Chesapeake Energy (CHK) 10-K 22 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2017	Feb. 15, 2018	Jun. 30, 2017
Document and Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	FY
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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		909,242,558
Entity Public Float			$ 4.5

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents ($2 and $1 attributable to our VIE)	$ 5	$ 882
Accounts receivable, net	1,322	1,057
Short-term derivative assets	27	0
Other current assets	171	203
Total Current Assets	1,525	2,142
Oil and natural gas properties, at cost based on full cost accounting:
Proved oil and natural gas properties ($488 and $488 attributable to our VIE)	68,858	66,451
Unproved properties	3,484	4,802
Other property and equipment	1,986	2,053
Total Property and Equipment, at Cost	74,328	73,306
Less: accumulated depreciation, depletion and amortization (($461) and ($458) attributable to our VIE)	(63,664)	(62,726)
Property and equipment held for sale, net	16	29
Total Property and Equipment, Net	10,680	10,609
LONG-TERM ASSETS:
Other long-term assets	220	277
TOTAL ASSETS	12,425	13,028
CURRENT LIABILITIES:
Accounts payable	654	672
Current maturities of long-term debt, net	52	503
Accrued interest	137	113
Short-term derivative liabilities	58	562
Other current liabilities ($3 and $3 attributable to our VIE)	1,455	1,798
Total Current Liabilities	2,356	3,648
LONG-TERM LIABILITIES:
Long-term debt, net	9,921	9,938
Long-term derivative liabilities	4	15
Asset retirement obligations, net of current portion	162	247
Other long-term liabilities	354	383
Total Long-Term Liabilities	10,441	10,583
CONTINGENCIES AND COMMITMENTS (Note 4)
Chesapeake Stockholders’ Equity:
Preferred stock, $0.01 par value, 20,000,000 shares authorized: 5,603,458 and 5,839,506 shares outstanding	1,671	1,771
Common stock, $0.01 par value, 2,000,000,000 and 1,500,000,000 shares authorized: 908,732,809 and 896,279,353 shares issued	9	9
Additional paid-in capital	14,437	14,486
Accumulated deficit	(16,525)	(17,474)
Accumulated other comprehensive loss	(57)	(96)
Less: treasury stock, at cost; 2,240,394 and 1,220,504 common shares	(31)	(27)
Total Chesapeake Stockholders’ Equity (Deficit)	(496)	(1,331)
Noncontrolling interests	124	128
Total Equity (Deficit)	(372)	(1,203)
TOTAL LIABILITIES AND EQUITY	$ 12,425	$ 13,028

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Preferred stock, par value (usd per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (shares)	20,000,000	20,000,000
Preferred stock, shares outstanding (shares)	5,603,458	5,839,506
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common Stock, Shares Authorized	2,000,000,000	1,500,000,000
Common stock, shares issued	908,732,809	896,279,353
Treasury stock, common shares	2,240,394	1,220,504
VIE, cash and cash equivalents	$ 5	$ 882
VIE. proved oil and natural gas properties	68,858	66,451
VIE. accumulated depreciation, depletion and amortization	(63,664)	(62,726)
VIE. other current liabilities	1,455	1,798
Variable Interest Entities, Primary Beneficiary [Member]
VIE, cash and cash equivalents	2	1
VIE. proved oil and natural gas properties	488	488
VIE. accumulated depreciation, depletion and amortization	(461)	(458)
VIE. other current liabilities	$ 3	$ 3

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
REVENUES:
Oil, natural gas and NGL	$ 4,985	$ 3,288	$ 5,391
Marketing, gathering and compression	4,511	4,584	7,373
Total Revenues	9,496	7,872	12,764
OPERATING EXPENSES:
Oil, natural gas and NGL production	562	710	1,046
Oil, natural gas and NGL gathering, processing and transportation	1,471	1,855	2,119
Production taxes	89	74	99
Marketing, gathering and compression	4,598	4,778	7,130
General and administrative	262	240	235
Restructuring and other termination costs	0	6	36
Provision for legal contingencies, net	(38)	123	353
Oil, natural gas and NGL depreciation, depletion and amortization	913	1,003	2,099
Depreciation and amortization of other assets	82	104	130
Impairment of oil and natural gas properties	0	2,564	18,238
Impairments of fixed assets and other	421	838	194
Net (gains) losses on sales of fixed assets	(3)	(12)	4
Total Operating Expenses	8,357	12,283	31,683
INCOME (LOSS) FROM OPERATIONS	1,139	(4,411)	(18,919)
OTHER INCOME (EXPENSE):
Interest expense	(426)	(296)	(317)
Losses on investments	0	(8)	(96)
Loss on sale of investment	0	(10)	0
Impairments of investments	0	(119)	(53)
Gains on purchases or exchanges of debt	233	236	279
Other income	9	19	8
Total Other Expense	(184)	(178)	(179)
INCOME (LOSS) BEFORE INCOME TAXES	955	(4,589)	(19,098)
Current income taxes	(9)	(19)	(36)
Deferred income taxes	11	(171)	(4,427)
Total Income Tax Expense (Benefit)	2	(190)	(4,463)
NET INCOME (LOSS)	953	(4,399)	(14,635)
Net (income) loss attributable to noncontrolling interests	(4)	9	68
Other comprehensive income	39	3	44
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	949	(4,390)	(14,567)
Preferred stock dividends	(85)	(97)	(171)
Loss on exchange of preferred stock	(41)	(428)	0
Earnings allocated to participating securities	(10)	0	0
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ 813	$ (4,915)	$ (14,738)
EARNINGS (LOSS) PER COMMON SHARE:
Earnings Per Share, Basic	$ 0.90	$ (6.43)	$ (22.26)
Earnings Per Share, Diluted	0.90	(6.43)	(22.26)
Common Stock, Dividends, Per Share, Declared	$ 0	$ 0	$ 0.0875
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Weighted Average Number of Shares Outstanding, Basic	906	764	662
Weighted Average Number of Shares Outstanding, Diluted	906	764	662

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
NET INCOME (LOSS)	$ 953	$ (4,399)	$ (14,635)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF INCOME TAX:
Unrealized gains (losses) on derivative instruments, net of income tax expense (benefit) of $0, ($14) and $12	5	(13)	20
Reclassification of losses on settled derivative instruments, net of income tax expense of $0, $18 and $15	34	16	24
Other Comprehensive Income	39	3	44
COMPREHENSIVE INCOME (LOSS)	992	(4,396)	(14,591)
Net income attributable to noncontrolling interests	4	(9)	(68)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	$ 988	$ (4,387)	$ (14,523)

CONSOLIDATED STATEMENTS OF COM6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income tax expense (benefit) of $0,$0, $0 and ($1) on unrealized gains (losses) on derivative instruments	$ 0	$ (14)	$ 12
Income tax expense (benefit) of $0, $0, $0 and $3 on reclassification of losses on settled derivative instruments	$ 0	$ 18	$ 15

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES:
NET INCOME (LOSS)	$ 953	$ (4,399)	$ (14,635)
ADJUSTMENTS TO RECONCILE NET INCOME (LOSS) TO CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES:
Depreciation, depletion and amortization	995	1,107	2,229
Deferred income tax expense (benefit)	11	(171)	(4,427)
Derivative (gains) losses, net	(409)	739	(932)
Cash receipts (payments) on derivative settlements, net	(18)	448	1,123
Stock-based compensation	49	52	78
Impairment of oil and natural gas properties	0	2,564	18,238
Net (gains) losses on sales of fixed assets	(3)	(12)	4
Renegotiation of natural gas gathering contracts	0	(115)	0
Impairments of fixed assets and other	4	467	175
Losses on investments	0	8	96
Loss on sale of investment	0	10	0
Impairments of investments	0	119	53
Gains on purchases or exchanges of debt	(235)	(236)	(304)
Restructuring and other termination costs	0	3	(14)
Provision for legal contingencies, net	(42)	87	340
Other	(89)	(114)	244
(Increase) decrease in accounts receivable and other assets	(163)	(4)	1,186
Decrease in accounts payable, accrued liabilities and other	(308)	(757)	(2,220)
Net Cash Provided By (Used In) Operating Activities	745	(204)	1,234
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(2,186)	(1,295)	(3,095)
Acquisitions of proved and unproved properties	(285)	(788)	(533)
Proceeds from divestitures of proved and unproved properties	1,249	1,406	189
Additions to other property and equipment	(21)	(37)	(143)
Proceeds from sales of other property and equipment	55	131	89
Cash paid for title defects	0	(69)	0
Additions to investments	0	0	(1)
Decrease in restricted cash	0	0	52
Other	0	(8)	(9)
Net Cash Used In Investing Activities	(1,188)	(660)	(3,451)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	7,771	5,146	0
Payments on revolving credit facility borrowings	(6,990)	(5,146)	0
Proceeds from issuance of senior notes, net	1,585	2,210	0
Proceeds from issuance of term loan, net	0	1,476	0
Cash paid to purchase debt	(2,592)	(2,734)	(508)
Cash paid for common stock dividends	0	0	(118)
Cash paid for preferred stock dividends	(183)	0	(171)
Cash paid to repurchase noncontrolling interest of CHK C-T	0	0	(143)
Distributions to noncontrolling interest owners	(8)	(10)	(85)
Other	(17)	(21)	(41)
Net Cash Provided By (Used In) Financing Activities	(434)	921	(1,066)
Net increase (decrease) in cash and cash equivalents	(877)	57	(3,283)
Cash and cash equivalents, beginning of period	882	825	4,108
Cash and cash equivalents, end of period	5	882	825
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid, net of capitalized interest	492	344	235
Income taxes paid, net of refunds received	(16)	(27)	44
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Divestiture of proved and unproved CHK-C-T properties	0	0	1,024
Debt exchanged for common stock	0	471	0
Repurchase of noncontrolling interest, Non-Cash Investing and Financing Activities	0	0	872
Change In Accrued Drilling And Completion Costs [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	14	(23)	(148)
Change In Accrued Acquisitions Of Proved And Unproved Properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	9	(13)	55
Change In Divested Proved And Unproved Properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in accrued drilling and completion costs	$ (57)	$ 52	$ 35

