As of June 30, 2016, we had fulfilled our drilling and completion commitment. See Note 10 for further discussion of the Trust. 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 volumetric production payment (VPP) transactions. 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 required to extend, renew or replace expiring joint leasehold, at our cost, to ensure that the net acreage is maintained in certain designated areas as of a future 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 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 (Note)

Other Liabilities (Note)	6 Months Ended
	Jun. 30, 2016
Other Liabilities Disclosure [Abstract]
Other Liabilities Disclosure	Other Liabilities Other current liabilities as of June 30, 2016 and December 31, 2015 are detailed below. June 30, December 31, ($ in millions) Revenues and royalties due others $ 430 $ 500 Accrued drilling and production costs 191 212 Joint interest prepayments received 84 169 Accrued compensation and benefits 173 264 Other accrued taxes 68 37 Bank of New York Mellon legal accrual 439 439 Minimum gathering volume commitment — 201 Other 247 397 Total other current liabilities $ 1,632 $ 2,219 Other long-term liabilities as of June 30, 2016 and December 31, 2015 are detailed below. June 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 175 $ 190 Financing obligations — 29 Unrecognized tax benefits 93 64 Other 151 126 Total other long-term liabilities $ 419 $ 409 ____________________________________________ (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. Approximately $29 million and $21 million of the total $204 million and $211 million obligations are recorded in other current liabilities as of June 30, 2016 and December 31, 2015, respectively.

Equity (Note)

Equity (Note)	6 Months Ended
	Jun. 30, 2016
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 are detailed below. Six Months Ended 2016 2015 (in thousands) Shares issued as of January 1 664,796 664,944 Exchange of convertible notes 55,428 — Exchange of senior notes 53,924 — Conversion of preferred stock 1,021 — Restricted stock issuances (net of forfeitures and cancellations) 1,529 103 Stock option exercises — 14 Shares issued as of June 30 776,698 665,061 On May 20, 2016, our shareholders approved an amendment to our certificate of incorporation to increase our authorized common stock from 1,000,000,000 shares to 1,500,000,000 shares, par value $0.01 per share. Preferred Stock Outstanding shares of our preferred stock for the Current Period and the Prior Period are detailed below. 5.75% 5.75% (A) 4.50% 5.00% (2005B) (in thousands) Shares outstanding as of January 1, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions (a) (25 ) (1 ) — — Shares outstanding as of June 30, 2016 1,472 1,099 2,559 2,096 Shares outstanding as of January 1, 2015 and June 30, 2015 1,497 1,100 2,559 2,096 ____________________________________________ (a) In the Current Period, holders of our 5.75% Cumulative Convertible Preferred Stock converted 24,601 shares into 975,488 shares of common stock. Also in the Current Period, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 1,201 shares into 46,018 shares of common stock. Dividends In January 2016, we announced that we were suspending dividend payments on each series of our outstanding convertible preferred stock. Suspension of the dividends did not constitute an event of default under our revolving credit facility or bond indentures. Our preferred stock dividends for the Current Period (paid in arrears) are detailed below. 5.75% 5.75% (A) 4.50% 5.00% ($ in millions) Dividends in arrears $ 42 $ 32 $ 6 $ 5 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. Six Months Ended 2016 2015 ($ in millions) Balance, December 31 $ (99 ) $ (143 ) Other comprehensive income before reclassifications (19 ) (1 ) Amounts reclassified from accumulated other comprehensive income 14 13 Net other comprehensive income (loss) (5 ) 12 Balance, June 30 $ (104 ) $ (131 ) 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 $10 million , $3 million , $14 million and $13 million , respectively.

Share-Based Compensation (Note)

Share-Based Compensation (Note)	6 Months Ended
	Jun. 30, 2016
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 common stock 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. Prior to 2014, we also granted restricted stock awards as equity compensation. We refer to both types of awards as restricted stock. A summary of the changes in unvested restricted stock during the Current Period is presented below. Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value (in thousands) Unvested restricted stock as of January 1, 2016 10,455 $ 17.31 Granted 2,882 $ 3.77 Vested (3,713 ) $ 17.35 Forfeited (902 ) $ 13.17 Unvested restricted stock as of June 30, 2016 8,722 $ 13.25 The aggregate intrinsic value of restricted stock that vested during the Current Period was approximately $16 million based on the stock price at the time of vesting. As of June 30, 2016 , there was approximately $76 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 1.57 years. Stock Options. In the Current Period and the Prior Period, we granted members of senior management stock options that vest ratably over a three -year period. In January 2013, we also granted retention awards of stock options to certain officers that vest one-third on each of the third , fourth and fifth anniversaries of the grant date. Each stock option award has an exercise price equal to the closing price of the Company’s common stock on the grant date. Outstanding options expire seven to ten years from the date of grant. We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on an average of historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account the Company's dividend policy, over the expected life of the option. The Company used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period. Expected option life – years 6.0 Volatility 46.07 % Risk-free interest rate 1.70 % Dividend yield — % The following table provides information related to stock option activity in the Current Period. Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2016 5,377 $ 19.37 5.80 $ — Granted 4,932 $ 3.71 Exercised — $ — $ — Expired (477 ) $ 19.06 Forfeited (945 ) $ 5.66 Outstanding as of June 30, 2016 8,887 $ 12.15 7.47 $ 2 Exercisable as of June 30, 2016 3,125 $ 19.62 5.32 $ — ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option. As of June 30, 2016 , there was $10 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 2.00 years . Restricted Stock and Stock Option Compensation. We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 10 $ 12 $ 18 $ 24 Oil and natural gas properties 5 8 9 15 Oil, natural gas and NGL production expenses 3 6 6 10 Marketing, gathering and compression expenses — 2 1 3 Total $ 18 $ 28 $ 34 $ 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 in 2016, 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% . The payout percentage of these PSUs is capped at 100% if the Company's absolute TSR is less than zero. For PSUs granted in 2015, the TSR component can range from 0% to 100% , and each of the two operational components can range from 0% to 50% resulting in a maximum total payout of 200% . The payout percentage for these PSUs is capped at 100% if the Company’s absolute TSR is less than zero. For PSUs granted in 2014, the TSR component can range from 0% to 200% , with no operational components. Compensation expense associated with PSU grants is recognized over the service period based on the graded-vesting method. The number of units settled is dependent upon the Company’s estimates of the underlying performance measures. The Company utilized the Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 79.84 % Risk-free interest rate 0.65 % Dividend yield for value of awards — % The following table presents a summary of our 2016, 2015 and 2014 PSU awards. Grant Date Fair Value June 30, 2016 Units Fair Value Vested Liability ($ in millions) 2016 Awards: Payable 2019 2,348,893 $ 10 $ 11 $ 3 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1 2014 Awards: Payable 2017 561,215 $ 16 $ 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 Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 1 $ (4 ) $ 3 $ (14 ) Restructuring and other termination costs — (5 ) 1 (15 ) Marketing, gathering and compression — — — (1 ) Oil and natural gas properties — — — (1 ) Total $ 1 $ (9 ) $ 4 $ (31 )

Derivative and Hedging Activiti

Derivative and Hedging Activities (Note)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Hedging Activities Disclosure	Derivative and Hedging Activities Chesapeake uses derivative instruments to secure attractive pricing and margins on its share of expected production, to reduce its exposure to fluctuations in future commodity prices and to protect its expected operating cash flow against significant market movements or volatility. Chesapeake also uses derivative instruments to mitigate a portion of its exposure to foreign currency exchange rate fluctuations. 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. Oil, Natural Gas and NGL Derivatives As of June 30, 2016 and December 31, 2015, 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 granted options that allow the counterparty to double the notional amount. • 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. • 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. • 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 June 30, 2016 and December 31, 2015 are provided below. June 30, 2016 December 31, 2015 Volume Fair Value Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 19.8 $ (78 ) 13.5 $ 144 Call options 12.3 (6 ) 19.2 (7 ) Total oil 32.1 (84 ) 32.7 137 Natural gas (tbtu): Fixed-price swaps 577 (130 ) 500 229 Collars 38 (4 ) — — Call options 205 (56 ) 295 (99 ) Basis protection swaps 44 (8 ) 57 — Total natural gas 864 (198 ) 852 130 NGL (mmgal): Fixed-price swaps 144 (10 ) — — Total estimated fair value $ (292 ) $ 267 We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the hedged production is still expected to occur. See further discussion below under Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) . Interest Rate Derivatives As of June 30, 2016 and December 31, 2015, 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 four years , we will recognize $6 million in net gains related to these transactions. Foreign Currency Derivatives We are party to cross currency swaps to mitigate our exposure to foreign currency exchange rate fluctuations. In December 2015, we exchanged in privately negotiated transactions and subsequently retired €42 million in aggregate principal amount of 6.25% Euro-denominated Senior Notes due 2017, and we simultaneously unwound the cross currency swaps for the same principal amount at a cost of $8 million . As a result, we realized a loss of $8 million in 2015 which was included in losses on purchases or exchanges of debt. Under the terms of the remaining cross currency swaps, on each semi-annual interest payment date, the counterparties pay us €9 million and we pay the counterparties $15 million , which yields an annual dollar-equivalent interest rate of 7.491% . Upon maturity of the notes, the counterparties will pay us €302 million and we will pay the counterparties $403 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 are designated as cash flow hedges and, because they are 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 do not impact earnings. The fair values of the cross currency swaps are recorded on the condensed consolidated balance sheets as liabilities of $64 million and $52 million as of June 30, 2016 and December 31, 2015, respectively. The euro-denominated debt in long-term debt has been adjusted to $337 million as of June 30, 2016 , using an exchange rate of $1.1106 to €1.00. 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 one of these supply contracts, we are committed to supply a minimum of 90 bbtu per day of natural gas through March 2025. The bifurcated derivative is measured at fair value on a quarterly basis and resulted in an unrealized loss of $37 million in the Current Quarter and $17 million in the Current Period, respectively. Both settlements and mark-to-market gains (losses) are included in marketing, gathering and compression revenues in our condensed consolidated statements of operations. Effect of Derivative Instruments – Condensed Consolidated Balance Sheets The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in Condensed Consolidated Balance Sheet Net Fair Value Presented in Condensed Consolidated Balance Sheet ($ in millions) As of June 30, 2016 Commodity Contracts: Short-term derivative asset $ 27 $ (27 ) $ — Short-term derivative liability (278 ) 27 (251 ) Long-term derivative liability (41 ) — (41 ) Total commodity contracts (292 ) — (292 ) Foreign Currency Contracts: (a) Short-term derivative liability (64 ) — (64 ) Total foreign currency contracts (64 ) — (64 ) Supply Contracts: Short-term derivative asset 30 — 30 Long-term derivative asset 250 — 250 Total supply contracts 280 — 280 Total derivatives $ (76 ) $ — $ (76 ) As of December 31, 2015 Commodity Contracts: Short-term derivative asset $ 381 $ (66 ) $ 315 Short-term derivative liability (106 ) 66 (40 ) Long-term derivative liability (8 ) — (8 ) Total commodity contracts 267 — 267 Foreign Currency Contracts: (a) Long-term derivative liability (52 ) — (52 ) Total foreign currency contracts (52 ) — (52 ) Supply Contracts: Short-term derivative asset 51 — 51 Long-term derivative asset 246 — 246 Total supply contracts 297 — 297 Total derivatives $ 512 $ — $ 512 ____________________________________________ (a) Designated as cash flow hedging instruments. As of June 30, 2016 and December 31, 2015, 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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Oil, natural gas and NGL revenues $ 884 $ 1,264 $ 1,696 $ 2,646 Gains (losses) on undesignated oil, natural gas and NGL derivatives (438 ) (43 ) (246 ) 135 Losses on terminated cash flow hedges (6 ) (5 ) (17 ) (22 ) Total oil, natural gas and NGL revenues $ 440 $ 1,216 $ 1,433 $ 2,759 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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 1,219 $ 2,085 $ 2,159 $ 3,760 Gains (losses) on undesignated supply contract derivatives (37 ) 220 (17 ) 220 Total marketing, gathering and compression revenues $ 1,182 $ 2,305 $ 2,142 $ 3,980 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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Interest expense on senior notes $ 107 $ 171 $ 222 $ 342 Amortization of loan discount, issuance costs and other 7 12 18 23 Interest expense on credit facilities 12 3 17 6 Gains on terminated fair value hedges (1 ) (1 ) (1 ) (2 ) Gains on undesignated interest rate derivatives — — — (10 ) Capitalized interest (63 ) (114 ) (132 ) (237 ) Total interest expense $ 62 $ 71 $ 124 $ 122 Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) A reconciliation of the changes in accumulated other comprehensive income (loss) in our condensed consolidated statements of stockholders’ equity related to our cash flow hedges is presented below. Three Months Ended June 30, 2016 2015 Before After Before After ($ in millions) Balance, beginning of period $ (156 ) $ (99 ) $ (216 ) $ (134 ) Net change in fair value (13 ) (15 ) — — Losses reclassified to income 6 10 5 3 Balance, end of period $ (163 ) $ (104 ) $ (211 ) $ (131 ) Six Months Ended June 30, 2016 2015 Before After Before After ($ in millions) Balance, beginning of period $ (160 ) $ (99 ) $ (231 ) $ (143 ) Net change in fair value (20 ) (19 ) (2 ) (1 ) Losses reclassified to income 17 14 22 13 Balance, end of period $ (163 ) $ (104 ) $ (211 ) $ (131 ) Approximately $99 million of the $104 million of accumulated other comprehensive loss as of June 30, 2016 represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the hedged production is still expected to occur. Deferred gain or loss amounts will be recognized in earnings in the month in which the originally forecasted hedged production occurs. As of June 30, 2016 , we expect to transfer approximately $20 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 rated investment grade 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 June 30, 2016 , our oil, natural gas, NGL, foreign currency and supply contract derivative instruments were spread among 15 counterparties. Hedging Arrangements In 2015, we began entering into bilateral hedging agreements. The counterparties’ and our obligations under certain of 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, interest rate 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 June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 27 $ — $ 27 Commodity liabilities — (248 ) (71 ) (319 ) Foreign currency liabilities — (64 ) — (64 ) Supply contract assets — — 280 280 Total derivatives $ — $ (285 ) $ 209 $ (76 ) As of December 31, 2015 Derivative Assets (Liabilities): Commodity assets $ — $ 372 $ 9 $ 381 Commodity liabilities — (14 ) (100 ) (114 ) Foreign currency liabilities — (52 ) — (52 ) Supply contract assets — — 297 297 Total derivatives $ — $ 306 $ 206 $ 512 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) Beginning balance as of December 31, 2015 $ (91 ) $ 297 Total gains (losses) (unrealized): Included in earnings (a) (8 ) 13 Total purchases, issuances, sales and settlements: Settlements 28 (30 ) Ending balance as of June 30, 2016 $ (71 ) $ 280 Beginning balance as of December 31, 2014 $ (54 ) $ 1 Total gains (losses) (unrealized): Included in earnings (a) 80 220 Total purchases, issuances, sales and settlements: Settlements (108 ) — Ending balance as of June 30, 2015 $ (82 ) $ 221 ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2016 2015 2016 2015 ($ in millions) Total gains (losses) included in earnings for the period $ (8 ) $ 80 $ (17 ) $ 220 Change in unrealized gains (losses) related to assets still held at reporting date $ (20 ) $ 69 $ (17 ) $ 220 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. 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 June 30, 2016 : Instrument Type Unobservable Input Range Weighted Average Fair Value June 30, 2016 ($ in millions) Oil trades (a) Oil price volatility curves 21.20% – 33.68% 29.04% $ (6 ) Supply contracts (b) Oil price volatility curves 19.94% – 37.25% 24.41% $ 280 Natural gas trades (a) Natural gas price volatility curves 19.97% – 53.48% 32.20% $ (65 ) ___________________________________________ (a) Fair value is based on an estimate derived from option models. (b) Fair value is based on an estimate derived from industry standard methodologies which consider historical relationships among various commodities, modeled market prices, time value and volatility factors.

Oil and Natural Gas Property Tr

Oil and Natural Gas Property Transactions (Note)	6 Months Ended
	Jun. 30, 2016
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 Quarter and the Current Period, we sold certain of our noncore oil and natural gas properties for net proceeds of approximately $833 million and $964 million , respectively, after post-closing adjustments. In both the Current Quarter and the Current Period, additional consideration of approximately $106 million was withheld subject to certain title, environmental and other standard contingencies. 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 part of 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. The costs that will apply in the future 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 June 30, 2016 , our outstanding VPPs consisted of the following: 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 1 December 2007 Kentucky and West Virginia 1,100 — 208 — 208 $ 1,953 1.7 346 4.8 385 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 June 30, 2016 Three Months Ended June 30, 2015 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 10 (a) 42.0 1.2 146.0 2.3 78.0 2.2 268.7 4.3 9 38.5 3.3 87.6 4.1 42.5 3.5 94.9 4.4 8 (b) — — — — — 13.6 — 13.6 4 (a) 9.9 1.9 — 2.0 10.7 2.0 — 2.1 3 (a) — 1.0 — 1.0 — 1.6 — 1.6 2 (a) — 0.6 — 0.6 — 1.0 — 1.0 1 — 3.1 — 3.1 — 3.3 — 3.3 90.4 11.1 233.6 13.1 131.2 27.2 363.6 30.3 Six Months Ended June 30, 2016 Six Months Ended June 30, 2015 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 5.8 161.0 4.4 545.0 8.7 9 77.9 6.7 176.9 8.2 86.1 7.2 191.9 8.9 8 (b) — — — — — 27.6 — 27.6 4 (a) 20.0 3.8 — 3.9 21.7 4.1 — 4.2 3 (a) — 2.5 — 2.5 — 3.3 — 3.3 2 (a) — 1.5 — 1.5 — 2.1 — 2.1 1 — 6.4 — 6.4 — 6.8 — 6.8 205.9 23.9 545.6 28.3 268.8 55.5 736.9 61.6 ____________________________________________ (a) In connection with certain divestitures in the Current Quarter, we purchased the remaining oil and natural gas interests previously sold in connection with VPP #10, VPP #4, VPP #3 and VPP #2. A majority of the oil and gas interests purchased were subsequently sold to the buyers of the assets. (b) VPP #8 expired in August 2015. The volumes remaining to be delivered on behalf of our VPP buyers as of June 30, 2016 were as follows: Volume Remaining as of June 30, 2016 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 56 0.6 52.4 1.4 64.2 1 78 — 71.9 — 71.9 0.6 124.3 1.4 136.1

Variable Interest Entities (Not

Variable Interest Entities (Note)	6 Months Ended
	Jun. 30, 2016
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract]
Variable Interest Entities Disclosure	Variable Interest Entities 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. We have determined that 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 obligations to perform under the development agreement, and (ii) as a result of the subordination and incentive thresholds applicable to the subordinated units we hold in the Trust, we have the obligation to absorb losses and the right to receive residual returns 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 June 30, 2016 and December 31, 2015, we had $261 million and $259 million , respectively, of noncontrolling interests on our condensed consolidated balance sheets attributable to the Trust. Net loss attributable to the Trust’s noncontrolling interests is presented in our condensed consolidated statements of operations as a nominal amount in the Current Quarter, a loss of approximately $1 million in the Prior Quarter, a nominal amount in the Current Period and a loss of approximately $1 million in the Prior Period. 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 June 30, 2016 , $1 million of cash and cash equivalents, $488 million of proved oil and natural gas properties and $456 million of accumulated depreciation, depletion and amortization 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 (Note)

Impairments (Note)	6 Months Ended
	Jun. 30, 2016
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 Current Quarter, the Prior Quarter, the Current Period and the Prior Period, capitalized costs of oil and natural gas properties exceeded the ceiling, resulting in impairments in the carrying value of our oil and natural gas properties of $1.045 billion , $5.015 billion , $1.898 billion and $9.991 billion , respectively. Cash flow hedges which relate to future periods increased the ceiling test impairment by $160 million , $190 million , $326 million and $385 million in the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, respectively. Based on the first-day-of-the-month prices we have received over the 11 months ended August 1, 2016 , as well as the current strip price for September 2016 , we expect to record another write-down in the carrying value of our oil and natural gas properties in the third quarter of 2016 , although the amount of impairment could be mitigated by the impact of anticipated divestitures in the third quarter of 2016 or other factors. Further write-downs in subsequent quarters will occur if the trailing 12-month commodity prices continue to fall as compared to the commodity prices used in prior quarters. Impairments of Fixed Assets and Other We review our long-lived assets, other than oil and natural gas properties, for recoverability whenever events or changes in circumstances indicate that carrying amounts may not be recoverable. We recognize an impairment loss if the carrying amount of a long-lived asset is not recoverable and exceeds its fair value. A summary of our impairments of fixed assets by asset class and other charges for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period is as follows: Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) Natural gas compressors $ — $ 21 $ 20 $ 21 Buildings and land — — 7 — Other 6 63 17 67 Total impairments of fixed assets and other $ 6 $ 84 $ 44 $ 88 Nonrecurring Fair Value Measurements. Fair value measurements for certain of the impairments discussed above 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 (Note)

Income Taxes (Note)	6 Months Ended
	Jun. 30, 2016
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 the 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 reversal of deferred tax liabilities, and tax planning strategies as well as the current and forecasted business economics of our industry. Based on our estimated operating results for the subsequent quarters, we project being in a net deferred tax asset position as of December 31, 2016. 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 we expect to incur over the three-year period ending December 31, 2016. This 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 estimates of future taxable income are increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence such as future expected growth.

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value Measurements (Note)	6 Months Ended
	Jun. 30, 2016
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 June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Financial Assets (Liabilities): Other current assets $ 45 $ — $ — $ 45 Other current liabilities (46 ) — — (46 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2015 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 ) 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 (Note)

Segment Information (Note)	6 Months Ended
	Jun. 30, 2016
Segment Reporting, Disclosure of Entity's Reportable Segments [Abstract]
Segment Information Disclosure	Segment Information As of June 30, 2016 , we have two reportable operating segments, each of which is managed separately because of the nature of its operations. The exploration and production operating segment is responsible for finding and producing oil, natural gas and NGL. The marketing, gathering and compression operating segment is responsible for marketing, gathering and compression of oil, natural gas and NGL. Management evaluates the performance of our segments based upon income (loss) before income taxes. 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 $848 million , $1.204 billion , $1.631 billion and $2.437 billion for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, respectively. During the Current Period, we changed the structure of our internal organization to include certain assets in our Exploration and Production reportable segment instead of our Other segment. Accordingly, this change has been reflected through retroactive revision of the segment information as of December 31, 2015, as shown in the tables below. The following table presents selected financial information for Chesapeake’s operating segments: Exploration and Production Marketing, Gathering and Compression Other Intercompany Eliminations Consolidated Total ($ in millions) Three Months Ended June 30, 2016 Revenues $ 440 $ 2,030 $ — $ (848 ) $ 1,622 Intersegment revenues — (848 ) — 848 — Total revenues $ 440 $ 1,182 $ — $ — $ 1,622 Income (Loss) Before Income Taxes $ (1,755 ) $ (44 ) $ (8 ) $ 57 $ (1,750 ) Three Months Ended June 30, 2015 Revenues $ 1,187 $ 3,509 $ — $ (1,175 ) $ 3,521 Intersegment revenues 29 (1,204 ) — 1,175 — Total revenues $ 1,216 $ 2,305 $ — $ — $ 3,521 Income (Loss) Before Income Taxes $ (5,785 ) $ 134 $ (31 ) $ 86 $ (5,596 ) Six Months Ended June 30, 2016 Revenues $ 1,433 $ 3,773 $ — $ (1,631 ) $ 3,575 Intersegment revenues — (1,631 ) — 1,631 — Total revenues $ 1,433 $ 2,142 $ — $ — $ 3,575 Income (Loss) Before Income Taxes $ (2,650 ) $ (4 ) $ (17 ) $ — $ (2,671 ) Six Months Ended June 30, 2015 Revenues $ 2,707 $ 6,417 $ — $ (2,385 ) $ 6,739 Intersegment revenues 52 (2,437 ) — 2,385 — Total revenues $ 2,759 $ 3,980 $ — $ — $ 6,739 Income (Loss) Before Income Taxes $ (11,134 ) $ 138 $ (45 ) $ 353 $ (10,688 ) As of June 30, 2016 Total Assets $ 10,842 $ 1,421 $ 1,423 $ (199 ) $ 13,487 As of December 31, 2015 Total Assets (as previously reported) $ 11,776 $ 1,524 $ 4,325 $ (311 ) $ 17,314 As of December 31, 2015 Total Assets (as revised) $ 14,610 $ 1,524 $ 1,491 $ (311 ) $ 17,314

Recently Issued Accounting Stan

Recently Issued Accounting Standards (Note)	6 Months Ended
	Jun. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of Adoption of New Accounting Pronouncements	The retrospective adjustment to the December 31, 2015 consolidated balance sheet is shown below. As Previously Reported December 31, 2015 Adjustment Effect As Adjusted $ in millions Other long-term assets $ 333 $ (43 ) $ 290 Long-term debt, net $ 10,354 $ (43 ) $ 10,311 Recently Issued Accounting Standards In May 2014, the 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. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early application not permitted. In July 2015, the FASB approved a one-year deferral of the effective date as well as permission to early adopt the new revenue recognition standard as of the original effective date. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In August 2014, the FASB issued updated guidance that requires management, for each annual and interim reporting period, to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the consolidated financial statements are issued. If management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern, certain disclosures are required to be made within the footnotes to the consolidated financial statements. The amendments in this update are effective for annual periods ending after December 15, 2016 and interim periods thereafter, with early adoption permitted. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In March 2016, the FASB issued guidance for improvements to employee share-based payment accounting to simplify the accounting for share-based compensation. The new standard requires all excess tax benefits and reductions from differences between the deduction for tax purposes and the compensation cost recorded for financial reporting purposes be recognized as income tax expense or benefit in the income statement and not recognized as additional paid-in capital. The new standard also requires all excess tax benefits and deficiencies to be classified as operating activity within the statement of cash flows. For public business entities, the amendments are effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Early adoption is permitted in any interim or annual period, with any adjustments reflected as of the beginning of the fiscal year of adoption. We have elected to early adopt the amendments effective January 1, 2016. The cumulative-effect adjustment to retained earnings for all excess tax benefits not previously recognized as of the beginning period is fully offset by a corresponding change in the valuation allowance resulting in no change. The implementation of this guidance did not have a material impact on our consolidated financial statements and related disclosures. In March 2016, the FASB issued new guidance that will result in fewer put or call options embedded in debt instruments qualifying for separate derivative accounting because companies will not be required to assess whether the contingent event, such as change in control or an IPO, is related to interest rates or credit risks. This standard is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures.

Basis of Presentation (Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Basis of Accounting Policy	The accompanying unaudited condensed consolidated financial statements of Chesapeake Energy Corporation ("Chesapeake" or the "Company") and its subsidiaries 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.

Impairments (Policies)

Impairments (Policies)	6 Months Ended
	Jun. 30, 2016
Asset Impairment Charges [Abstract]
Impairment or Disposal of Long-Lived Assets, Policy	Our proved oil and natural gas properties are subject to quarterly full cost ceiling tests.

Income Taxes Income Taxes (Poli

Income Taxes Income Taxes (Policy)	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Tax, Policy	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 the taxable income is generated, to determine whether a valuation allowance is required.