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	Preferred Stock [Member]	Preferred Stock [Member]Preferred Stock, Exchanged for Shares of Common Stock [Member]	Common Stock [Member]	Common Stock [Member]Conversion of preferred stock into common stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]	Additional Paid-in Capital [Member]Senior Notes Exchanged for Shares of Common Stock [Member]	Additional Paid-in Capital [Member]Preferred Stock, Exchanged for Shares of Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Stock - Common [Member]	Parent [Member]	Noncontrolling Interest [Member]	Noncontrolling Interest, Chesapeake Cleveland Tonkawa Limited Liability Company [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]
Stock repurchased during period, value			$ 0
Stock issued during period, value, conversion of convertible securities				0	$ 0
Stock-based compensation						71
Convertible notes exchanged, value						0	$ 0	$ 0
Exchange of preferred stock for shares of common stock									$ 0
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt						0
Equity component of contingent convertible notes repurchased, net of tax						0
Dividends on preferred stock						(128)
Dividends on common stock						(59)
Issuance costs						0
Increase (decrease) in tax benefit from stock-based compensation						(12)
Net income (loss) attributable to Chesapeake	$ (14,567)									(14,567)
Hedging activity											44
Purchase of 1,206,419, 37,871 and 54,493 shares for company benefit plans												(1)
Release of 186,529, 255,091 and 231,081 shares from company benefit plans												5
Chesapeake stockholders’ equity, end of period at Dec. 31, 2015		3,062		7		12,403				(13,084)	(99)	(33)	$ 2,256
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	(68)													(68)	$ 50
Distributions to noncontrolling interest owners														(78)
Repurchase of noncontrolling interest of CHK C-T															(1,015)
Stockholders' equity attributable to noncontrolling interest, end of period at Dec. 31, 2015														141
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	2,397
Stock repurchased during period, value			(1,291)
Stock issued during period, value, conversion of convertible securities				1	1
Stock-based compensation						64
Convertible notes exchanged, value						(165)	241	229
Exchange of preferred stock for shares of common stock									1,290
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt	445					445
Equity component of contingent convertible notes repurchased, net of tax	(26)					(16)
Dividends on preferred stock						0
Dividends on common stock						0
Issuance costs						(5)
Increase (decrease) in tax benefit from stock-based compensation						0
Net income (loss) attributable to Chesapeake	(4,390)									(4,390)
Hedging activity											3
Purchase of 1,206,419, 37,871 and 54,493 shares for company benefit plans												0
Release of 186,529, 255,091 and 231,081 shares from company benefit plans												6
Chesapeake stockholders’ equity, end of period at Dec. 31, 2016	(1,331)	1,771		9		14,486				(17,474)	(96)	(27)	(1,331)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	(9)													(9)
Distributions to noncontrolling interest owners														(4)
Repurchase of noncontrolling interest of CHK C-T															0
Stockholders' equity attributable to noncontrolling interest, end of period at Dec. 31, 2016	128													128
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	(1,203)
Stock repurchased during period, value			$ (100)
Stock issued during period, value, conversion of convertible securities				0	$ 0
Stock-based compensation						54
Convertible notes exchanged, value						0	$ 0	$ 0
Exchange of preferred stock for shares of common stock									$ 100
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt						0
Equity component of contingent convertible notes repurchased, net of tax						(20)
Dividends on preferred stock						(183)
Dividends on common stock						0
Issuance costs						0
Increase (decrease) in tax benefit from stock-based compensation						0
Net income (loss) attributable to Chesapeake	949									949
Hedging activity											39
Purchase of 1,206,419, 37,871 and 54,493 shares for company benefit plans												(7)
Release of 186,529, 255,091 and 231,081 shares from company benefit plans												3
Chesapeake stockholders’ equity, end of period at Dec. 31, 2017	(496)	$ 1,671		$ 9		$ 14,437				$ (16,525)	$ (57)	$ (31)	$ (496)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	4													4
Distributions to noncontrolling interest owners														(8)
Repurchase of noncontrolling interest of CHK C-T															$ 0
Stockholders' equity attributable to noncontrolling interest, end of period at Dec. 31, 2017	124													$ 124
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	$ (372)

CONSOLIDATED STATEMENTS OF STO9

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Treasury Stock - Common [Member]
Purchase of shares for company benefit plans, shares	1,206,419	37,871	54,493
Release of shares from company benefit plans, shares	186,529	255,091	231,081
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Preferred Stock [Member]
Conversion of Stock, Shares Converted	236,048	1,412,009	0
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	9,965,835	1,021,506	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	0	55,427,782	0
Senior Notes Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	53,923,925	0