Recently Issued Accounting St28

Recently Issued Accounting Standards (Policies)	6 Months Ended
	Jun. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements, Policy	Recently Issued Accounting Standards In May 2014, the 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. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early application not permitted. In July 2015, the FASB approved a one-year deferral of the effective date as well as permission to early adopt the new revenue recognition standard as of the original effective date. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In August 2014, the FASB issued updated guidance that requires management, for each annual and interim reporting period, to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the consolidated financial statements are issued. If management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern, certain disclosures are required to be made within the footnotes to the consolidated financial statements. The amendments in this update are effective for annual periods ending after December 15, 2016 and interim periods thereafter, with early adoption permitted. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In March 2016, the FASB issued guidance for improvements to employee share-based payment accounting to simplify the accounting for share-based compensation. The new standard requires all excess tax benefits and reductions from differences between the deduction for tax purposes and the compensation cost recorded for financial reporting purposes be recognized as income tax expense or benefit in the income statement and not recognized as additional paid-in capital. The new standard also requires all excess tax benefits and deficiencies to be classified as operating activity within the statement of cash flows. For public business entities, the amendments are effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Early adoption is permitted in any interim or annual period, with any adjustments reflected as of the beginning of the fiscal year of adoption. We have elected to early adopt the amendments effective January 1, 2016. The cumulative-effect adjustment to retained earnings for all excess tax benefits not previously recognized as of the beginning period is fully offset by a corresponding change in the valuation allowance resulting in no change. The implementation of this guidance did not have a material impact on our consolidated financial statements and related disclosures. In March 2016, the FASB issued new guidance that will result in fewer put or call options embedded in debt instruments qualifying for separate derivative accounting because companies will not be required to assess whether the contingent event, such as change in control or an IPO, is related to interest rates or credit risks. This standard is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures.

Basis of Presentation (Tables)

Basis of Presentation (Tables)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Schedule of Adoption of New Accounting Pronouncements	The retrospective adjustment to the December 31, 2015 consolidated balance sheet is shown below. As Previously Reported December 31, 2015 Adjustment Effect As Adjusted $ in millions Other long-term assets $ 333 $ (43 ) $ 290 Long-term debt, net $ 10,354 $ (43 ) $ 10,311 Recently Issued Accounting Standards In May 2014, the 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. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early application not permitted. In July 2015, the FASB approved a one-year deferral of the effective date as well as permission to early adopt the new revenue recognition standard as of the original effective date. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In August 2014, the FASB issued updated guidance that requires management, for each annual and interim reporting period, to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the consolidated financial statements are issued. If management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern, certain disclosures are required to be made within the footnotes to the consolidated financial statements. The amendments in this update are effective for annual periods ending after December 15, 2016 and interim periods thereafter, with early adoption permitted. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. 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. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures. In March 2016, the FASB issued guidance for improvements to employee share-based payment accounting to simplify the accounting for share-based compensation. The new standard requires all excess tax benefits and reductions from differences between the deduction for tax purposes and the compensation cost recorded for financial reporting purposes be recognized as income tax expense or benefit in the income statement and not recognized as additional paid-in capital. The new standard also requires all excess tax benefits and deficiencies to be classified as operating activity within the statement of cash flows. For public business entities, the amendments are effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Early adoption is permitted in any interim or annual period, with any adjustments reflected as of the beginning of the fiscal year of adoption. We have elected to early adopt the amendments effective January 1, 2016. The cumulative-effect adjustment to retained earnings for all excess tax benefits not previously recognized as of the beginning period is fully offset by a corresponding change in the valuation allowance resulting in no change. The implementation of this guidance did not have a material impact on our consolidated financial statements and related disclosures. In March 2016, the FASB issued new guidance that will result in fewer put or call options embedded in debt instruments qualifying for separate derivative accounting because companies will not be required to assess whether the contingent event, such as change in control or an IPO, is related to interest rates or credit risks. This standard is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. We are evaluating the impact of this guidance on our consolidated financial statements and related disclosures.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2016
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Antidilutive Securities Excluded From Computation Of Earnings Per Share	For the Current Quarter, the Prior Quarter, the Current Period and the Prior Period, shares of the following securities and associated adjustments to net income, representing dividends on preferred stock and allocated earnings on participating securities, were excluded from the calculation of diluted EPS as the effect was antidilutive. Net Income Adjustments Shares ($ in millions) (in millions) Three Months Ended June 30, 2016 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 21 58 5.75% cumulative convertible preferred stock (series A) $ 16 42 5.00% cumulative convertible preferred stock (series 2005B) $ 2 6 4.50% cumulative convertible preferred stock $ 3 6 Participating securities $ — 1 Three Months Ended June 30, 2015 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 21 59 5.75% cumulative convertible preferred stock (series A) $ 16 42 5.00% cumulative convertible preferred stock (series 2005B) $ 3 6 4.50% cumulative convertible preferred stock $ 3 6 Participating securities $ — 1 Six Months Ended June 30, 2016 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 42 58 5.75% cumulative convertible preferred stock (series A) $ 32 42 5.00% cumulative convertible preferred stock (series 2005B) $ 5 6 4.50% cumulative convertible preferred stock $ 6 6 Participating securities $ — 1 Six Months Ended June 30, 2015 Common stock equivalent of our preferred stock outstanding: 5.75% cumulative convertible preferred stock $ 43 59 5.75% cumulative convertible preferred stock (series A) $ 32 42 5.00% cumulative convertible preferred stock (series 2005B) $ 5 6 4.50% cumulative convertible preferred stock $ 6 6 Participating securities $ — 2

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Schedule of Debt	Our long-term debt consisted of the following as of June 30, 2016 and December 31, 2015: June 30, 2016 December 31, 2015 Principal Amount Carrying Principal Carrying ($ in millions) 3.25% senior notes due 2016 $ — $ — $ 381 $ 381 6.25% euro-denominated senior notes due 2017 (a) 337 337 329 329 6.5% senior notes due 2017 315 315 453 453 7.25% senior notes due 2018 531 531 538 538 Floating rate senior notes due 2019 949 949 1,104 1,104 6.625% senior notes due 2020 822 822 822 822 6.875% senior notes due 2020 302 302 304 304 6.125% senior notes due 2021 584 584 589 589 5.375% senior notes due 2021 276 276 286 286 4.875% senior notes due 2022 607 607 639 639 8.00% senior secured second lien notes due 2022 2,425 3,501 2,425 3,584 5.75% senior notes due 2023 384 384 384 384 2.75% contingent convertible senior notes due 2035 (b) 2 2 2 2 2.5% contingent convertible senior notes due 2037 (b)(c) 730 694 1,110 1,027 2.25% contingent convertible senior notes due 2038 (b)(c) 315 276 340 290 Revolving credit facility 100 100 — — Debt issuance costs — (35 ) — (43 ) Discount on senior notes — (2 ) — (4 ) Interest rate derivatives (d) — 6 — 7 Total debt, net 8,679 9,649 9,706 10,692 Less current maturities of long-term debt, net (e) (1,066 ) (1,028 ) (381 ) (381 ) Total long-term debt, net $ 7,613 $ 8,621 $ 9,325 $ 10,311 ___________________________________________ (a) The principal and carrying amounts shown are based on the exchange rate of $1.1106 to €1.00 and $1.0862 to €1.00 as of June 30, 2016 and December 31, 2015, respectively. See Foreign Currency Derivatives in Note 8 for information on our related foreign currency derivatives. (b) The repurchase, conversion, contingent interest and redemption provisions of our contingent convertible senior notes are as follows: Holders’ Demand Repurchase Rights . The holders of our contingent 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 on any of four dates that are five , ten , fifteen and twenty years before the maturity date. Optional Conversion by Holders . At the holder’s option, prior to maturity under certain circumstances, the notes are convertible into cash and, if applicable, shares of our common stock using a net share settlement process. 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 specified period in the Current Quarter, the price of our common stock was below the threshold level for each series of the contingent convertible senior notes and, as a result, the holders do not have the option to convert their notes into cash and common stock in the third quarter of 2016 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 and the Prior Quarter. In general, upon conversion of a contingent convertible senior note, the holder will receive cash equal to the principal amount of the note and common stock for the note’s conversion value in excess of the principal amount. Contingent Interest. We will pay contingent interest on the convertible senior notes after they have been outstanding at least ten years during certain periods if the average trading price of the notes exceeds the threshold defined in the indenture. The holders’ demand repurchase dates, the common stock price conversion threshold amounts (as adjusted to give effect to cash dividends on our common stock) and the ending date of the first six-month period in which contingent interest may be payable for the contingent convertible senior notes are as follows: Contingent Convertible Senior Notes Holders' Demand Repurchase Dates Common Stock Price Conversion Thresholds Contingent Interest First Payable (if applicable) 2.75% due 2035 November 15, 2020, 2025, 2030 $ 45.02 May 14, 2016 2.5% due 2037 May 15, 2017, 2022, 2027, 2032 $ 59.44 November 14, 2017 2.25% due 2038 December 15, 2018, 2023, 2028, 2033 $ 100.20 June 14, 2019 Optional Redemption by the Company. We may redeem the contingent convertible senior notes once they have been outstanding for ten years at a redemption price of 100% of the principal amount of the notes, payable in cash. In addition, we may redeem our 2.75% Contingent Convertible Senior Notes due 2035 at any time. (c) The carrying amount associated with the equity component of our contingent convertible senior notes as of June 30, 2016 and December 31, 2015 is net of $75 million and $133 million , respectively. This amount is amortized based on an effective yield method. (d) See Interest Rate Derivatives in Note 8 for further discussion related to these instruments. (e) As of June 30, 2016 , current maturities of long-term debt net includes our 6.25% Euro-denominated Senior Notes due 2017 and our 2.5% Contingent Convertible Senior Notes due 2037 (the 2037 Notes). As discussed in footnote (b) above, the holders of our 2037 Notes could exercise their individual demand repurchase rights on May 15, 2017 , which would require us to repurchase all or a portion of the principal amount of the notes. As of June 30, 2016 , there was $36 million associated with the equity component of the 2037 Notes.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below. June 30, 2016 December 31, 2015 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 1,028 $ 984 $ 381 $ 366 Long-term debt (Level 1) $ 8,515 $ 5,793 $ 10,304 $ 3,735 Long-term debt (Level 2) $ 100 $ 83 $ — $ —

Contingencies and Commitments32

Contingencies and Commitments (Tables)	6 Months Ended
	Jun. 30, 2016
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. June 30, ($ in millions) 2016 $ 925 2017 1,874 2018 1,670 2019 1,374 2020 1,046 2021 – 2099 6,572 Total $ 13,461

Other Liabilities (Tables)

Other Liabilities (Tables)	6 Months Ended
	Jun. 30, 2016
Other Liabilities Disclosure [Abstract]
Other Current Liabilities	Other current liabilities as of June 30, 2016 and December 31, 2015 are detailed below. June 30, December 31, ($ in millions) Revenues and royalties due others $ 430 $ 500 Accrued drilling and production costs 191 212 Joint interest prepayments received 84 169 Accrued compensation and benefits 173 264 Other accrued taxes 68 37 Bank of New York Mellon legal accrual 439 439 Minimum gathering volume commitment — 201 Other 247 397 Total other current liabilities $ 1,632 $ 2,219
Other Long-Term Liabilities	Other long-term liabilities as of June 30, 2016 and December 31, 2015 are detailed below. June 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 175 $ 190 Financing obligations — 29 Unrecognized tax benefits 93 64 Other 151 126 Total other long-term liabilities $ 419 $ 409 ____________________________________________ (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. Approximately $29 million and $21 million of the total $204 million and $211 million obligations are recorded in other current liabilities as of June 30, 2016 and December 31, 2015, respectively.

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2016
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 are detailed below. Six Months Ended 2016 2015 (in thousands) Shares issued as of January 1 664,796 664,944 Exchange of convertible notes 55,428 — Exchange of senior notes 53,924 — Conversion of preferred stock 1,021 — Restricted stock issuances (net of forfeitures and cancellations) 1,529 103 Stock option exercises — 14 Shares issued as of June 30 776,698 665,061
Schedule of Stock by Class,Preferred Stock Conversion Terms	Outstanding shares 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, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions (a) (25 ) (1 ) — — Shares outstanding as of June 30, 2016 1,472 1,099 2,559 2,096 Shares outstanding as of January 1, 2015 and June 30, 2015 1,497 1,100 2,559 2,096 ____________________________________________ (a) In the Current Period, holders of our 5.75% Cumulative Convertible Preferred Stock converted 24,601 shares into 975,488 shares of common stock. Also in the Current Period, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 1,201 shares into 46,018 shares of common stock.
Schedule of Dividends Payable	Our preferred stock dividends for the Current Period (paid in arrears) are detailed below. 5.75% 5.75% (A) 4.50% 5.00% ($ in millions) Dividends in arrears $ 42 $ 32 $ 6 $ 5
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. Six Months Ended 2016 2015 ($ in millions) Balance, December 31 $ (99 ) $ (143 ) Other comprehensive income before reclassifications (19 ) (1 ) Amounts reclassified from accumulated other comprehensive income 14 13 Net other comprehensive income (loss) (5 ) 12 Balance, June 30 $ (104 ) $ (131 )

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2016
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, 2016 10,455 $ 17.31 Granted 2,882 $ 3.77 Vested (3,713 ) $ 17.35 Forfeited (902 ) $ 13.17 Unvested restricted stock as of June 30, 2016 8,722 $ 13.25
Equity-Classified Share-Based Payment Award Valuation Assumptions	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 46.07 % Risk-free interest rate 1.70 % Dividend yield — % The Company utilized the Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 79.84 % Risk-free interest rate 0.65 % Dividend yield for value of awards — %
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, 2016 5,377 $ 19.37 5.80 $ — Granted 4,932 $ 3.71 Exercised — $ — $ — Expired (477 ) $ 19.06 Forfeited (945 ) $ 5.66 Outstanding as of June 30, 2016 8,887 $ 12.15 7.47 $ 2 Exercisable as of June 30, 2016 3,125 $ 19.62 5.32 $ — ___________________________________________ (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 (credits) related to PSUs for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 1 $ (4 ) $ 3 $ (14 ) Restructuring and other termination costs — (5 ) 1 (15 ) Marketing, gathering and compression — — — (1 ) Oil and natural gas properties — — — (1 ) Total $ 1 $ (9 ) $ 4 $ (31 ) We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 10 $ 12 $ 18 $ 24 Oil and natural gas properties 5 8 9 15 Oil, natural gas and NGL production expenses 3 6 6 10 Marketing, gathering and compression expenses — 2 1 3 Total $ 18 $ 28 $ 34 $ 52
Liability-Classified Share-Based Payment Award Valuation Assumptions	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 46.07 % Risk-free interest rate 1.70 % Dividend yield — % The Company utilized the Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 79.84 % Risk-free interest rate 0.65 % Dividend yield for value of awards — %
Schedule of Nonvested Performance-based Units Activity	The following table presents a summary of our 2016, 2015 and 2014 PSU awards. Grant Date Fair Value June 30, 2016 Units Fair Value Vested Liability ($ in millions) 2016 Awards: Payable 2019 2,348,893 $ 10 $ 11 $ 3 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1 2014 Awards: Payable 2017 561,215 $ 16 $ 1 $ 1
Liability-Classified Stock-Based 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 Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 1 $ (4 ) $ 3 $ (14 ) Restructuring and other termination costs — (5 ) 1 (15 ) Marketing, gathering and compression — — — (1 ) Oil and natural gas properties — — — (1 ) Total $ 1 $ (9 ) $ 4 $ (31 ) We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) General and administrative expenses $ 10 $ 12 $ 18 $ 24 Oil and natural gas properties 5 8 9 15 Oil, natural gas and NGL production expenses 3 6 6 10 Marketing, gathering and compression expenses — 2 1 3 Total $ 18 $ 28 $ 34 $ 52

Derivative and Hedging Activi36

Derivative and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2016
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 June 30, 2016 and December 31, 2015 are provided below. June 30, 2016 December 31, 2015 Volume Fair Value Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 19.8 $ (78 ) 13.5 $ 144 Call options 12.3 (6 ) 19.2 (7 ) Total oil 32.1 (84 ) 32.7 137 Natural gas (tbtu): Fixed-price swaps 577 (130 ) 500 229 Collars 38 (4 ) — — Call options 205 (56 ) 295 (99 ) Basis protection swaps 44 (8 ) 57 — Total natural gas 864 (198 ) 852 130 NGL (mmgal): Fixed-price swaps 144 (10 ) — — Total estimated fair value $ (292 ) $ 267
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 June 30, 2016 and December 31, 2015 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in Condensed Consolidated Balance Sheet Net Fair Value Presented in Condensed Consolidated Balance Sheet ($ in millions) As of June 30, 2016 Commodity Contracts: Short-term derivative asset $ 27 $ (27 ) $ — Short-term derivative liability (278 ) 27 (251 ) Long-term derivative liability (41 ) — (41 ) Total commodity contracts (292 ) — (292 ) Foreign Currency Contracts: (a) Short-term derivative liability (64 ) — (64 ) Total foreign currency contracts (64 ) — (64 ) Supply Contracts: Short-term derivative asset 30 — 30 Long-term derivative asset 250 — 250 Total supply contracts 280 — 280 Total derivatives $ (76 ) $ — $ (76 ) As of December 31, 2015 Commodity Contracts: Short-term derivative asset $ 381 $ (66 ) $ 315 Short-term derivative liability (106 ) 66 (40 ) Long-term derivative liability (8 ) — (8 ) Total commodity contracts 267 — 267 Foreign Currency Contracts: (a) Long-term derivative liability (52 ) — (52 ) Total foreign currency contracts (52 ) — (52 ) Supply Contracts: Short-term derivative asset 51 — 51 Long-term derivative asset 246 — 246 Total supply contracts 297 — 297 Total derivatives $ 512 $ — $ 512 ____________________________________________ (a) Designated as cash flow hedging instruments
Schedule of Derivative Instruments, Natural Gas and Oil Sales	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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 1,219 $ 2,085 $ 2,159 $ 3,760 Gains (losses) on undesignated supply contract derivatives (37 ) 220 (17 ) 220 Total marketing, gathering and compression revenues $ 1,182 $ 2,305 $ 2,142 $ 3,980 The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) Oil, natural gas and NGL revenues $ 884 $ 1,264 $ 1,696 $ 2,646 Gains (losses) on undesignated oil, natural gas and NGL derivatives (438 ) (43 ) (246 ) 135 Losses on terminated cash flow hedges (6 ) (5 ) (17 ) (22 ) Total oil, natural gas and NGL revenues $ 440 $ 1,216 $ 1,433 $ 2,759
Schedule of Derivative Instruments, Marketing, Gathering and Compression Sales	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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 1,219 $ 2,085 $ 2,159 $ 3,760 Gains (losses) on undesignated supply contract derivatives (37 ) 220 (17 ) 220 Total marketing, gathering and compression revenues $ 1,182 $ 2,305 $ 2,142 $ 3,980 The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below. Three Months Ended Six Months Ended 2016 2015 2016 2015 ($ in millions) Oil, natural gas and NGL revenues $ 884 $ 1,264 $ 1,696 $ 2,646 Gains (losses) on undesignated oil, natural gas and NGL derivatives (438 ) (43 ) (246 ) 135 Losses on terminated cash flow hedges (6 ) (5 ) (17 ) (22 ) Total oil, natural gas and NGL revenues $ 440 $ 1,216 $ 1,433 $ 2,759
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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Interest expense on senior notes $ 107 $ 171 $ 222 $ 342 Amortization of loan discount, issuance costs and other 7 12 18 23 Interest expense on credit facilities 12 3 17 6 Gains on terminated fair value hedges (1 ) (1 ) (1 ) (2 ) Gains on undesignated interest rate derivatives — — — (10 ) Capitalized interest (63 ) (114 ) (132 ) (237 ) Total interest expense $ 62 $ 71 $ 124 $ 122
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 June 30, 2016 2015 Before After Before After ($ in millions) Balance, beginning of period $ (156 ) $ (99 ) $ (216 ) $ (134 ) Net change in fair value (13 ) (15 ) — — Losses reclassified to income 6 10 5 3 Balance, end of period $ (163 ) $ (104 ) $ (211 ) $ (131 ) Six Months Ended June 30, 2016 2015 Before After Before After ($ in millions) Balance, beginning of period $ (160 ) $ (99 ) $ (231 ) $ (143 ) Net change in fair value (20 ) (19 ) (2 ) (1 ) Losses reclassified to income 17 14 22 13 Balance, end of period $ (163 ) $ (104 ) $ (211 ) $ (131 )
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 June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 27 $ — $ 27 Commodity liabilities — (248 ) (71 ) (319 ) Foreign currency liabilities — (64 ) — (64 ) Supply contract assets — — 280 280 Total derivatives $ — $ (285 ) $ 209 $ (76 ) As of December 31, 2015 Derivative Assets (Liabilities): Commodity assets $ — $ 372 $ 9 $ 381 Commodity liabilities — (14 ) (100 ) (114 ) Foreign currency liabilities — (52 ) — (52 ) Supply contract assets — — 297 297 Total derivatives $ — $ 306 $ 206 $ 512 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) Beginning balance as of December 31, 2015 $ (91 ) $ 297 Total gains (losses) (unrealized): Included in earnings (a) (8 ) 13 Total purchases, issuances, sales and settlements: Settlements 28 (30 ) Ending balance as of June 30, 2016 $ (71 ) $ 280 Beginning balance as of December 31, 2014 $ (54 ) $ 1 Total gains (losses) (unrealized): Included in earnings (a) 80 220 Total purchases, issuances, sales and settlements: Settlements (108 ) — Ending balance as of June 30, 2015 $ (82 ) $ 221 ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2016 2015 2016 2015 ($ in millions) Total gains (losses) included in earnings for the period $ (8 ) $ 80 $ (17 ) $ 220 Change in unrealized gains (losses) related to assets still held at reporting date $ (20 ) $ 69 $ (17 ) $ 220 The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Financial Assets (Liabilities): Other current assets $ 45 $ — $ — $ 45 Other current liabilities (46 ) — — (46 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2015 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 )
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 27 $ — $ 27 Commodity liabilities — (248 ) (71 ) (319 ) Foreign currency liabilities — (64 ) — (64 ) Supply contract assets — — 280 280 Total derivatives $ — $ (285 ) $ 209 $ (76 ) As of December 31, 2015 Derivative Assets (Liabilities): Commodity assets $ — $ 372 $ 9 $ 381 Commodity liabilities — (14 ) (100 ) (114 ) Foreign currency liabilities — (52 ) — (52 ) Supply contract assets — — 297 297 Total derivatives $ — $ 306 $ 206 $ 512 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) Beginning balance as of December 31, 2015 $ (91 ) $ 297 Total gains (losses) (unrealized): Included in earnings (a) (8 ) 13 Total purchases, issuances, sales and settlements: Settlements 28 (30 ) Ending balance as of June 30, 2016 $ (71 ) $ 280 Beginning balance as of December 31, 2014 $ (54 ) $ 1 Total gains (losses) (unrealized): Included in earnings (a) 80 220 Total purchases, issuances, sales and settlements: Settlements (108 ) — Ending balance as of June 30, 2015 $ (82 ) $ 221 ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2016 2015 2016 2015 ($ in millions) Total gains (losses) included in earnings for the period $ (8 ) $ 80 $ (17 ) $ 220 Change in unrealized gains (losses) related to assets still held at reporting date $ (20 ) $ 69 $ (17 ) $ 220
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 June 30, 2016 : Instrument Type Unobservable Input Range Weighted Average Fair Value June 30, 2016 ($ in millions) Oil trades (a) Oil price volatility curves 21.20% – 33.68% 29.04% $ (6 ) Supply contracts (b) Oil price volatility curves 19.94% – 37.25% 24.41% $ 280 Natural gas trades (a) Natural gas price volatility curves 19.97% – 53.48% 32.20% $ (65 ) ___________________________________________ (a) Fair value is based on an estimate derived from option models. (b) Fair value is based on an estimate derived from industry standard methodologies which consider historical relationships among various commodities, modeled market prices, time value and volatility factors.

Oil and Natural Gas Property 37

Oil and Natural Gas Property Transactions (Tables)	6 Months Ended
	Jun. 30, 2016
Property, Plant and Equipment [Abstract]
VPP Transactions	As of June 30, 2016 , our outstanding VPPs consisted of the following: 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 1 December 2007 Kentucky and West Virginia 1,100 — 208 — 208 $ 1,953 1.7 346 4.8 385
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 June 30, 2016 Three Months Ended June 30, 2015 VPP # Oil Natural Gas NGL Total Oil Natural Gas NGL Total (mbbl) (bcf) (mbbl) (bcfe) (mbbl) (bcf) (mbbl) (bcfe) 10 (a) 42.0 1.2 146.0 2.3 78.0 2.2 268.7 4.3 9 38.5 3.3 87.6 4.1 42.5 3.5 94.9 4.4 8 (b) — — — — — 13.6 — 13.6 4 (a) 9.9 1.9 — 2.0 10.7 2.0 — 2.1 3 (a) — 1.0 — 1.0 — 1.6 — 1.6 2 (a) — 0.6 — 0.6 — 1.0 — 1.0 1 — 3.1 — 3.1 — 3.3 — 3.3 90.4 11.1 233.6 13.1 131.2 27.2 363.6 30.3 Six Months Ended June 30, 2016 Six Months Ended June 30, 2015 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 5.8 161.0 4.4 545.0 8.7 9 77.9 6.7 176.9 8.2 86.1 7.2 191.9 8.9 8 (b) — — — — — 27.6 — 27.6 4 (a) 20.0 3.8 — 3.9 21.7 4.1 — 4.2 3 (a) — 2.5 — 2.5 — 3.3 — 3.3 2 (a) — 1.5 — 1.5 — 2.1 — 2.1 1 — 6.4 — 6.4 — 6.8 — 6.8 205.9 23.9 545.6 28.3 268.8 55.5 736.9 61.6 ____________________________________________ (a) In connection with certain divestitures in the Current Quarter, we purchased the remaining oil and natural gas interests previously sold in connection with VPP #10, VPP #4, VPP #3 and VPP #2. A majority of the oil and gas interests purchased were subsequently sold to the buyers of the assets. (b) VPP #8 expired in August 2015.
VPP Volumes Remaining to Be Delivered	The volumes remaining to be delivered on behalf of our VPP buyers as of June 30, 2016 were as follows: Volume Remaining as of June 30, 2016 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 56 0.6 52.4 1.4 64.2 1 78 — 71.9 — 71.9 0.6 124.3 1.4 136.1

Impairments (Tables)

Impairments (Tables)	6 Months Ended
	Jun. 30, 2016
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 Six Months Ended 2016 2015 2016 2015 ($ in millions) Natural gas compressors $ — $ 21 $ 20 $ 21 Buildings and land — — 7 — Other 6 63 17 67 Total impairments of fixed assets and other $ 6 $ 84 $ 44 $ 88