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Organization, Consolidation, Basis of Presentation, Business Description and Accounting Policies Disclosure	Basis of Presentation and Summary of Significant Accounting Policies Description of Company Chesapeake Energy Corporation ("Chesapeake", “we,” “our”, “us” or the "Company") is an oil and natural gas exploration and production company engaged in the acquisition, exploration and development of properties for the production of oil, natural gas and natural gas liquids (NGL) from underground reservoirs. Our operations are located onshore in the United States. Basis of Presentation The accompanying consolidated financial statements of Chesapeake were prepared in accordance with 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. Accounting Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the related disclosures in the financial statements. Management evaluates its estimates and related assumptions regularly, including those related to the impairment of oil and natural gas properties, oil and natural gas reserves, derivatives, income taxes, collectibility of accounts receivable, impairment of other property and equipment, environmental remediation costs, asset retirement obligations, litigation and regulatory proceedings and fair values. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ significantly from these estimates. Consolidation We consolidate entities in which we have a controlling financial interest. We consolidate subsidiaries in which we hold, directly or indirectly, more than 50% of the voting rights and variable interest entities (VIEs) in which we are the primary beneficiary. We use the equity method of accounting to record our net interests where we have the ability to exercise significant influence through our investment. Under the equity method, our share of net income (loss) is included in our consolidated statements of operations according to our equity ownership or according to the terms of the applicable governing instrument. Undivided interests in oil and natural gas properties are consolidated on a proportionate basis. Segments Operating segments are defined as components of an enterprise that engage in activities from which it may earn revenues and incur expenses for which separate operational financial information is available and is regularly evaluated by the chief operating decision maker for the purpose of allocating an enterprise’s resources and assessing its operating performance. We have historically presented two reportable operating segments: (i) exploration and production and (ii) marketing, gathering and compression. In the fourth quarter of 2017, we completed the realignment of our marketing, gathering and compression operations to serve as an ancillary service integral to our exploration and production activities. Following this realignment, we have a single, company-wide management team that administers all activities as a whole rather than through discrete operating units, with an emphasis on allocating capital focused on the expansion of our exploration and production assets. As a result, we have concluded that we have only one reportable operating segment, which is exploration and production. Prior year financial information for our previous marketing, gathering and compression reportable operating segment has been eliminated. Noncontrolling Interests Noncontrolling interests represent third-party equity ownership in certain of our consolidated subsidiaries and are presented as a component of equity. See Note 8 for further discussion of noncontrolling interests. Variable Interest Entities VIEs are entities that, by design, either (i) lack sufficient equity to permit the entity to finance its activities independently, or (ii) have equity holders that do not have the power to direct the activities of the entity that most significantly impact its economic performance, the obligation to absorb the entity’s losses, or the right to receive the entity’s residual returns. We consolidate a VIE when we are the primary beneficiary, which is the party that has both (i) the power to direct the activities that most significantly impact the VIE’s economic performance and (ii) through its interests in the VIE, the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether we own a variable interest in a VIE, we perform a qualitative analysis of the entity’s design, organizational structure, primary decision makers and relevant agreements. We continually monitor our consolidated VIE to determine if any events have occurred that could cause the primary beneficiary to change. See Note 8 for further discussion of our VIE. Cash and Cash Equivalents For purposes of the consolidated financial statements, we consider investments in all highly liquid instruments with original maturities of three months or less at the date of purchase to be cash equivalents. Accounts Receivable Our accounts receivable are primarily from purchasers of oil, natural gas and NGL and from exploration and production companies that own interests in properties we operate. This industry concentration could affect our overall exposure to credit risk, either positively or negatively, because our purchasers and joint working interest owners may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated. We utilize an allowance method in accounting for bad debt based on historical trends in addition to specifically identifying receivables that we believe may be uncollectible. Accounts receivable as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) Oil, natural gas and NGL sales $ 959 $ 840 Joint interest 209 156 Other 184 93 Allowance for doubtful accounts (30 ) (32 ) Total accounts receivable, net $ 1,322 $ 1,057 Oil and Natural Gas Properties We follow the full cost method of accounting under which all costs associated with oil and natural gas property acquisition, exploration and development activities are capitalized. We capitalize internal costs that can be directly identified with these activities and do not capitalize any costs related to production, general corporate overhead or similar activities (see Supplementary Information – Supplemental Disclosures About Oil, Natural Gas and NGL Producing Activities ). Capitalized costs are amortized on a composite unit-of-production method based on proved oil and natural gas reserves. Estimates of our proved reserves as of December 31, 2017 were prepared by an independent engineering firm and our internal staff. In addition, our internal engineers review and update our reserves on a quarterly basis. Proceeds from the sale of oil and natural gas properties are accounted for as reductions of capitalized costs unless these sales involve a significant change in proved reserves and significantly alter the relationship between costs and proved reserves, in which case a gain or loss is recognized. The costs of unproved properties are excluded from amortization until the properties are evaluated. We review all of our unproved properties quarterly to determine whether or not and to what extent proved reserves have been assigned to the properties and otherwise if impairment has occurred. Unproved properties are grouped by major prospect area in circumstances where individual property costs are not significant. In addition, we analyze our unproved leasehold and transfer to proved properties that portion of our leasehold that expired in the quarter, or leasehold that is no longer part of our development strategy and will be abandoned. The table below sets forth the cost of unproved properties excluded from the amortization base as of December 31, 2017 and the year in which the associated costs were incurred: Year of Acquisition 2017 2016 2015 Prior Total ($ in millions) Leasehold cost $ 70 $ 89 $ 87 $ 2,368 $ 2,614 Exploration cost 50 9 33 11 103 Capitalized interest 154 116 120 377 767 Total $ 274 $ 214 $ 240 $ 2,756 $ 3,484 We also review, on a quarterly basis, the carrying value of our oil and natural gas properties under the full cost accounting rules of the SEC. This quarterly review is referred to as a ceiling test. 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 oil and natural gas derivatives designated as cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. The ceiling test calculation uses costs as of the end of the applicable quarterly period and the unweighted arithmetic average of oil, natural gas and NGL prices on the first day of each month within the 12-month period prior to the ending date of the quarterly period. These prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives designated as cash flow hedges. As of December 31, 2017, none of our open derivative instruments were designated as cash flow hedges. Our oil and natural gas hedging activities are discussed in Note 11. Two primary factors impacting the ceiling test are reserve levels and oil, natural gas and NGL prices, and their associated impact on the present value of estimated future net revenues. Revisions to estimates of oil and natural gas reserves and/or an increase or decrease in prices can have a material impact on the present value of our estimated future net revenues. Any excess of the net book value over the ceiling is written off as an impairment expense. We account for seismic costs as part of our oil and natural gas properties. Exploration costs may be incurred both before acquiring the related property and after acquiring the property. Further, exploration costs include, among other things, geological and geophysical studies and salaries and other expenses of geologists, geophysical crews and others conducting those studies. These costs are capitalized as incurred. We review our unproved properties and associated seismic costs quarterly to determine whether impairment has occurred. To the extent that seismic costs cannot be directly associated with specific unproved properties, they are included in the amortization base as incurred. Estimates of oil and natural gas reserves and their values, future production rates and future costs and expenses are the most significant of our estimates. The accuracy of any reserve estimate is a function of the quality of data available and of engineering and geological interpretation and judgment. In addition, estimates of reserves may be revised based on actual production, results of subsequent exploration and development activities, recent commodity prices, operating costs and other factors. These revisions could materially affect our financial statements. The volatility of commodity prices results in increased uncertainty inherent in these estimates and assumptions. Changes in oil, natural gas or NGL prices could result in significant changes to the quarterly ceiling test calculation. Other Property and Equipment Other property and equipment consists primarily of natural gas compressors, buildings and improvements, land, vehicles, computers and office equipment. Major renewals and betterments are capitalized while the costs of repairs and maintenance are charged to expense as incurred. The costs of assets retired or otherwise disposed of and the applicable accumulated depreciation are removed from the accounts, and the resulting gain or loss is reflected in operating expenses. Other property and equipment costs, excluding land, are depreciated on a straight-line basis. Realization of the carrying value of other property and equipment is reviewed for possible impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Assets are determined to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset, including any disposal value, is less than the carrying amount of the asset. If any asset is determined to be impaired, the loss is measured as the amount by which the carrying amount of the asset exceeds its fair value. An estimate of fair value is based on the best information available, including prices for similar assets and discounted cash flow. Capitalized Interest Interest from external borrowings is capitalized on significant investments in unproved properties and major development projects until the asset is ready for service using the weighted average borrowing rate of outstanding borrowings. Capitalized interest is determined by multiplying our weighted-average borrowing cost on debt by the average amount of qualifying costs incurred. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying asset. Accounts Payable Included in accounts payable as of December 31, 2017 and 2016 are liabilities of approximately $92 million and $77 million , respectively, representing the amount by which checks issued, but not yet presented to our banks for collection, exceeded balances in applicable bank accounts. Debt Issuance Costs Included in other long-term assets are costs associated with the issuance and amendments of our revolving credit facility. The remaining unamortized issuance costs as of December 31, 2017 and 2016, totaled $22 million and $32 million , respectively, and are being amortized over the life of credit facility using the straight-line method. Included in debt are costs associated with the issuance of our senior notes and term loan. The remaining unamortized issuance costs as of December 31, 2017 and 2016, totaled $63 million and $64 million , respectively, and are being amortized over the life of the senior notes using the effective interest method. Litigation Contingencies We are subject to litigation and regulatory proceedings, claims and liabilities that arise in the ordinary course of business. We accrue losses associated with litigation and regulatory claims when such losses are probable and reasonably estimable. If we determine that a loss is probable and cannot estimate a specific amount for that loss but can estimate a range of loss, our best estimate within the range is accrued. Estimates are adjusted as additional information becomes available or circumstances change. Legal defense costs associated with loss contingencies are expensed in the period incurred. Environmental Remediation Costs We record environmental reserves for estimated remediation costs related to existing conditions from past operations when the responsibility to remediate is probable and the costs can be reasonably estimated. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Asset Retirement Obligations We recognize liabilities for obligations associated with the retirement of tangible long-lived assets that result from the acquisition, construction and development of the assets. We recognize the fair value of a liability for a retirement obligation in the period in which the liability is incurred. For oil and natural gas properties, this is the period in which an oil or natural gas well is acquired or drilled. The liability is then accreted each period until the liability is settled or the well is sold, at which time the liability is removed. The related asset retirement cost is capitalized as part of the carrying amount of our oil and natural gas properties. See Note 17 for further discussion of asset retirement obligations. Revenue Recognition Oil, Natural Gas and NGL Sales . Revenue from the sale of oil, natural gas and NGL is recognized when title passes, net of royalties due to third parties. Natural Gas Imbalances . We follow the sales method of accounting for our natural gas revenue whereby we recognize sales revenue on all natural gas sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. An asset or a liability is recognized to the extent that we have an imbalance in excess of the remaining estimated natural gas reserves on the underlying properties. The natural gas imbalance net liability position as of December 31, 2017 and 2016, was $5 million and $9 million , respectively. Marketing, Gathering and Compression Sales. In connection with the marketing of our production, we take title to the oil, natural gas and NGL we purchase from other interest owners at defined delivery points and deliver the product to third parties, at which time revenues are recorded. In addition, we periodically enter into a variety of oil, natural gas and NGL purchase and sale contracts with third parties for various commercial purposes, primarily for credit risk mitigation and to help meet certain of our pipeline delivery commitments. In circumstances where we act as a principal rather than an agent, our results of operations related to oil, natural gas and NGL marketing activities are presented on a gross basis. Gathering and compression revenues consist of fees billed to other interest owners in operated wells or third-party producers for the gathering, treating and compression of natural gas. Revenues are recognized when the service is performed and are based upon non-regulated rates and the related gathering, treating and compression volumes. All significant intercompany accounts and transactions have been eliminated. Fair Value Measurements Certain financial instruments are reported at fair value on our consolidated balance sheets. Under fair value measurement accounting guidance, fair value is defined as the amount that would be received from the sale of an asset or paid for the transfer of a liability in an orderly transaction between market participants (i.e., an exit price). To estimate an exit price, a three-level hierarchy is used. The fair value hierarchy prioritizes the inputs, which refer broadly to assumptions market participants would use in pricing an asset or a liability, into three levels. Level 1 inputs are unadjusted quoted prices in active markets for identical assets and liabilities and have the highest priority. Level 2 inputs are inputs other than quoted prices within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability and have the lowest priority. The valuation techniques that may be used to measure fair value include a market approach, an income approach and a cost approach. A market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. An income approach uses valuation techniques to convert future amounts to a single present amount based on current market expectations, including present value techniques, option-pricing models and the excess earnings method. The cost approach is based on the amount that currently would be required to replace the service capacity of an asset (replacement cost). The carrying values of financial instruments comprising cash and cash equivalents, accounts payable and accounts receivable approximate fair values due to the short-term maturities of these instruments. Derivatives Derivative instruments are recorded at fair value, and changes in fair value are recognized currently in earnings unless specific hedge accounting criteria are followed. For qualifying commodity derivative instruments designated as cash flow hedges, changes in fair value, to the extent the hedge is effective, are recognized in other comprehensive income until the hedged item is recognized in earnings. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings. Locked-in gains and losses of settled cash flow hedges are recorded in accumulated other comprehensive income and are transferred to earnings in the month of production. Changes in the fair value of interest rate derivative instruments designated as fair value hedges are recorded on the consolidated balance sheets as assets or liabilities, and the debt's carrying value amount is adjusted by the change in the fair value of the debt subsequent to the initiation of the derivative. Differences between the changes in the fair values of the hedged item and the derivative instrument, if any, represent hedge ineffectiveness and are recognized currently in earnings. Locked-in gains and losses related to settled fair value hedges are amortized as an adjustment to interest expense over the remaining term of the related debt instrument. We have elected not to designate any of our qualifying commodity and interest rate derivatives as cash flow or fair value hedges. Therefore, changes in fair value of these derivatives that occur prior to their maturity (i.e., temporary fluctuations in value) are recognized in our consolidated statements of operations within oil, natural gas and NGL sales and interest expense, respectively. Derivative instruments reflected as current in the consolidated balance sheets represent the estimated fair value of derivatives scheduled to settle over the next twelve months based on market prices/rates as of the respective balance sheet dates. Cash settlements of our derivative instruments are generally classified as operating cash flows unless the derivatives are deemed to contain, for accounting purposes, a significant financing element at contract inception, in which case these cash settlements are classified as financing cash flows in the accompanying consolidated statement of cash flows. All of our derivative instruments are subject to master netting arrangements by contract type which provide for the offsetting of asset and liability positions within each contract type, as well as related cash collateral if applicable, by counterparty. Therefore, we net the value of our derivative instruments by contract type with the same counterparty in the accompanying consolidated balance sheets. We have established the fair value of our derivative instruments using established index prices, volatility curves and discount factors. These estimates are compared to our counterparty values for reasonableness. The values we report in our financial statements are as of a point in time and subsequently change as these estimates are revised to reflect actual results, changes in market conditions and other factors. Derivative transactions are subject to the risk that counterparties will be unable to meet their obligations. This non-performance risk is considered in the valuation of our derivative instruments, but to date has not had a material impact on the values of our derivatives. See Note 11 for further discussion of our derivative instruments. Share-Based Compensation Our share-based compensation program consists of restricted stock, stock options and performance share units granted to employees and restricted stock granted to non-employee directors under our Long Term Incentive Plan. We recognize the cost of employee services received in exchange for restricted stock and stock options based on the fair value of the equity instruments as of the grant date. For employees, this value is amortized over the vesting period, which is generally three or four years from the grant date. For directors, although restricted stock grants vest over three years , this value is recognized immediately as there is a non-substantive service condition for vesting. Because performance share units can only be settled in cash, they are classified as a liability in our consolidated financial statements and are measured at fair value as of the grant date and re-measured at fair value at the end of each reporting period. These fair value adjustments are recognized as general and administrative expense in the consolidated statements of operations. To the extent compensation expense relates to employees directly involved in the acquisition of oil and natural gas leasehold and exploration and development activities, these amounts are capitalized to oil and natural gas properties. Amounts not capitalized to oil and natural gas properties are recognized as general and administrative expenses, oil, natural gas and NGL production expenses, or marketing, gathering and compression expenses, based on the employees involved in those activities. See Note 9 for further discussion of share-based compensation. Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) that supersedes virtually all existing revenue recognition guidance. The new standard includes a five-step revenue recognition model that requires the recognition of revenue to depict the transfer of promised goods to customers in an amount reflecting the consideration we expect to be entitled in exchange for those goods. The standard is required to be adopted using either the full retrospective approach or the modified retrospective approach. We will adopt this new standard in the first quarter of 2018 using the modified retrospective approach. Among other things, the standard requires enhanced disclosures about revenue and provides guidance for transactions that were not previously addressed comprehensively. As of December 31, 2017, we have completed our evaluation of the new standard and have concluded that the cumulative effect of adoption will not have a material impact on our consolidated financial statements. The adoption will result in a change in the gross versus net presentation of certain revenue transactions in our consolidated statements of operations, but any such presentation changes would not have an impact on income (loss) from operations, earnings per share or cash flows. In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10) : Recognition and Measurement of Financial Assets and Financial Liabilities. ASU 2016-01 will require equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) to be measured at fair value with changes in fair value recognized in net income. In addition, ASU 2016-01 changes certain disclosure requirements and other aspects of GAAP. We will adopt ASU 2016-01 on January 1, 2018. As of December 31, 2017, we have completed our evaluation of the new standard and have concluded that the effect on our financial statements is not material, but may be material in the future if we were to sell a portion of our equity method investments such that we no longer had the ability to exercise significant influence over the operating and financial activities of the investee. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) which updated lease accounting guidance requiring lessees to recognize most leases, including operating leases, on the balance sheet as a right of use asset and lease liability. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2018 and will be adopted using a modified retrospective transition method, which requires applying the new standard to leases that exist or are entered into after the beginning of the earliest period in the financial statements. Early adoption is permitted, but we do not plan to early adopt . The standard will not apply to our leases of mineral rights. We are continuing to evaluate the impact of this standard on our consolidated financial statements and related disclosures. In August 2017, the FASB issued ASU 2017-12 , Derivatives and Hedging (Topic 815) which makes significant changes to the current hedge accounting guidance. The new standard eliminates the requirement to separately measure and report hedge ineffectiveness and generally requires the entire change in the fair value of a hedging instrument to be presented in the same income statement line as the hedged item. The new standard also eases certain documentation and assessment requirements and modifies the accounting for components excluded from the assessment of hedge effectiveness. The new standard update is effective for annual and interim periods beginning after December 15, 2018, including interim periods within those annual periods. Early adoption is permitted, but we do not plan to early adopt. We are currently evaluating the impact of this standard on our consolidated financial statements and related disclosures. Reclassifications Certain reclassifications have been made to the consolidated financial statements for 2016 and 2015 to conform to the presentation used for the 2017 consolidated financial statements.

Earnings Per Share (Notes)

Earnings Per Share (Notes)	12 Months Ended
	Dec. 31, 2017
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Earnings Per Share Disclosure	Earnings Per Share Basic earnings per share (EPS) is calculated using the weighted average number of common shares outstanding during the period and includes the effect of any participating securities as appropriate. Participating securities consist of unvested restricted stock issued to our employees and non-employee directors that provide dividend rights. Diluted EPS is calculated assuming the issuance of common shares for all potentially dilutive securities, provided the effect is not antidilutive. For all periods presented, our contingent convertible senior notes did not have a dilutive effect and therefore were excluded from the calculation of diluted EPS. See Note 3 for further discussion of our convertible senior notes and contingent convertible senior notes. Shares of common stock for the following dilutive securities were excluded from the calculation of diluted EPS as the effect was antidilutive. Years Ended December 31, 2017 2016 2015 (in millions) Common stock equivalent of our preferred stock outstanding 60 63 113 Common stock equivalent of our convertible senior notes outstanding 146 146 — Common stock equivalent of our preferred stock outstanding prior to exchange 1 37 — Participating securities 1 1 1

Debt (Notes)

Debt (Notes)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Debt Disclosure	Debt Our long-term debt consisted of the following as of December 31, 2017 and 2016: December 31, 2017 December 31, 2016 Principal Amount Carrying Principal Carrying ($ in millions) 6.25% euro-denominated senior notes due 2017 $ — $ — $ 258 $ 258 6.5% senior notes due 2017 — — 134 134 7.25% senior notes due 2018 44 44 64 64 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 437 437 780 780 6.875% senior notes due 2020 227 227 279 278 6.125% senior notes due 2021 548 548 550 550 5.375% senior notes due 2021 267 267 270 270 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 (a) 1,416 1,895 2,419 3,409 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,300 1,290 1,000 985 5.5% convertible senior notes due 2026 (b)(c)(d) 1,250 837 1,250 811 8.00% senior notes due 2027 1,300 1,298 — — 2.75% contingent convertible senior notes due 2035 (d) — — 2 2 2.5% contingent convertible senior notes due 2037 (d) — — 114 112 2.25% contingent convertible senior notes due 2038 (b)(d) 9 8 200 180 Term loan due 2021 1,233 1,233 1,500 1,500 Revolving credit facility 781 781 — — Debt issuance costs — (63 ) — (64 ) Interest rate derivatives — 2 — 3 Total debt, net 9,981 9,973 9,989 10,441 Less current maturities of long-term debt, net (e) (53 ) (52 ) (506 ) (503 ) Total long-term debt, net $ 9,928 $ 9,921 $ 9,483 $ 9,938 ___________________________________________ (a) The carrying amounts as of December 31, 2017 and 2016, include premium amounts of $479 million and $990 million , respectively, associated with a troubled debt restructuring. The premium is being amortized based on the effective yield method. (b) We are required to account for the liability and equity components of our convertible debt instruments separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rates for our 2.25% Contingent Convertible Senior Notes due 2038 and our 5.5% Convertible Senior Notes due 2026 are 8.0% and 11.5% , respectively. (c) The conversion and redemption provisions of our convertible senior notes are as follows: Optional Conversion by Holders . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. The notes may be converted into cash, our common stock, or a combination of cash and common stock, at our election. One triggering circumstance is when the price of our common stock exceeds a threshold amount during a specified period in a fiscal quarter. Convertibility based on common stock price is measured quarterly. During the fourth quarter of 2017, the price of our common stock was below the threshold level and, as a result, the holders do not have the option to convert their notes in the first quarter of 2018 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 year ended December 31, 2017. Upon conversion of a convertible senior note, the holder will receive cash, common stock or a combination of cash and common stock, at our election, according to the conversion rate specified in the indenture. The common stock price conversion threshold amount for the convertible senior notes is 130% of the conversion price of $8.568 . Optional Redemption by the Company . We may redeem the convertible senior notes for cash on or after September 15, 2019 , if the price of our common stock exceeds 130% of the conversion price during a specified period at a redemption price of 100% of the principal amount of the notes. Holders’ Demand Repurchase Rights. The holders of our convertible senior notes may require us to repurchase, in cash, all or a portion of their notes at 100% of the principal amount of the notes upon certain fundamental changes. (d) The carrying amounts as of December 31, 2017 and 2016, are reflected net of discounts of $414 million and $461 million , respectively, associated with the equity component of our convertible and contingent convertible senior notes. This amount is being amortized based on the effective yield method through the first demand repurchase date as applicable. (e) As of December 31, 2017, current maturities of long-term debt, net includes our 7.25% Senior Notes due December 2018 and our 2.25% Contingent Convertible Notes due 2038 Notes. Debt maturities for the next five years and thereafter are as follows: Principal Amount of Debt Securities ($ in millions) 2018 $ 53 2019 1,161 2020 664 2021 2,048 2022 1,867 Thereafter 4,188 Total $ 9,981 Debt Issuances and Retirements - 2017 We issued through two private placements $1.300 billion aggregate principal amount of unsecured 8.00% Senior Notes due 2027 for net proceeds of approximately $1.285 billion . The first private placement was issued at par and the second private placement was issued at 99.75% of par. Some or all of the notes may be redeemed at any time prior to June 15, 2022, subject to a make-whole premium. We also may redeem some or all of the notes at any time on or after June 15, 2022, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes . In addition, subject to certain conditions, we may redeem up to 35% of the aggregate principal amount of the notes at any time prior to June 15, 2020 , at a price equal to 108% of the principal amount of the notes to be redeemed using the net proceeds of certain equity offerings. We also issued in a private placement $300 million aggregate principal amount of additional 8.00% Senior Notes due 2025 (New 2025 Notes) at 101.25% of par for net proceeds of $301 million . The New 2025 Notes are an additional issuance of our outstanding 8.00% Senior Notes due 2025, which we issued in 2016 in an original aggregate principal amount of $1.0 billion at 98.52% of par. The New 2025 Notes issued and the previously issued senior notes due 2025 will be treated as a single class of notes under the indenture. We retired $2.389 billion principal amount of our outstanding senior notes, senior secured second lien notes, contingent convertible notes and term loan through purchases in the open market, tender offers or repayment upon maturity for $2.592 billion using proceeds from the issuances described above. For the open market repurchases and tender offers, we recorded an net aggregate gain of approximately $233 million , including $374 million of premium associated with our 8.00% Senior Secured Second Lien Notes due 2022. Debt Issuances and Retirements - 2016 During 2016, we issued in a private placement $1.0 billion principal amount of unsecured 8.00% Senior Notes due 2025 at a discount for net proceeds of approximately $975 million . Some or all of the notes may be redeemed at any time prior to January 15, 2020, subject to a make-whole premium. In addition, we may redeem some or all of the notes at any time on or after January 15, 2020, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes. In addition, subject to certain conditions, we may redeem up to 35% of the aggregate principal amount of the notes at any time prior to January 15, 2020 , at a price equal to 108% of the principal amount of the notes to be redeemed using the net proceeds of certain equity offerings. During 2016, we issued in a private placement $1.25 billion principal amount of unsecured 5.5% Convertible Senior Notes due 2026 at par for net proceeds of approximately $1.235 billion . The notes are convertible, under certain specified circumstances, into cash, common stock, or a combination of cash and common stock, at our election. We accounted for the liability and equity components separately and reflected interest expense at the interest rate of similar nonconvertible debt at the time of issuance. The allocation to the equity component of the convertible notes was $445 million ( $165 million tax expense). Additionally, debt issuance costs were allocated in proportion to the liability and equity components and accounted for as debt issuance costs and equity issuance costs, respectively. The accretion of the resulting discount on the debt is recognized through the convertible note’s maturity date as a component of interest expense, thereby increasing the amount of interest expense required to be recognized with respect to such instruments. We retired $2.884 billion principal amount of our outstanding senior notes and contingent convertible senior notes through purchases in the open market, tender offers or repayment upon maturity for $2.734 billion . Additionally, we privately negotiated an exchange of approximately $577 million principal amount of our outstanding senior notes and contingent convertible senior notes for 109,351,707 common shares. We recorded an aggregate net gain of approximately $236 million associated with the tender offers, debt repurchases and exchanges discussed above, which was net of $26 million ( $10 million tax benefit) associated with the equity component of the retired contingent convertible senior notes. Senior Secured Second Lien Notes Our second lien notes are secured second lien obligations and are effectively junior to our current and future secured first lien indebtedness, including indebtedness incurred under our revolving credit facility and our term loan facility, to the extent of the value of the collateral securing such indebtedness, effectively senior to all of our existing and future unsecured indebtedness, including our outstanding senior notes, to the extent of the value of the collateral, and senior to any future subordinated indebtedness that we may incur. We have the option to redeem the second lien notes, in whole or in part, at specified make-whole or redemption prices. Our second lien notes are governed by an indenture containing covenants that may limit our ability and our subsidiaries’ ability to create liens securing certain indebtedness, enter into certain sale-leaseback transactions, consolidate, merge or transfer assets and dispose of certain collateral and use proceeds from dispositions of certain collateral. As a holding company, Chesapeake owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under the second lien notes are fully and unconditionally guaranteed, jointly and severally, by certain of our direct and indirect wholly owned subsidiaries. Senior Notes, Contingent Convertible Senior Notes and Convertible Senior Notes Our senior notes and our contingent convertible senior notes are unsecured senior obligations of Chesapeake and rank equally in right of payment with all of our other existing and future senior unsecured indebtedness and rank senior in right of payment to all of our future subordinated indebtedness. Our obligations under the senior notes and the contingent convertible senior notes are jointly and severally, fully and unconditionally guaranteed by certain of our direct and indirect wholly owned subsidiaries. See Note 19 for consolidating financial information regarding our guarantor and non-guarantor subsidiaries. We may redeem the senior notes, other than the convertible senior notes, at any time at specified make-whole or redemption prices. Our senior notes are governed by indentures containing covenants that may limit our ability and our subsidiaries’ ability to incur certain secured indebtedness, enter into sale-leaseback transactions, and consolidate, merge or transfer assets. The indentures governing the senior notes and the convertible senior notes do not have any financial or restricted payment covenants. Indentures for the Second Lien Notes, senior notes and convertible senior notes have cross default provisions that apply to other indebtedness Chesapeake or any guarantor subsidiary may have from time to time with an outstanding principal amount of at least $50 million or $75 million , depending on the indenture. Term Loan Facility We have a secured five -year term loan facility in an aggregate principal amount of $1.233 billion as of December 31, 2017 . Our obligations under the facility are unconditionally guaranteed on a joint and several basis by the same subsidiaries that guarantee our revolving credit facility, second lien notes and senior notes and are secured by first-priority liens on the same collateral securing our revolving credit facility (with a position in the collateral proceeds waterfall junior to the revolving credit facility). The term loan bears interest at a rate of London Interbank Offered Rate (LIBOR) plus 7.50% per annum, subject to a 1.00% LIBOR floor, or the Alternative Base Rate (ABR) plus 6.50% per annum, subject to a 2.00% ABR floor, at our option. The term loan matures in August 2021 and voluntary prepayments are subject to a make-whole premium prior to the second anniversary of the closing of the term loan, a premium to par of 4.25% from the second anniversary until but excluding the third anniversary, a premium to par of 2.125% from the third anniversary until but excluding the fourth anniversary and at par beginning on the fourth anniversary. The term loan may be subject to mandatory prepayments and offers to purchase with net cash proceeds of certain issuances of debt, certain asset sales and other dispositions of collateral and upon a change of control. The term loan contains covenants limiting our ability to incur additional indebtedness, incur liens, consummate mergers and similar fundamental changes, make restricted payments, sell collateral and use proceeds from such sales, make investments, repay certain subordinate, unsecured or junior lien indebtedness, and enter into transactions with affiliates. Revolving Credit Facility We have a senior secured revolving credit facility currently subject to a $3.8 billion borrowing base that matures in December 2019. As of December 31, 2017 , we had outstanding borrowings of $781 million under the revolving credit facility and had used $116 million of the revolving credit facility for various letters of credit. Borrowings under the revolving credit facility bear interest at a variable rate. The terms of the revolving credit facility include covenants limiting, among other things, our ability to incur additional indebtedness, make investments or loans, create liens, consummate mergers and similar fundamental changes, make restricted payments, make investments in unrestricted subsidiaries and enter into transactions with affiliates. In the fourth quarter of 2017, we completed a scheduled borrowing base redetermination review and our lenders reaffirmed our $3.8 billion borrowing base. Our next borrowing base redetermination is scheduled for the second quarter of 2018. We entered into a third amendment to our revolving credit facility in 2016, and a fourth amendment in 2017. After giving effect to those amendments, our revolving credit facility currently requires that we maintain a net debt to capitalization ratio of not greater than 65% , a first lien secured leverage ratio of not more than 3.50 to 1.0 on December 31, 2017 and 3.00 to 1.0 thereafter and an interest coverage ratio of at least 1.25 to 1.0 . In the third amendment, we agreed to grant liens and security interests on a majority of our assets. The third amendment also gave us the ability to incur first lien indebtedness on a pari passu basis with the existing obligations under the credit agreement, subject to a position in the collateral proceeds waterfall in favor of the revolving lenders and affiliated hedge providers and the other limitations on junior lien debt set forth in the credit agreement. The amount of such additional first lien indebtedness currently permitted by the revolving credit facility is $1.3 billion . As of December 31, 2017 , we were in compliance with all applicable financial covenants under the credit agreement and we were able to borrow up to the full availability under the revolving credit facility. Fair Value of Debt We estimate the fair value of our senior notes based on the market value of our publicly traded debt as determined based on the yield of our senior notes (Level 1). The fair value of all other debt is based on a market approach using estimates provided by an independent investment financial data services firm (Level 2). Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: December 31, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 52 $ 53 $ 503 $ 511 Long-term debt (Level 1) $ 2,633 $ 2,629 $ 3,271 $ 3,216 Long-term debt (Level 2) $ 7,286 $ 7,301 $ 6,664 $ 6,654