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2016
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 June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 27 $ — $ 27 Commodity liabilities — (248 ) (71 ) (319 ) Foreign currency liabilities — (64 ) — (64 ) Supply contract assets — — 280 280 Total derivatives $ — $ (285 ) $ 209 $ (76 ) As of December 31, 2015 Derivative Assets (Liabilities): Commodity assets $ — $ 372 $ 9 $ 381 Commodity liabilities — (14 ) (100 ) (114 ) Foreign currency liabilities — (52 ) — (52 ) Supply contract assets — — 297 297 Total derivatives $ — $ 306 $ 206 $ 512 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) Beginning balance as of December 31, 2015 $ (91 ) $ 297 Total gains (losses) (unrealized): Included in earnings (a) (8 ) 13 Total purchases, issuances, sales and settlements: Settlements 28 (30 ) Ending balance as of June 30, 2016 $ (71 ) $ 280 Beginning balance as of December 31, 2014 $ (54 ) $ 1 Total gains (losses) (unrealized): Included in earnings (a) 80 220 Total purchases, issuances, sales and settlements: Settlements (108 ) — Ending balance as of June 30, 2015 $ (82 ) $ 221 ___________________________________________ (a) Oil, Natural Gas and NGL Sales Marketing, Gathering and Compression Revenue 2016 2015 2016 2015 ($ in millions) Total gains (losses) included in earnings for the period $ (8 ) $ 80 $ (17 ) $ 220 Change in unrealized gains (losses) related to assets still held at reporting date $ (20 ) $ 69 $ (17 ) $ 220 The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2016 Financial Assets (Liabilities): Other current assets $ 45 $ — $ — $ 45 Other current liabilities (46 ) — — (46 ) Total $ (1 ) $ — $ — $ (1 ) As of December 31, 2015 Financial Assets (Liabilities): Other current assets $ 50 $ — $ — $ 50 Other current liabilities (51 ) — — (51 ) Total $ (1 ) $ — $ — $ (1 )

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2016
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 June 30, 2016 Revenues $ 440 $ 2,030 $ — $ (848 ) $ 1,622 Intersegment revenues — (848 ) — 848 — Total revenues $ 440 $ 1,182 $ — $ — $ 1,622 Income (Loss) Before Income Taxes $ (1,755 ) $ (44 ) $ (8 ) $ 57 $ (1,750 ) Three Months Ended June 30, 2015 Revenues $ 1,187 $ 3,509 $ — $ (1,175 ) $ 3,521 Intersegment revenues 29 (1,204 ) — 1,175 — Total revenues $ 1,216 $ 2,305 $ — $ — $ 3,521 Income (Loss) Before Income Taxes $ (5,785 ) $ 134 $ (31 ) $ 86 $ (5,596 ) Six Months Ended June 30, 2016 Revenues $ 1,433 $ 3,773 $ — $ (1,631 ) $ 3,575 Intersegment revenues — (1,631 ) — 1,631 — Total revenues $ 1,433 $ 2,142 $ — $ — $ 3,575 Income (Loss) Before Income Taxes $ (2,650 ) $ (4 ) $ (17 ) $ — $ (2,671 ) Six Months Ended June 30, 2015 Revenues $ 2,707 $ 6,417 $ — $ (2,385 ) $ 6,739 Intersegment revenues 52 (2,437 ) — 2,385 — Total revenues $ 2,759 $ 3,980 $ — $ — $ 6,739 Income (Loss) Before Income Taxes $ (11,134 ) $ 138 $ (45 ) $ 353 $ (10,688 ) As of June 30, 2016 Total Assets $ 10,842 $ 1,421 $ 1,423 $ (199 ) $ 13,487 As of December 31, 2015 Total Assets (as previously reported) $ 11,776 $ 1,524 $ 4,325 $ (311 ) $ 17,314 As of December 31, 2015 Total Assets (as revised) $ 14,610 $ 1,524 $ 1,491 $ (311 ) $ 17,314

Basis of Presentation Basis of

Basis of Presentation Basis of Presentation Debt Reclassifications Table (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets	$ 348	$ 290
Long-term debt, net	$ 8,621	10,311
Accounting Standards Update 2015-03 [Member] | Other Noncurrent Assets [Member] | Scenario, Previously Reported [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets		333
Accounting Standards Update 2015-03 [Member] | Other Noncurrent Assets [Member] | Restatement Adjustment [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets		(43)
Accounting Standards Update 2015-03 [Member] | Other Noncurrent Liabilities [Member] | Scenario, Previously Reported [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Long-term debt, net		10,354
Accounting Standards Update 2015-03 [Member] | Other Noncurrent Liabilities [Member] | Restatement Adjustment [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Long-term debt, net		$ (43)

Basis of Presentation - Narrati

Basis of Presentation - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Aug. 01, 2016	Dec. 31, 2015
Summary of Significant Accounting Policies [Table] [Line Items]
Impairment of oil and natural gas properties	$ 1,045	$ 5,015	$ 1,898	$ 9,991
Debt Instrument, Face Amount	8,679		8,679			$ 9,706
Long-term Debt, Maturities, Repayments of Principal in Year Two	1,382		1,382
Long-term Debt, Maturities, Repayments of Principal in Year Three	846		846
Long-term Debt, Gross	9,649		9,649			10,692
Line of Credit Facility, Remaining Borrowing Capacity	3,087		3,087
Collateral, Received Requests [Member] | Revolving Credit Facility [Member] | Subsequent Event [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Cash Collateral for Borrowed Securities					$ 274
Collateral, Additional Required [Member] | Scenario, Forecast [Member] | Revolving Credit Facility [Member] | Subsequent Event [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Cash Collateral for Borrowed Securities					$ 664
6.25% Euro-Denominated Senior Notes Due 2017 [ Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Year Two	337		337
2.5% Contingent Convertible Senior Notes due 2037 [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Year Two	730		730
6.5% Senior Notes Due 2017 [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Year Two	315		315
Line of Credit [Member] | Revolving Credit Facility [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Debt Instrument, Face Amount						0
Long-term Debt, Gross	100		100
Senior Notes [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Debt Instrument, Face Amount						329
Long-term Debt, Gross	$ 337		$ 337			329
Debt Instrument, Interest Rate, Stated Percentage	6.25%		6.25%
Senior Notes [Member] | 2.5% Contingent Convertible Senior Notes due 2037 [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Debt Instrument, Face Amount	$ 730		$ 730			1,110
Long-term Debt, Gross	$ 694		$ 694			1,027
Debt Instrument, Interest Rate, Stated Percentage	2.50%		2.50%
Senior Notes [Member] | 6.5% Senior Notes Due 2017 [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Debt Instrument, Face Amount	$ 315		$ 315			453
Long-term Debt, Gross	$ 315		$ 315			$ 453
Debt Instrument, Interest Rate, Stated Percentage	6.50%		6.50%
Senior Notes [Member] | 6.75% Senior Notes Due 2019 [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.775%		6.775%

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities Excluded from Computation of EPS Table (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income Adjustments	$ 0	$ 0	$ 0	$ 0
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1	1	1	2
5.75% Cumulative Convertible Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income Adjustments	$ 21	$ 21	$ 42	$ 43
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	58	59	58	59
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income Adjustments	$ 16	$ 16	$ 32	$ 32
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	42	42	42	42
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income Adjustments	$ 2	$ 3	$ 5	$ 5
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	6	6	6	6
4.50% Cumulative Convertible Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income Adjustments	$ 3	$ 3	$ 6	$ 6
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	6	6	6	6

Debt - Long-Term Debt Table (De

Debt - Long-Term Debt Table (Details) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)$ / shares$ / €	Dec. 31, 2015USD ($)$ / €	Dec. 31, 2006$ / €
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 8,679	$ 9,706
Long-term Debt, Gross	9,649	10,692
Deferred Long-term Liability Charges	(35)	(43)
Debt Instrument, Unamortized Discount	(2)	(4)
Long-term debt, current maturities including discount	(1,066)	(381)
Current maturities of long-term debt, net	(1,028)	(381)
Long-term Debt, Fair Value	7,613	9,325
Long-term debt, net	$ 8,621	10,311
Commitment Period	10 years
Line of Credit [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		0
Long-term Debt, Gross	$ 100
Long-term Line of Credit	100	0
Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	$ (75)	(133)
Percentage Of Principal Amount Of Notes For Repurchase Requirement Of Contingent Convertible Senior Notes	100.00%
Commitment Period	10 years
Debt Instrument, Convertible, Terms of Conversion Feature	5 days
Debt Instrument, Redemption Price, Percentage	100.00%
Convertible Debt [Member] | Debt Instrument, Redemption, Period One [Member]
Long-Term Debt Instrument [Line Items]
Commitment Period	5 years
Convertible Debt [Member] | Debt Instrument, Redemption, Period Two [Member]
Long-Term Debt Instrument [Line Items]
Commitment Period	10 years
Convertible Debt [Member] | Debt Instrument, Redemption, Period Three [Member]
Long-Term Debt Instrument [Line Items]
Commitment Period	15 years
Convertible Debt [Member] | Debt Instrument, Redemption, Period Four [Member]
Long-Term Debt Instrument [Line Items]
Commitment Period	20 years
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	6	7
3.25% Senior Notes due 2016 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	0	381
Long-term Debt, Gross	$ 0	381
Debt Instrument, Interest Rate, Stated Percentage	3.25%
6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		329
Long-term Debt, Gross	$ 337	$ 329
Debt Instrument, Interest Rate, Stated Percentage	6.25%
6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Cross Currency Interest Rate Contract [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Derivative, Forward Exchange Rate | $ / €	1.1106	1.0862	1.3325
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%
6.5% Senior Notes Due 2017 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 315	$ 453
Long-term Debt, Gross	$ 315	453
Debt Instrument, Interest Rate, Stated Percentage	6.50%
7.25% Senior Notes Due 2018 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 531	538
Long-term Debt, Gross	$ 531	538
Debt Instrument, Interest Rate, Stated Percentage	7.25%
Floating Rate Senior Notes due 2019 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 949	1,104
Long-term Debt, Gross	949	1,104
6.625% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	822	822
Long-term Debt, Gross	$ 822	822
Debt Instrument, Interest Rate, Stated Percentage	6.625%
6.875% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 302	304
Long-term Debt, Gross	$ 302	304
Debt Instrument, Interest Rate, Stated Percentage	6.875%
6.125% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 584	589
Long-term Debt, Gross	$ 584	589
Debt Instrument, Interest Rate, Stated Percentage	6.125%
5.375% Senior Notes due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 276	286
Long-term Debt, Gross	$ 276	286
Debt Instrument, Interest Rate, Stated Percentage	5.375%
4.875% Senior Notes due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 607	639
Long-term Debt, Gross	$ 607	639
Debt Instrument, Interest Rate, Stated Percentage	4.875%
8.00% Senior Secured Second Lien Notes Due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 2,425	2,425
Long-term Debt, Gross	$ 3,501	3,584
Debt Instrument, Interest Rate, Stated Percentage	8.00%
5.75% Senior Notes due 2023 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 384	384
Long-term Debt, Gross	$ 384	384
Debt Instrument, Interest Rate, Stated Percentage	5.75%
2.75% Contingent Convertible Senior Notes Due 2035 [Member]
Long-Term Debt Instrument [Line Items]
Common Stock Price Conversion Thresholds | $ / shares	$ 45.02
Debt Instrument, Date of First Required Payment	May 14, 2016
2.75% Contingent Convertible Senior Notes Due 2035 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 2	2
Long-term Debt, Gross	$ 2	2
Debt Instrument, Interest Rate, Stated Percentage	2.75%
2.5% Contingent Convertible Senior Notes due 2037 [Member]
Long-Term Debt Instrument [Line Items]
Common Stock Price Conversion Thresholds | $ / shares	$ 59.44
Debt Instrument, Date of First Required Payment	Nov. 14, 2017
2.5% Contingent Convertible Senior Notes due 2037 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 730	1,110
Long-term Debt, Gross	$ 694	1,027
Debt Instrument, Interest Rate, Stated Percentage	2.50%
2.5% Contingent Convertible Senior Notes due 2037 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	$ (36)
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Debt Instrument, Redemption Period, Start Date	May 15, 2017
2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Common Stock Price Conversion Thresholds | $ / shares	$ 100.20
Debt Instrument, Date of First Required Payment	Jun. 14, 2019
2.25% Contingent Convertible Senior Notes Due 2038 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 315	340
Long-term Debt, Gross	$ 276	$ 290
Debt Instrument, Interest Rate, Stated Percentage	2.25%

Debt - Long Term Debt Table (Ph

Debt - Long Term Debt Table (Phantom) (Details)	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
3.25% Senior Notes due 2016 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Debt Instrument Maturity Date	Mar. 15, 2016
6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.25%
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	Jun. 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	Feb. 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. 5, 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
2.75% Contingent Convertible Senior Notes Due 2035 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instruments Convertible Optional Repurchase Dates	November 15, 2015, 2020, 2025, 2030
2.75% Contingent Convertible Senior Notes Due 2035 [Member] | Senior Notes [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]
Long-Term Debt Instrument [Line Items]
Debt Instruments Convertible Optional Repurchase Dates	May 15, 2017, 2022, 2027, 2032
2.5% Contingent Convertible Senior Notes due 2037 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Debt Instrument Maturity Date	May 17, 2037
2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instruments Convertible Optional Repurchase Dates	December 15, 2018, 2023, 2028, 2033
2.25% Contingent Convertible Senior Notes Due 2038 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument Maturity Date	Dec. 15, 2038