Contingencies and Commitments (

Contingencies and Commitments (Notes)	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies Litigation and Regulatory Proceedings We are involved in a number of litigation and regulatory proceedings including those described below. Many of these proceedings are in early stages, and many of them seek or may seek damages and penalties, the amount of which is indeterminate. Our total accrued liability in respect of litigation and regulatory proceedings is determined on a case-by-case basis and represents an estimate of probable losses after considering, among other factors, the progress of each case or proceeding, our experience and the experience of others in similar cases or proceedings, and the opinions and views of legal counsel. Significant judgment is required in making these estimates and our final liabilities may ultimately be materially different. Regulatory and Related Proceedings. We have received U.S. Postal Service and state subpoenas seeking information on our royalty payment practices. We have engaged in discussions with the U.S. Postal Service and state agency representatives and continue to respond to related subpoenas and demands. Business Operations. We are involved in various other lawsuits and disputes incidental to our business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions. Regarding royalty claims, we 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, utilized improper measurement techniques entered into arrangements with affiliates that resulted in underpayment of royalties in connection with the production and sale of natural gas and NGL, or similar theories. These lawsuits include cases filed by individual royalty owners and putative class actions, some of which seek to certify a statewide class. The lawsuits seek compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our royalty payment practices, pre-and post-judgment interest, and attorney’s fees and costs. 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. We have 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 numerous lawsuits seeking damages with respect to underpayment of royalties in multiple states where we have operated, including those discussed below. On December 9, 2015, the Commonwealth of Pennsylvania, by the Office of Attorney General, filed a lawsuit in the Bradford County Court of Common Pleas related to royalty underpayment and lease acquisition and accounting practices with respect to properties in Pennsylvania. The lawsuit, which primarily relates to the Marcellus Shale and Utica Shale, alleges that we violated the Pennsylvania Unfair Trade Practices and Consumer Protection Law (UTPCPL) by making improper deductions and entering into arrangements with affiliates that resulted in underpayment of royalties. The lawsuit includes other UTPCPL claims and antitrust claims, including that a joint exploration agreement to which we are a party established unlawful market allocation for the acquisition of leases. The lawsuit seeks statutory restitution, civil penalties and costs, as well as a temporary injunction from exploration and drilling activities in Pennsylvania until restitution, penalties and costs have been paid, and a permanent injunction from further violations of the UTPCPL. Putative statewide class actions in Pennsylvania and Ohio and purported class arbitrations in Pennsylvania have been filed on behalf of royalty owners asserting various claims for damages related to alleged underpayment of royalties as a result of the divestiture of substantially all of our midstream business and most of our gathering assets in 2012 and 2013. These cases include claims for violation of and conspiracy to violate the federal Racketeer Influenced and Corrupt Organizations Act and for an unlawful market allocation agreement for mineral rights, intentional interference with contractual relations, and violations of antitrust laws related to purported markets for gas mineral rights, operating rights and gas gathering sources. These lawsuits seek in aggregate compensatory, consequential, treble, and punitive damages, restitution and disgorgement of profits, declaratory and injunctive relief regarding our royalty payment practices, pre-and post-judgment interest, and attorney’s fees and costs. On December 20, 2017, we reached a tentative settlement to resolve substantially all Pennsylvania civil royalty cases for approximately $30 million . We believe losses are reasonably possible in certain of the pending royalty cases for which we have not accrued a loss contingency, but we are currently unable to estimate an amount or range of loss or the impact the actions could have on our future results of operations or cash flows. Uncertainties in pending royalty cases generally include the complex nature of the claims and defenses, the potential size of the class in class actions, the scope and types of the properties and agreements involved, and the applicable production years. We are also defending lawsuits alleging various violations of the Sherman Antitrust Act and state antitrust laws. In 2016, putative class action lawsuits were filed in the U.S. District Court for the Western District of Oklahoma and in Oklahoma state courts, and an individual lawsuit was filed in the U.S. District Court of Kansas, in each case against us and other defendants. The lawsuits generally allege that, since 2007 and continuing through April 2013, the defendants conspired to rig bids and depress the market for the purchases of oil and natural gas leasehold interests and properties in the Anadarko Basin containing producing oil and natural gas wells. The lawsuits seek damages, attorney’s fees, costs and interest, as well as enjoinment from adopting practices or plans that would restrain competition in a similar manner as alleged in the lawsuits. Environmental Contingencies The nature of the oil and gas business carries with it certain environmental risks for us and our subsidiaries. We have implemented various policies, programs, procedures, training and audits to reduce and mitigate such environmental risks. We conduct periodic reviews, on a company-wide basis, to assess changes in our environmental risk profile. Environmental reserves are established for environmental liabilities for which economic losses are probable and reasonably estimable. We manage our exposure to environmental liabilities in acquisitions by using an evaluation process that seeks to identify pre-existing contamination or compliance concerns and address the potential liability. Depending on the extent of an identified environmental concern, we may, among other things, exclude a property from the transaction, require the seller to remediate the property to our satisfaction in an acquisition or agree to assume liability for the remediation of the property
Commitments	Commitments Operating Leases Future operating lease commitments related to other property and equipment are not recorded as obligations in the accompanying consolidated balance sheets. The aggregate undiscounted minimum future lease payments are presented below: December 31, 2017 ($ in millions) 2018 $ 6 2019 5 2020 2 2021 1 Total $ 14 Lease expense for the years ended December 31, 2017, 2016 and 2015, was $3 million , $5 million and $7 million , respectively. Gathering, Processing and Transportation Agreements We have contractual commitments with midstream service companies and pipeline carriers for future gathering, processing and transportation of oil, natural gas and NGL to move certain of our production to market. Working interest owners and royalty interest owners, where appropriate, will be responsible for their proportionate share of these costs. Commitments related to gathering, processing and transportation agreements are not recorded as obligations in the accompanying consolidated balance sheets; however, they are reflected in our estimates of proved reserves. The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: December 31, ($ in millions) 2018 $ 1,079 2019 1,051 2020 979 2021 883 2022 771 2023 – 2035 4,404 Total $ 9,167 In addition, we have entered into long-term agreements for certain natural gas gathering and related services within specified acreage dedication areas in exchange for cost-of-service based fees redetermined annually, or tiered fees based on volumes delivered relative to scheduled volumes. Future gathering fees may vary with the applicable agreement. Drilling Contracts We have contracts with various drilling contractors to utilize drilling services at market-based pricing. These commitments are not recorded as obligations in the accompanying consolidated balance sheets. As of December 31, 2017, the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $23 million . Oil, Natural Gas and NGL Purchase Commitments We commit to purchase oil, natural gas and NGL from other owners in the properties we operate, including owners associated with our remaining volumetric production payment (VPP) transaction. Production purchases under these arrangements are based on market prices at the time of production, and the purchased oil, natural gas and NGL are resold at market prices. See Volumetric Production Payments in Note 12 for further discussion of our VPP transactions. Other Commitments As part of our normal course of business, we enter into various agreements providing, or otherwise arranging for, financial or performance assurances to third parties on behalf of our wholly owned guarantor subsidiaries. These agreements may include future payment obligations or commitments regarding operational performance that effectively guarantee our subsidiaries’ future performance. In connection with acquisitions and divestitures, our purchase and sale agreements generally provide indemnification to the counterparty for liabilities incurred as a result of a breach of a representation or warranty by the indemnifying party and/or other specified matters. These indemnifications generally have a discrete term and are intended to protect the parties against risks that are difficult to predict or cannot be quantified at the time of entering into or consummating a particular transaction. For divestitures of oil and natural gas properties, our purchase and sale agreements may require the return of a portion of the proceeds we receive as a result of uncured title or environmental defects. Certain of our oil and natural gas properties are burdened by non-operating interests, such as royalty and overriding royalty interests, including overriding royalty interests sold through our VPP transactions. As the holder of the working interest from which these interests have been created, we have the responsibility to bear the cost of developing and producing the reserves attributable to these interests. See Volumetric Production Payments in Note 12 for further discussion of our VPP transactions. While executing our strategic priorities, we have incurred certain cash charges, including contract termination charges, financing extinguishment costs and charges for unused natural gas transportation and gathering capacity. As we continue to focus on our strategic priorities, we may take certain actions that reduce financial leverage and complexity, and we may incur additional cash and noncash charges.

Other Liabilities (Notes)

Other Liabilities (Notes)	12 Months Ended
	Dec. 31, 2017
Other Liabilities Disclosure [Abstract]
Other Liabilities Disclosure	Other Liabilities Other current liabilities as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) Revenues and royalties due others $ 612 $ 543 Accrued drilling and production costs 216 169 Joint interest prepayments received 74 71 Accrued compensation and benefits 214 239 Other accrued taxes 43 32 Bank of New York Mellon legal accrual (a) — 440 Other 296 304 Total other current liabilities $ 1,455 $ 1,798 ____________________________________________ (a) In 2017, we received notice from the U.S. Supreme Court that it would not review our appeal of the decision by the U.S. District Court for the Southern District of New York regarding the early redemption of our 6.775% Senior Notes due 2019. As a result of the decision, we paid $441 million with cash on hand and borrowings under the credit facility, and the related supersedeas bond was released. Other long-term liabilities as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 156 $ 160 Unrecognized tax benefits 101 97 Other 97 126 Total other long-term liabilities $ 354 $ 383 ____________________________________________ (a) The CHK Utica, L.L.C. investors’ right to receive proportionately an overriding royalty interest (ORRI) in the first 1,500 net wells drilled on certain of our Utica Shale leasehold runs through 2023. We have the right to repurchase the ORRIs in the remaining net wells once we have drilled a minimum of 1,300 net wells. As of December 31, 2017, we had drilled 572 net wells. The obligation to deliver future ORRIs, which has been recorded as a liability, will be settled through the future conveyance of the underlying ORRIs to the investors on a net-well basis. As of December 31, 2017 and 2016, approximately $30 million and $43 million of the total ORRI obligations are recorded in other current liabilities, respectively.

Income Taxes (Notes)