Debt - Senior Notes and Conting

Debt - Senior Notes and Contingent Convertible Senior Notes Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Long-Term Debt Instrument [Line Items]
Cash paid to purchase debt			$ 472	$ 0
Gains on purchases or exchanges of debt	$ 68	$ 0	$ 168	$ 0
Noncontrolling Interest, Ownership Percentage by Parent	100.00%		100.00%
Senior Notes Exchanged for Shares of Common Stock [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	$ 290		$ 290
Debt Conversion, Converted Instrument, Shares Issued			53,923,925
Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount	287		$ 287
Debt Conversion, Converted Instrument, Shares Issued			55,427,782
Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Cash paid to purchase debt			$ 151
Debt Instrument, Repurchased Face Amount	$ 181		181
Senior Notes [Member] | 3.25% Senior Notes due 2016 [Member]
Long-Term Debt Instrument [Line Items]
Cash paid to purchase debt			$ 259
Debt Instrument, Interest Rate, Stated Percentage	3.25%		3.25%
Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Cash paid to purchase debt			$ 63
Debt Instrument, Repurchased Face Amount	$ 118		$ 118

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Apr. 08, 2016	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Long-Term Debt Instrument [Line Items]
Long-term Debt, Gross								$ 9,649		$ 10,692
Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Borrowing capacity			$ 4,000					4,000
Letters of Credit Outstanding, Amount								813
Line of Credit Facility, Description			The amendment reduces the interest coverage ratio from 1.1 to 1.0 to 0.65 to 1.0 through the first quarter of 2017, after which it will increase to 0.70 to 1.0 through the second quarter of 2017, 1.2 to 1.0 through the third quarter of 2017 and 1.25 to 1.0 thereafter. The amendment also includes a collateral value coverage test whereby if the collateral value coverage ratio, tested as of December 31, 2016, falls below 1.1 to 1.0, the $500 million minimum liquidity covenant increases to $750 million, and if the collateral value coverage ratio, tested as of March 31, 2017, falls below 1.25 to 1.0, our borrowing ability will be reduced in order to satisfy such ratio.
Revolving Credit Facility [Member] | Scenario, Forecast [Member]
Long-Term Debt Instrument [Line Items]
Minimum liquidity requirement ($ in millions) when covenant ratio is above 1.1 to 1.0					$ 500
Revolving Credit Facility [Member] | First Lien [Member]
Long-Term Debt Instrument [Line Items]
Borrowing capacity								2,500
Revolving Credit Facility [Member] | Line of Credit [Member]
Long-Term Debt Instrument [Line Items]
Long-term Debt, Gross								100
Revolving Credit Facility, Interest Coverage Ratio [Member] | Scenario, Forecast [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Description				1.25 to 1.0	1.2 to 1.0	0.70 to 1.0	0.65 to 1.0		1.1 to 1.0
Revolving Credit Facility, Collateral Value Coverage Ratio [Member] | Scenario, Forecast [Member] | Minimum [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Description	1.25 to 1.0	1.1 to 1.0
Revolving Credit Facility, Collateral Value Coverage Minimum Liquidity [Member] [Member] | Scenario, Forecast [Member] | Minimum [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Description	500
Revolving Credit Facility, Collateral Value Coverage Minimum Liquidity [Member] [Member] | Scenario, Forecast [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Description	750
6.75% Senior Notes Due 2019 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Supersedeas Bond								$ 461

Debt - Fair Value of Other Fina

Debt - Fair Value of Other Financial Instruments (Table) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 7,613	$ 9,325
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	1,028	381
Long-term Debt, Fair Value	8,515	10,304
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	984	366
Long-term Debt, Fair Value	5,793	3,735
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	100	0
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	$ 83	$ 0

Contingencies - Narrative (Deta

Contingencies - Narrative (Details) - USD ($) $ in Millions	Jul. 17, 2015	Jul. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Loss Contingencies [Line Items]
Provision for legal contingencies			$ 82	$ 334	$ 104	$ 359
6.75% Senior Notes Due 2019 [Member] | Senior Notes [Member]
Loss Contingencies [Line Items]
Supersedeas Bond					$ 461
Debt Instrument, Interest Rate, Stated Percentage			6.775%		6.775%
6.875% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Loss Contingencies [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.875%		6.875%
6.125% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Loss Contingencies [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.125%		6.125%
8.00% Senior Secured Second Lien Notes Due 2022 [Member] | Senior Notes [Member]
Loss Contingencies [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.00%		8.00%
Redemption of 2019 Notes [Member] | 6.75% Senior Notes Due 2019 [Member] | Senior Notes [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	$ 380
Loss Contingency, Prejudgment Interest Awarded	$ 59
Provision for legal contingencies							$ 339	$ 100
MDL [Member]
Loss Contingencies [Line Items]
Percentage of hydrocarbons					97.00%
Payments for Legal Settlements					$ 29
MDL [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Promissory Note, Legal Settlement		$ 10
Term for Promissory Note		3 years

Commitments - Undiscounted Gath

Commitments - Undiscounted Gathering Processing and Transportation Agreements Commitments Table (Details) - Gathering and Processing Equipment [Member] $ in Millions	Jun. 30, 2016USD ($)
Other Commitments [Line Items]
Gathering, Processing and Transportation Commitment, Remainder of Year	$ 925
Gathering, Processing and Transportation Commitment, Due in Second Year	1,874
Gathering, Processing and Transportation Commitment, Due in Third Year	1,670
Gathering, Processing and Transportation Commitment, Due in Fourth Year	1,374
Gathering, Processing and Transportation Commitment, Due in Fifth Year	1,046
Gathering, Processing and Transportation Commitment, Due after Fifth Year	6,572
Gathering, Processing and Transportation Commitment	$ 13,461

Commitments - Narrative (Detail

Commitments - Narrative (Details) $ in Millions	1 Months Ended	6 Months Ended
	Nov. 30, 2011well	Jun. 30, 2016USD ($)Crew
Long-term Purchase Commitment [Line Items]
Gathering Fee Escalation Rate		15.00%
Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Long-term Purchase Commitment [Line Items]
Productive Oil Wells, Number of Wells, Gross | well	69
Wells, Initial Number of Wells [Member] | Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Long-term Purchase Commitment [Line Items]
Development Wells Drilled, Net Productive | well	118
Drilling Rig Leases [Member]
Long-term Purchase Commitment [Line Items]
Contractual Obligation | $		$ 177
Drilling Rig Leases [Member] | Minimum [Member]
Long-term Purchase Commitment [Line Items]
Lease Term		3 months
Drilling Rig Leases [Member] | Maximum [Member]
Long-term Purchase Commitment [Line Items]
Lease Term		3 years
Pressure Pumping Leases [Member] | Seven Seven Energy Inc. [Member]
Long-term Purchase Commitment [Line Items]
Percent of Total		50.00%
Operating Leases, Future Minimum Payments Due | $		$ 155
Pressure Pumping Leases [Member] | Seven Seven Energy Inc. [Member] | Through June 30, 2017 [Member]
Long-term Purchase Commitment [Line Items]
Number of Crews | Crew		3

Other Liabilities - Current Tab

Other Liabilities - Current Table (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Other Current Liabilities [Line Items]
Revenues and royalties due others	$ 430	$ 500
Accrued drilling and production costs	191	212
Joint interest prepayments received	84	169
Accrued compensation and benefits	173	264
Other accrued taxes	68	37
Minimum gathering volume commitment	0	201
Other current liabilities	247	397
Total other current liabilities	1,632	2,219
Bank of New York Melton legal accrual [Member]
Other Current Liabilities [Line Items]
Estimated Litigation Liability	$ 439	$ 439

Other Liabilities - Long-Term T

Other Liabilities - Long-Term Table (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)well	Dec. 31, 2015USD ($)
Other Long-Term Liabilities [Line Items]
Financing obligations	$ 0	$ 29
Other long-term liabilities	151	126
Total other long-term liabilities	419	409
Total other current liabilities	1,632	2,219
Other Noncurrent Liabilities [Member]
Other Long-Term Liabilities [Line Items]
Unrecognized Tax Benefits	93	64
Noncontrolling Interest, Chesapeake Utica L L C [Member]
Other Long-Term Liabilities [Line Items]
Conveyance Obligation Noncurrent	175	190
Total other long-term liabilities	204	211
Total other current liabilities	$ 29	$ 21
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%

Equity Equity - Common Stock Ta

Equity Equity - Common Stock Table (Details) - shares	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	664,795,509
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	0
Common Stock, Shares, Issued End of Period	776,697,583
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	664,796,000	664,944,000
Stock Issued During Period, Shares, Restricted Stock Award, Net of Forfeitures	1,529,000	103,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	0	14,000
Common Stock, Shares, Issued End of Period	776,698,000	665,061,000
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	55,428,000	0
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	53,924,000	0
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	1,021,000	0

Equity - Convertible Preferred

Equity - Convertible Preferred Stock Table (Details) - shares	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period	7,251,515
Preferred stock, shares outstanding, end of period	7,225,713
Preferred stock, shares outstanding, beginning and end of period	7,251,515
5.75% Cumulative Convertible Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period	1,497,000
Preferred stock, shares outstanding, end of period	1,472,000	1,497,000
Preferred stock, shares outstanding, beginning and end of period	1,497,000	1,497,000
5.75% Cumulative Convertible Preferred Stock [Member] | Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	24,601
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period		1,497,000
Conversion of Stock, Shares Converted	25,000
Preferred stock, shares outstanding, end of period		1,497,000
Preferred stock, shares outstanding, beginning and end of period		1,497,000
5.75% Cumulative Convertible Preferred Stock [Member] | Common Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	975,488
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period	1,100,000
Preferred stock, shares outstanding, end of period	1,099,000	1,100,000
Preferred stock, shares outstanding, beginning and end of period	1,100,000	1,100,000
5.75% Cumulative Convertible Preferred Stock Series A [Member] | Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	1,201
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period		1,100,000
Conversion of Stock, Shares Converted	1,000
Preferred stock, shares outstanding, end of period		1,100,000
Preferred stock, shares outstanding, beginning and end of period		1,100,000
5.75% Cumulative Convertible Preferred Stock Series A [Member] | Common Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	46,018
4.50% Cumulative Convertible Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period	2,559,000
Preferred stock, shares outstanding, end of period	2,559,000	2,559,000
Preferred stock, shares outstanding, beginning and end of period	2,559,000	2,559,000
4.50% Cumulative Convertible Preferred Stock [Member] | Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period		2,559,000
Conversion of Stock, Shares Converted	0
Preferred stock, shares outstanding, end of period		2,559,000
Preferred stock, shares outstanding, beginning and end of period		2,559,000
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period	2,096,000
Preferred stock, shares outstanding, end of period	2,096,000	2,096,000
Preferred stock, shares outstanding, beginning and end of period	2,096,000	2,096,000
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member] | Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Preferred stock, shares outstanding, beginning of period		2,096,000
Conversion of Stock, Shares Converted	0
Preferred stock, shares outstanding, end of period		2,096,000
Preferred stock, shares outstanding, beginning and end of period		2,096,000

Equity Equity - Dividends (Deta

Equity Equity - Dividends (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
5.75% Cumulative Convertible Preferred Stock [Member]
Dividends Payable [Line Items]
Preferred Stock, Amount of Preferred Dividends in Arrears	$ 42
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Dividends Payable [Line Items]
Preferred Stock, Amount of Preferred Dividends in Arrears	32
4.50% Cumulative Convertible Preferred Stock [Member]
Dividends Payable [Line Items]
Preferred Stock, Amount of Preferred Dividends in Arrears	6
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Dividends Payable [Line Items]
Preferred Stock, Amount of Preferred Dividends in Arrears	$ 5

Equity - AOCI Changes Net of Ta

Equity - AOCI Changes Net of Tax Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Period Start			$ (99)
Net Other Comprehensive Income	$ (5)	$ 3	(5)	$ 12
Accumulated Other Comprehensive Income (Loss), Net of Tax Period End	(104)		(104)
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 Period Start			(99)	(143)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax			(19)	(1)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax			14	13
Net Other Comprehensive Income			(5)	12
Accumulated Other Comprehensive Income (Loss), Net of Tax Period End	$ (104)	$ (131)	$ (104)	$ (131)

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Equity [Abstract]
Common Stock, Shares Authorized	1,500,000,000		1,500,000,000		1,000,000,000
Common stock, par value (usd per share)	$ 0.01		$ 0.01		$ 0.01
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Oil, natural gas and NGL	$ 440	$ 1,216	$ 1,433	$ 2,759
Commodity Contract [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Oil, natural gas and NGL	$ 10	$ 3	$ 14	$ 13

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock Table (Details) - Restricted Stock [Member] shares in Thousands	6 Months Ended
	Jun. 30, 2016$ / 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	10,455
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | shares	2,882
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period | shares	(3,713)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period | shares	(902)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Shares, Period End | shares	8,722
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	$ 17.31
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ / shares	3.77
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ / shares	17.35
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ / shares	13.17
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Period End | $ / shares	$ 13.25

Share-Based Compensation - Equi

Share-Based Compensation - Equity-Classified Valuation Table (Details) - Employee Stock Option [Member]	6 Months Ended
	Jun. 30, 2016
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	46.07%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.70%
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	Jun. 30, 2016	Jan. 01, 2016	Jun. 30, 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		5,377	5,377
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross			4,932
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			(477)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested Options Forfeited, Number of Shares			(945)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number Period End	8,887		8,887
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	3,125		3,125
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		$ 19.37	$ 19.37
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price			3.71
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			19.06
Share-based Compensation Arrangements by Share-based Payment Award, Options, Forfeitures in Period, Weighted Average Exercise Price			5.66
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price Period End	$ 12.15		12.15
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 19.62		$ 19.62
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	7 years 5 months 20 days	5 years 9 months 20 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	5 years 3 months 27 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value Period Start		$ 0	$ 0
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		2
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value	$ 0		$ 0

Share-Based Compensation - Eq62

Share-Based Compensation - Equity-Classified Compensation Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 18	$ 28	$ 34	$ 52
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	10	12	18	24
Oil and Gas Properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	5	8	9	15
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	3	6	6	10
Marketing, Gathering and Compression Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 0	$ 2	$ 1	$ 3

Share-Based Compensation - Liab

Share-Based Compensation - Liability Classified Valuation Table (Details) - Performance Shares [Member]	6 Months Ended
	Jun. 30, 2016
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	79.84%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	0.65%
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	Jun. 30, 2016	Jan. 01, 2016	Jan. 01, 2015	Jan. 01, 2014
Payable 2019 [Member] | Year of 2016 [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	$ 11	$ 10
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 3
Payable 2018 [Member] | Year of 2015 [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
Payable 2017 [Member] | Year of 2014 [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	561,215
Fair Value of Share Based Award	$ 1			$ 16
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 1

Share-Based Compensation - Li65

Share-Based Compensation - Liability-Classified Compensation Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 18	$ 28	$ 34	$ 52
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	10	12	18	24
Marketing, Gathering and Compression Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	0	2	1	3
Oil and Gas Properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	5	8	9	15
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	1	(9)	4	(31)
Performance Shares [Member] | General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	1	(4)	3	(14)
Performance Shares [Member] | Restructuring Charges [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	0	(5)	1	(15)
Performance Shares [Member] | 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)
Performance Shares [Member] | Oil and Gas Properties [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) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value	$ 16
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 76
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	1 year 6 months 27 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
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	$ 10
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
TSR [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Monte Carlo simulation
Year of 2015 [Member] | Long-Term Incentive Plan [Member] | Performance Shares [Member] | Minimum [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		100.00%
Management [Member] | Employee Stock Option [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	33.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Management [Member] | Employee Stock Option [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
Management [Member] | Employee Stock Option [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
Management [Member] | Stock Option Award Three Year Anniversary [Member] | Employee Stock Option [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
Management [Member] | Stock Optioin Award Four Year Anniversary [Member] | Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years
Management [Member] | Stock option Award Five Year Anniversary [Member] | Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	5 years
Management [Member] | Years of 2015 and 2016 [Member] | Share-Based Comp Award Three Year Anniversary [Member] | 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 Rights		third
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | Performance Shares [Member] | Minimum [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	100.00%
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | Performance Shares [Member] | Maximum [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	200.00%
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Minimum [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	0.00%
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Maximum [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	100.00%
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | Operational Component [Member] | Minimum [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	0.00%
Management [Member] | Year of 2016 [Member] | Long-Term Incentive Plan [Member] | Operational Component [Member] | Maximum [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	100.00%
Management [Member] | Year of 2015 [Member] | Long-Term Incentive Plan [Member] | Performance Shares [Member] | Maximum [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	200.00%
Management [Member] | Year of 2015 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Minimum [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	0.00%
Management [Member] | Year of 2015 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Maximum [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	100.00%
Management [Member] | Year of 2015 [Member] | Long-Term Incentive Plan [Member] | Operational Component [Member] | Minimum [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	0.00%
Management [Member] | Year of 2015 [Member] | Long-Term Incentive Plan [Member] | Operational Component [Member] | Maximum [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	50.00%
Management [Member] | Year of 2014 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Minimum [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	0.00%
Management [Member] | Year of 2014 [Member] | Long-Term Incentive Plan [Member] | TSR [Member] | Maximum [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	200.00%

Derivative and Hedging Activi67

Derivative and Hedging Activities - Derivative Instruments Table (Details) MMBbls in Millions, $ in Millions, MMBTU in Trillions	6 Months Ended	12 Months Ended
	Jun. 30, 2016USD ($)MMBTUMMBbls	Dec. 31, 2015USD ($)MMBTUMMBbls	Jun. 30, 2015USD ($)
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (76)	$ 512	$ 512
Oil [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	32.1	32.7
Derivative Assets (Liabilities), at Fair Value, Net	$ (84)	$ 137
Oil [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	19.8	13.5
Derivative Assets (Liabilities), at Fair Value, Net	$ (78)	$ 144
Oil [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	12.3	19.2
Derivative Assets (Liabilities), at Fair Value, Net	$ (6)	$ (7)
Natural Gas [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (198)	$ 130
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	864	852
Natural Gas [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (130)	$ 229
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	577	500
Natural Gas [Member] | Call Option [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (56)	$ (99)
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	205	295
Natural Gas [Member] | Collar [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (4)	$ 0
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	38	0
Natural Gas [Member] | Basis Swap [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (8)	$ 0
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	44	57
Natural Gas Liquids [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (10)	$ 0
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	144	0
Commodity Contract [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (292)	$ 267

Derivative and Hedging Activi68

Derivative and Hedging Activities - Derivative Instruments in Balance Sheet Table (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		$ 512
Derivative Liability, Fair Value, Gross Liability	$ (76)
Derivative Asset, Fair Value, Gross Liability	0
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net	(76)	512	$ 512
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net	(292)	267
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		267
Derivative Liability, Fair Value, Gross Liability	(292)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	(292)	267
Not Designated as Hedging Instrument [Member] | Supply Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		297
Derivative Asset, Fair Value, Gross Liability	0
Derivative Liability, Fair Value, Gross Asset	280	0
Derivative, Fair Value, Net	280	297
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	27	381
Derivative Asset, Fair Value, Gross Liability	(27)	(66)
Derivative, Fair Value, Net	0	315
Not Designated as Hedging Instrument [Member] | Other Current Assets [Member] | Supply Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	30	51
Derivative Asset, Fair Value, Gross Liability	0	0
Derivative, Fair Value, Net	30	51
Not Designated as Hedging Instrument [Member] | Other Noncurrent Assets [Member] | Supply Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	250	246
Derivative Asset, Fair Value, Gross Liability	0	0
Derivative, Fair Value, Net	250	246
Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(278)	(106)
Derivative Liability, Fair Value, Gross Asset	27	66
Derivative, Fair Value, Net	(251)	(40)
Not Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(41)	(8)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	(41)	(8)
Designated as Hedging Instrument [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(64)	(52)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	(64)	(52)
Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(64)
Derivative Liability, Fair Value, Gross Asset	0
Derivative, Fair Value, Net	$ (64)
Designated as Hedging Instrument [Member] | Other Noncurrent Liabilities [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		(52)
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net		$ (52)

Derivative and Hedging Activi69

Derivative and Hedging Activities - Natural Gas and Oil Sales Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Oil, natural gas and NGL revenues	$ 440	$ 1,216	$ 1,433	$ 2,759
Gains (losses) on undesignated oil, natural gas and NGL derivatives	0	0	0	10
Total oil, natural gas and NGL revenues	440	1,216	1,433	2,759
Oil, Natural Gas and NGL [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Oil, natural gas and NGL revenues	884	1,264	1,696	2,646
Gains (losses) on undesignated oil, natural gas and NGL derivatives	(438)	(43)	(246)	135
Losses on terminated cash flow hedges	(6)	(5)	(17)	(22)
Total oil, natural gas and NGL revenues	$ 884	$ 1,264	$ 1,696	$ 2,646

Derivative and Hedging Activi70

Derivative and Hedging Activities Derivative and Hedging Activities, Marketing, Gathering and Compression Sales (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Marketing, gathering and compression revenues	$ 1,182	$ 2,305	$ 2,142	$ 3,980
Gains (losses) on undesignated supply contract derivatives	0	0	0	10
Total marketing, gathering and compression revenues	1,182	2,305	2,142	3,980
Marketing, Gathering And Compression [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Marketing, gathering and compression revenues	1,219	2,085	2,159	3,760
Gains (losses) on undesignated supply contract derivatives	(37)	220	(17)	220
Total marketing, gathering and compression revenues	$ 1,219	$ 2,085	$ 2,159	$ 3,760

Derivative and Hedging Activi71

Derivative and Hedging Activities - Components of Interest Income and Interest Expense Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Interest expense on senior notes	$ 107	$ 171	$ 222	$ 342
Amortization of loan discount, issuance costs and other	7	12	18	23
Interest expense on credit facilities	12	3	17	6
Gains on terminated fair value hedges	(1)	(1)	(1)	(2)
Gains on undesignated interest rate derivatives	0	0	0	(10)
Capitalized interest	(63)	(114)	(132)	(237)
Total interest expense	$ 62	$ 71	$ 124	$ 122

Derivative and Hedging Activi72

Derivative and Hedging Activities - Cash Flow Hedges Components of AOCI Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Period Start			$ (99)
Other Comprehensive Income (Loss), Net Change in Fair Value, Net of Tax	$ (15)	$ 0	(19)	$ (1)
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	10	3	14	13
Accumulated Other Comprehensive Income (Loss), Net of Tax Period End	(104)		(104)
Cash Flow Hedging [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Before Tax, Period Start	(156)	(216)	(160)	(231)
Accumulated Other Comprehensive Income (Loss), Net of Tax Period Start	(99)	(134)	(99)	(143)
Other Comprehensive Income (Loss), Net Change in Fair Value, Before Tax	(13)	0	(20)	(2)
Other Comprehensive Income (Loss), Losses Reclassified to Income, Before Tax	6	5	17	22
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	10	3	14	13
Accumulated Other Comprehensive Income (Loss), Before Tax, Period End	(163)	(211)	(163)	(211)
Accumulated Other Comprehensive Income (Loss), Net of Tax Period End	$ (104)	$ (131)	$ (104)	$ (131)

Derivative and Hedging Activi73

Derivative and Hedging Activities - Fair Value of Recurring Assets and Liabilities Table (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (76)	$ 512	$ 512
Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	27		381
Derivative Liability	(319)		(114)
Derivative Assets (Liabilities), at Fair Value, Net	(292)	267
Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability	(64)		(52)
Supply Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	280		297
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		0
Fair Value, Inputs, Level 1 [Member] | Supply Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	0		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	(285)		306
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	27		372
Derivative Liability	(248)		(14)
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	(64)		(52)
Fair Value, Inputs, Level 2 [Member] | Supply Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	0		0
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	209		206
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	0		9
Derivative Liability	(71)		(100)
Derivative Assets (Liabilities), at Fair Value, Net	(71)	(91)	(82)	$ (54)
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		0
Fair Value, Inputs, Level 3 [Member] | Supply Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	280		297
Derivative Assets (Liabilities), at Fair Value, Net	$ 280	$ 297	$ 221	$ 1

Derivative and Hedging Activi74

Derivative and Hedging Activities - Fair Value Level 3 Measurements Table (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Period Start		$ 512
Derivative Assets (Liabilities), at Fair Value, Net, Period End	$ 512	(76)	$ 512
Commodity Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Period Start		267
Derivative Assets (Liabilities), at Fair Value, Net, Period End		(292)
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, Period End	206	209	206
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, Period Start		(91)	(54)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings		(8)	80
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements		28	(108)
Derivative Assets (Liabilities), at Fair Value, Net, Period End	(82)	(71)	(82)
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member] | Oil, Natural Gas and NGL [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		(8)	80
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)		(20)	69
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, Period Start		297	1
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings		13	220
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements		(30)	0
Derivative Assets (Liabilities), at Fair Value, Net, Period End	221	280	221
Fair Value, Inputs, Level 3 [Member] | Supply Contract [Member] | Marketing, Gathering And Compression [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	$ 220		(17)
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)		$ (17)	$ 220

Derivative and Hedging Activi75

Derivative and Hedging Activities - Quantitative Disclosures Level 3 Table (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
Energy Related Derivative, Oil Trades [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	29.04%
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (6)
Energy Related Derivative, Oil Trades [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	21.20%
Energy Related Derivative, Oil Trades [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	33.68%
Energy Related Derivative, Supply Contract [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	24.41%
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 280
Energy Related Derivative, Supply Contract [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	19.94%
Energy Related Derivative, Supply Contract [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	37.25%
Energy Related Derivative, Natural Gas Trades [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	32.20%
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (65)
Energy Related Derivative, Natural Gas Trades [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	19.97%
Energy Related Derivative, Natural Gas Trades [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	53.48%

Derivative and Hedging Activi76

Derivative and Hedging Activities - Narrative (Details) € in Millions, $ in Millions, MMBTU in Billions	1 Months Ended		3 Months Ended		6 Months Ended
	Dec. 31, 2015USD ($)Derivatives$ / €	Dec. 31, 2006USD ($)$ / €	Jun. 30, 2016USD ($)counterpartyDerivatives$ / €	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)MMBTUcounterpartyDerivatives$ / €	Jun. 30, 2015USD ($)	Jun. 30, 2016EUR (€)counterpartyDerivatives$ / €	Mar. 31, 2016USD ($)	Dec. 31, 2015EUR (€)Derivatives$ / €	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2006EUR (€)$ / €
Derivative [Line Items]
Number of Interest Rate Derivatives Held | Derivatives	0		0		0		0		0
Gains on purchases or exchanges of debt			$ 68	$ 0	$ 168	$ 0
Derivative Liability, Fair Value, Gross Liability			(76)		(76)
Debt Instrument, Face Amount	$ 9,706		8,679		8,679
Accumulated other comprehensive loss	(99)		(104)		(104)
Expected amount to be transferred of during the next 12 months			(20)		(20)
Cash Flow Hedging [Member]
Derivative [Line Items]
Accumulated other comprehensive loss	(99)		(104)	$ (131)	(104)	$ (131)		$ (99)		$ (134)	$ (143)
Cash Flow Hedging [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Derivative [Line Items]
Accumulated other comprehensive loss			(99)		(99)
Senior Notes [Member]
Derivative [Line Items]
Debt Instrument, Repurchased Face Amount			$ 181		$ 181
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%
Debt Instrument, Face Amount	329
Interest Rate Contract [Member]
Derivative [Line Items]
Amortization Period of Deferred Gain (Loss) on Discontinuation of Fair Value Hedge					4 years
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge	7		$ 6		$ 6
Debt Instrument, Face Amount	$ 0		$ 0		$ 0
Cross Currency Interest Rate Contract [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member]
Derivative [Line Items]
Debt Instrument, Repurchased Face Amount | €									€ 42
Debt Instrument, Interest Rate, Stated Percentage	6.25%		6.25%		6.25%		6.25%		6.25%
Cash paid to purchase debt	$ (8)
Gains on purchases or exchanges of debt	$ (8)
Semi Annual Interest Rate Swap Payments By Counterparty | €							€ 302					€ 9
Short-term Debt, Refinanced, Description		$ 15	$ 403		$ 403
Dollar Equivalent Interest Rate		7.491%
Derivative, Forward Exchange Rate | $ / €	1.0862	1.3325	1.1106		1.1106		1.1106		1.0862			1.3325
Foreign Exchange Contract [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ (52)		$ (64)		$ (64)
Other Contracts, A [Member]
Derivative [Line Items]
Derivative, Number of Instruments Held | Derivatives			1		1		1
Other Contracts, A [Member] | Minimum [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU					90
Other Contracts, A [Member] | Fair Value, Inputs, Level 3 [Member] | Marketing, Gathering And Compression [Member]
Derivative [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings			$ 37		$ 17
Credit Risk [Member]
Derivative [Line Items]
Number of counterparties in hedge facility | counterparty			15		15		15

Oil and Natural Gas Property 77

Oil and Natural Gas Property Transactions - VPP Transactions Table (Details) MBbls in Millions, $ in Millions, Mcfe in Billions, Mcf in Billions	3 Months Ended		6 Months Ended
	Jun. 30, 2011USD ($)	Dec. 31, 2007USD ($)McfeMBblsMcf	Jun. 30, 2016USD ($)McfeMBblsMcf	May 31, 2011McfeMBblsMcf
VPP Transactions [Line Items]
Cash Proceeds from Volumetric Production Payment (VPP) | $			$ 1,953
Proved Developed Reserves (Energy) | Mcfe			385
Oil [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)			1.7
Natural Gas [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume) | Mcf			346
Natural Gas Liquids [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)			4.8
VPP 9 Mid-Continent [Member]
VPP Transactions [Line Items]
Cash Proceeds from Volumetric Production Payment (VPP) | $	$ 853
Proved Developed Reserves (Energy) | Mcfe				177
VPP 9 Mid-Continent [Member] | Oil [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)				1.7
VPP 9 Mid-Continent [Member] | Natural Gas [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume) | Mcf				138
VPP 9 Mid-Continent [Member] | Natural Gas Liquids [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)				4.8
VPP 1 Kentucky and West Virginia [Member]
VPP Transactions [Line Items]
Cash Proceeds from Volumetric Production Payment (VPP) | $		$ 1,100
Proved Developed Reserves (Energy) | Mcfe		208
VPP 1 Kentucky and West Virginia [Member] | Oil [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)		0
VPP 1 Kentucky and West Virginia [Member] | Natural Gas [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume) | Mcf		208
VPP 1 Kentucky and West Virginia [Member] | Natural Gas Liquids [Member]
VPP Transactions [Line Items]
Proved Developed Reserves (Volume)		0

Oil and Natural Gas Property 78

Oil and Natural Gas Property Transactions - VPP Volumes Produced During Period Table (Details) Mcfe in Billions, Mcf in Billions	3 Months Ended		6 Months Ended
	Jun. 30, 2016McfeMBblsMcf	Jun. 30, 2015McfeMBblsMcf	Jun. 30, 2016McfeMBblsMcf	Jun. 30, 2015McfeMBblsMcf
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	13.1	30.3	28.3	61.6
Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	90,400	0	205,900	268,800
Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	11.1	27.2	23.9	55.5
Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	233,600	363,600	545,600	736,900
VPP 10 Anadarko Basin Granite Wash [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	2.3	4.3	5.8	8.7
VPP 10 Anadarko Basin Granite Wash [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	42,000	78,000	108,000	161,000
VPP 10 Anadarko Basin Granite Wash [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	1.2	2.2	3	4.4
VPP 10 Anadarko Basin Granite Wash [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	146,000	268,700	368,700	545,000
VPP 9 Mid-Continent [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	4.1	4.4	8.2	8.9
VPP 9 Mid-Continent [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	38,500	131,200	77,900	86,100
VPP 9 Mid-Continent [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	3.3	3.5	6.7	7.2
VPP 9 Mid-Continent [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	87,600	94,900	176,900	191,900
VPP 8 Barnett Shale [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	0	13.6	0	27.6
VPP 8 Barnett Shale [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	42,500	0	0
VPP 8 Barnett Shale [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	0	13.6	0	27.6
VPP 8 Barnett Shale [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0
VPP 4 Anadarko and Arkoma Basins [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	2	2.1	3.9	4.2
VPP 4 Anadarko and Arkoma Basins [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	9,900	0	20,000	21,700
VPP 4 Anadarko and Arkoma Basins [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	1.9	2	3.8	4.1
VPP 4 Anadarko and Arkoma Basins [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0
VPP 3 Anadarko Basin [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	1	1.6	2.5	3.3
VPP 3 Anadarko Basin [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	10,700	0	0
VPP 3 Anadarko Basin [Member] | Natural Gas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production | Mcf	1	1.6	2.5	3.3
VPP 3 Anadarko Basin [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0
VPP 2 Texas, Oklahoma and Kansas [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	0.6	1	1.5	2.1
VPP 2 Texas, Oklahoma and Kansas [Member] | Oil [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	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 | Mcf	0.6	1	1.5	2.1
VPP 2 Texas, Oklahoma and Kansas [Member] | Natural Gas Liquids [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]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserve, Production (Energy) | Mcfe	3.1	3.3	6.4	6.8
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 | Mcf	3.1	3.3	6.4	6.8
VPP 1 Kentucky and West Virginia [Member] | Natural Gas Liquids [Member]
VPP Volumes Produced During Period [Line Items]
Proved Developed and Undeveloped Reserves, Production	0	0	0	0

Oil and Natural Gas Property 79

Oil and Natural Gas Property Transactions - VPP Volume Remaining to Be Delivered Table (Details) Mcf in Millions, MMBbls in Millions, MBbls in Millions, Mcfe in Billions	6 Months Ended
	Jun. 30, 2016McfeMBblsMMBblsMcf	May 31, 2011McfeMBblsMcf	Dec. 31, 2007McfeMBblsMcf
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Mcfe	385
Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Mcfe	136.1
Oil [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls	1.7
Oil [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	0.6
Natural Gas [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf	346,000
Natural Gas [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf	124.3
Natural Gas Liquids [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls	4.8
Natural Gas Liquids [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	1.4
VPP 9 Mid-Continent [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Mcfe		177
VPP 9 Mid-Continent [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Term remaining (in months)	56 months
Proved Developed Reserves (Energy) | Mcfe	64.2
VPP 9 Mid-Continent [Member] | Oil [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls		1.7
VPP 9 Mid-Continent [Member] | Oil [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	0.6
VPP 9 Mid-Continent [Member] | Natural Gas [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf		138,000
VPP 9 Mid-Continent [Member] | Natural Gas [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf	52.4
VPP 9 Mid-Continent [Member] | Natural Gas Liquids [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls		4.8
VPP 9 Mid-Continent [Member] | Natural Gas Liquids [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	1.4
VPP 1 Kentucky and West Virginia [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Mcfe			208
VPP 1 Kentucky and West Virginia [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Term remaining (in months)	78 months
Proved Developed Reserves (Energy) | Mcfe	71.9
VPP 1 Kentucky and West Virginia [Member] | Oil [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls			0
VPP 1 Kentucky and West Virginia [Member] | Oil [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	0
VPP 1 Kentucky and West Virginia [Member] | Natural Gas [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf			208,000
VPP 1 Kentucky and West Virginia [Member] | Natural Gas [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Mcf	71.9
VPP 1 Kentucky and West Virginia [Member] | Natural Gas Liquids [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MBbls			0
VPP 1 Kentucky and West Virginia [Member] | Natural Gas Liquids [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | MMBbls	0

Oil and Natural Gas Property 80

Oil and Natural Gas Property Transactions - Narrative (Details)	3 Months Ended	6 Months Ended
	Jun. 30, 2016USD ($)	Jun. 30, 2016USD ($)VPP	Jun. 30, 2015USD ($)
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties	$ 833,000,000	$ 964,000,000	$ 14,000,000
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Consideration Transferred	$ 106,000,000	$ 106,000,000
Number of VPP Transactions | VPP		4
Corporate VPP [Member]
Business Acquisition [Line Items]
Property, Plant and Equipment, Additions		$ 259,000,000
Gain (Loss) on Disposition of Other Assets		$ 0

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Variable Interest Entity [Line Items]
Noncontrolling interests	$ 261		$ 261		$ 259
Net income attributable to noncontrolling interests	0	$ 18	0	$ 37
VIE, Cash and cash equivalents	4	2,051	4	2,051	825	$ 4,108
VIE. proved natural gas and oil properties	64,547		64,547		63,843
VIE. accumulated depreciation, depletion and amortization	(61,757)		(61,757)		(59,365)
Variable Interest Entities, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
VIE, Cash and cash equivalents	1		1		1
VIE. proved natural gas and oil properties	488		488		488
VIE. accumulated depreciation, depletion and amortization	(456)		(456)		$ (428)
Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Variable Interest Entity [Line Items]
Net income attributable to noncontrolling interests	$ 0	$ 1	$ 0	$ 1

Impairments Impairments - Fixed

Impairments Impairments - Fixed Assets and Other Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Property, Plant and Equipment [Line Items]
Impairments of fixed assets and other	$ 6	$ 84	$ 44	$ 88
Compressor [Member]
Property, Plant and Equipment [Line Items]
Impairments of fixed assets and other	0	21	20	21
Buildings and land [Member]
Property, Plant and Equipment [Line Items]
Impairments of fixed assets and other	0	0	7	0
Other [Member]
Property, Plant and Equipment [Line Items]
Impairments of fixed assets and other	$ 6	$ 63	$ 17	$ 67

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Asset Impairment Charges [Abstract]
Impairment of oil and natural gas properties	$ 1,045	$ 5,015	$ 1,898	$ 9,991
Effects of Cash Flow Hedges Considered in Calculation Ceiling Limitation, Amount	$ 160	$ 190	$ 326	$ 385

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Table (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	$ (1)	$ (1)
Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	45	50
Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	(46)	(51)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	(1)	(1)
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	45	50
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	(46)	(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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Total Revenues	$ 1,622	$ 3,521	$ 3,575	$ 6,739
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(1,750)	(5,596)	(2,671)	(10,688)
TOTAL ASSETS	13,487		13,487		$ 17,314
Oil And Gas Exploration And Production [Member]
Segment Reporting Information [Line Items]
Total Revenues	440	1,216	1,433	2,759
Marketing, Gathering And Compression [Member]
Segment Reporting Information [Line Items]
Total Revenues	1,182	2,305	2,142	3,980
Other Segments [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Reportable Subsegments [Member]
Segment Reporting Information [Line Items]
Total Revenues	1,622	3,521	3,575	6,739
Intersubsegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Operating Segments [Member] | Reportable Subsegments [Member] | Oil And Gas Exploration And Production [Member]
Segment Reporting Information [Line Items]
Total Revenues	440	1,187	1,433	2,707
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(1,755)	(5,785)	(2,650)	(11,134)
TOTAL ASSETS	10,842		10,842		14,610
Operating Segments [Member] | Reportable Subsegments [Member] | Oil And Gas Exploration And Production [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
TOTAL ASSETS					11,776
Operating Segments [Member] | Reportable Subsegments [Member] | Marketing, Gathering And Compression [Member]
Segment Reporting Information [Line Items]
Total Revenues	2,030	3,509	3,773	6,417
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(44)	134	(4)	138
TOTAL ASSETS	1,421		1,421		1,524
Operating Segments [Member] | Reportable Subsegments [Member] | Marketing, Gathering And Compression [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
TOTAL ASSETS					1,524
Operating Segments [Member] | Reportable Subsegments [Member] | Other Segments [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(8)	(31)	(17)	(45)
TOTAL ASSETS	1,423		1,423		1,491
Operating Segments [Member] | Reportable Subsegments [Member] | Other Segments [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
TOTAL ASSETS					4,325
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Intersegment Eliminations [Member] | Reportable Subsegments [Member]
Segment Reporting Information [Line Items]
Total Revenues	(848)	(1,175)	(1,631)	(2,385)
Intersegment Eliminations [Member] | Intersubsegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	848	1,175	1,631	2,385
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	57	86	0	353
TOTAL ASSETS	(199)		(199)		(311)
Intersegment Eliminations [Member] | Intersubsegment Eliminations [Member] | Scenario, Previously Reported [Member]
Segment Reporting Information [Line Items]
TOTAL ASSETS					$ (311)
Intersegment Eliminations [Member] | Intersubsegment Eliminations [Member] | Oil And Gas Exploration And Production [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	29	0	52
Intersegment Eliminations [Member] | Intersubsegment Eliminations [Member] | Marketing, Gathering And Compression [Member]
Segment Reporting Information [Line Items]
Total Revenues	848	1,204	1,631	2,437
Intersegment Eliminations [Member] | Intersubsegment Eliminations [Member] | Other Segments [Member]
Segment Reporting Information [Line Items]
Total Revenues	$ 0	$ 0	$ 0	$ 0

Segment Information - Narrative

Segment Information - Narrative (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)Segment	Jun. 30, 2015USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | Segment			2
Total Revenues	$ 1,622	$ 3,521	$ 3,575	$ 6,739
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Marketing, Gathering And Compression [Member]
Segment Reporting Information [Line Items]
Total Revenues	1,182	2,305	2,142	3,980
Intersubsegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	0	0	0	0
Intersubsegment Eliminations [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	848	1,175	1,631	2,385
Intersubsegment Eliminations [Member] | Marketing, Gathering And Compression [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Total Revenues	$ 848	$ 1,204	$ 1,631	$ 2,437