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Tax Disclosure	Income Taxes The components of the income tax provision (benefit) for each of the periods presented below are as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Current Federal $ (14 ) $ (14 ) $ — State 5 (5 ) (36 ) Current Income Taxes (9 ) (19 ) (36 ) Deferred Federal 13 (147 ) (4,385 ) State (2 ) (24 ) (42 ) Deferred Income Taxes 11 (171 ) (4,427 ) Total $ 2 $ (190 ) $ (4,463 ) The effective income tax expense (benefit) differed from the computed "expected" federal income tax expense on earnings before income taxes for the following reasons: Years Ended December 31, 2017 2016 2015 ($ in millions) Income tax expense (benefit) at the federal statutory rate (35%) $ 333 $ (1,606 ) $ (6,684 ) State income taxes (net of federal income tax benefit) 66 (30 ) (406 ) Remeasurement of deferred tax assets and liabilities 1,266 — — Change in valuation allowance (1,676 ) 1,423 2,727 Other 13 23 (100 ) Total $ 2 $ (190 ) $ (4,463 ) On December 22, 2017, the President of the United States signed into law the Tax Act, which substantially revised numerous areas of U.S. federal income tax law, including lowering the tax rate for corporations from a maximum rate of 35% to a flat rate of 21% and eliminating the corporate alternative minimum tax (AMT). These changes are generally in effect for tax years beginning after December 31, 2017. Although we are still in the process of evaluating the full impact of the Tax Act, the table above reflects the adjustments for remeasurement of deferred tax assets and liabilities. This remeasurement did not impact our income tax provision or balance sheet due to the offsetting effect of adjusting the valuation allowance. Due to various estimates included in determining the tax provision, the remeasurement is considered provisional and may be adjusted through subsequent events such as the filing of our consolidated federal income tax return for the period ended December 31, 2017. We reassessed the realizability of our deferred tax assets and continue to maintain a valuation allowance against a significant portion of our net deferred tax assets excluding the deferred tax assets related to AMT credit carryovers that are expected to be realized in the future. The $1.676 billion net decrease in our valuation allowance is reflected as a component of income tax expense in our consolidated statement of operations for the year ended December 31, 2017. This decrease is primarily due to offsetting the provisional remeasurement of deferred tax assets and liabilities as a result of the Tax Act, as well as an offset to current year tax expense. Deferred income taxes are provided to reflect temporary differences in the tax basis of assets and liabilities and their reported amounts in the financial statements. The tax-effected temporary differences, tax credits and net operating loss carryforwards that comprise our deferred taxes are as follows: Years Ended December 31, 2017 2016 ($ in millions) Deferred tax liabilities: Volumetric production payments $ (129 ) $ (223 ) Other (20 ) (62 ) Deferred tax liabilities (149 ) (285 ) Deferred tax assets: Property, plant and equipment 1 593 Net operating loss carryforwards 2,248 2,587 Carrying value of debt 161 539 Asset retirement obligations 42 98 Investments 161 275 Derivative instruments 17 161 Accrued liabilities 125 319 Other 71 118 Deferred tax assets 2,826 4,690 Valuation allowance (2,674 ) (4,389 ) Net deferred tax assets 152 301 Net deferred tax assets $ 3 $ 16 As of December 31, 2017, we had federal NOL carryforwards of approximately $8.073 billion and state NOL carryforwards of approximately $10.066 billion , which excludes the NOL carryforwards related to unrecognized tax benefits. The associated deferred tax assets related to these federal and state NOL carryforwards were $1.695 billion and $581 million , respectively. The NOL carryforwards expire between 2031 and 2037. The value of these carryforwards depends on our ability to generate taxable income. As of December 31, 2017 and 2016, we had deferred tax assets of $2.826 billion and $4.690 billion upon which we had a valuation allowance of $2.674 billion and $4.389 billion , respectively. Of the net change in the valuation allowance of $1.715 billion for both federal and state deferred tax assets, $1.676 billion is reflected as a component of income tax expense in the consolidated statement of operations and the remainder is reflected in components of stockholders’ equity. A valuation allowance for deferred tax assets, including NOL carryforwards, is recognized when it is more-likely- than-not that all or some portion 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 such taxable income is generated, to determine whether a valuation allowance is required. Such 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. Management assesses all 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 objectively verifiable negative evidence is the cumulative loss incurred over the three-year period ending December 31, 2017. Such objective negative evidence limits our ability to consider various forms of subjective positive evidence, such as our projections for future income. Accordingly, management has not changed its judgement with respect to the need for a valuation allowance against substantially all of our net deferred tax asset position. 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 positive evidence such as future expected growth. Our ability to utilize NOL carryforwards to reduce future federal taxable income and federal income tax is subject to various limitations under the Code. The utilization of these carryforwards may be limited upon the occurrence of certain ownership changes, including the issuance or exercise of rights to acquire stock, the purchase or sale of stock by 5% stockholders, as defined in Treasury regulations, and the offering of stock by us during any three-year period resulting in an aggregate change of more than 50% in the beneficial ownership of Chesapeake. As of December 31, 2017, we do not believe that an ownership change has occurred that would limit our NOL carryforwards. Certain future transactions involving our equity (including relatively small transactions and transactions beyond our control) could cause an ownership change and therefore a limitation on the annual utilization of NOL carryforwards and possibly other tax attributes. Accounting guidance for recognizing and measuring uncertain tax positions requires a more-likely-than-not threshold condition be met on a tax position, based solely on the technical merits of being sustained, before any benefit of the tax position can be recognized in the financial statements. Guidance is also provided regarding de-recognition, classification and disclosure of these uncertain tax positions. As of December 31, 2017 and 2016, the amount of unrecognized tax benefits related to NOL carryforwards and tax liabilities associated with uncertain tax positions was $106 million and $202 million , respectively. Of the 2017 amount, $74 million is related to state tax liabilities, $4 million is related to federal tax liabilities and the remainder is related to NOL carryforwards. Of the 2016 amount, $76 million is related to state tax liabilities while the remainder is related to NOL carryforwards. If recognized, $74 million of the uncertain tax positions identified would have an effect on the effective tax rate. No material changes to the current uncertain tax positions are expected within the next 12 months. As of December 31, 2017 and 2016, we had accrued liabilities of $23 million and $20 million , respectively, for interest related to these uncertain tax positions. We recognize interest related to uncertain tax positions as a component of interest expense. Penalties, if any, related to uncertain tax positions would be recorded in other expenses. A reconciliation of the beginning and ending balances of unrecognized tax benefits is as follows: 2017 2016 2015 ($ in millions) Unrecognized tax benefits at beginning of period $ 202 $ 280 $ 303 Additions based on tax positions related to the current year — — 27 Additions to tax positions of prior years 4 33 — Settlements (100 ) (111 ) — Reductions to tax positions of prior years — — (50 ) Unrecognized tax benefits at end of period $ 106 $ 202 $ 280 Our federal and state income tax returns are routinely audited by federal and state fiscal authorities. The Internal Revenue Service (IRS) is currently auditing our federal income tax returns for 2010 through 2015. During the 2017 fourth quarter, we reached a tentative settlement with the IRS in regards to our 2010 to 2013 federal income tax returns. Even though the audit remains open, we have concluded that uncertain tax positions related to these respective years are effectively settled and the corresponding unrecognized tax benefits have now been recorded. The 2010 through 2017 years and the 2007 through 2017 years remain open for all purposes of examination by the IRS and other taxing authorities in material jurisdictions, respectively.

Related Parties (Notes)

Related Parties (Notes)	12 Months Ended
	Dec. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related Party Transactions Our equity method investees are considered related parties. Hydraulic fracturing and other services are provided to us in the ordinary course of business by our equity affiliate FTSI. As well operators, we are reimbursed by other working interest owners through the joint interest billing process for their proportionate share of these costs. For the years ended December 31, 2017, 2016 and 2015, our expenditures for hydraulic fracturing services with FTSI were $111 million , $3 million and $65 million , respectively.

Equity (Notes)

Equity (Notes)	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Stockholders' Equity Note Disclosure	Equity Common Stock A summary of the changes in our common shares issued for the years ended December 31, 2017, 2016 and 2015 is detailed below: Years Ended December 31, 2017 2016 2015 (in thousands) Shares issued as of January 1 896,279 664,796 664,944 Exchange of convertible notes — 55,428 — Exchange of senior notes — 53,924 — Exchange/conversion of preferred stock 9,966 120,186 — Restricted stock issuances (net of forfeitures and cancellations) 2,488 1,945 (163 ) Stock option exercises — — 15 Shares issued as of December 31 908,733 896,279 664,796 During the year ended December 31, 2017, our shareholders approved an amendment to our certificate of incorporation to increase our authorized common stock to 2,000,000,000 shares, par value $0.01 per share. Preferred Stock Following is a summary of our preferred stock, including the primary conversion terms as of December 31, 2017: Preferred Stock Series Issue Date Liquidation Preference per Share Holder's Conversion Right Conversion Rate Conversion Price Company's Conversion Right From Company's Market Conversion Trigger (a) 5.75% cumulative convertible non-voting May and June 2010 $ 1,000 Any time 39.6858 $ 25.1979 May 17, 2015 $ 32.7573 5.75% (series A) cumulative convertible non-voting May 2010 $ 1,000 Any time 38.3508 $ 26.0751 May 17, 2015 $ 33.8976 4.50% cumulative convertible September 2005 $ 100 Any time 2.4561 $ 40.7152 September 15, 2010 $ 52.9298 5.00% cumulative convertible (series 2005B) November 2005 $ 100 Any time 2.7745 $ 36.0431 November 15, 2010 $ 46.8560 ___________________________________________ (a) Convertible at the Company's option if the trading price of the Company's common stock equals or exceeds the trigger price for a specified time period or after the applicable conversion date if there are less than 250,000 shares of 4.50% or 5.00% (Series 2005B) preferred stock outstanding or 25,000 shares of 5.75% or 5.75% (Series A) preferred stock outstanding. Outstanding shares of our preferred stock for the years ended December 31, 2017, 2016 and 2015 are detailed below: 5.75% 5.75% (A) 4.50% 5.00% (2005B) (in thousands) Shares outstanding as of January 1, 2017 843 476 2,559 1,962 Preferred stock conversions/exchanges (a) (73 ) (13 ) — (151 ) Shares outstanding as of December 31, 2017 770 463 2,559 1,811 Shares outstanding as of January 1, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions/exchanges (b) (654 ) (624 ) — (134 ) Shares outstanding as of December 31, 2016 843 476 2,559 1,962 Shares outstanding as of January 1, 2015 and December 31, 2015 1,497 1,100 2,559 2,096 ____________________________________________ (a) During 2017, holders of our 5.75% Cumulative Convertible Preferred Stock exchanged 72,600 shares into 7,442,156 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock exchanged 12,500 shares into 1,205,923 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged 150,948 shares into 1,317,756 shares of common stock. In connection with the exchanges, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $41 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share. (b) During 2016, holders of our 5.75% Cumulative Convertible Preferred Stock converted 653,872 shares into 59,141,429 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 624,137 shares into 60,032,734 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged or converted 134,000 shares into 1,012,032 shares of common stock. In connection with the exchanges noted above, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $428 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share. Dividends Dividends declared on our preferred stock are reflected as adjustments to retained earnings to the extent a surplus of retained earnings exists after giving effect to the dividends. To the extent retained earnings are insufficient to fund the distributions, payments are reflected in our financial statements as a return of contributed capital rather than earnings and are accounted for as a reduction to paid-in capital. Dividends on our outstanding preferred stock are payable quarterly. We may pay dividends on our 5.00% Cumulative Convertible Preferred Stock (Series 2005B) and our 4.50% Cumulative Convertible Preferred Stock in cash, common stock or a combination thereof, at our option. Dividends on both series of our 5.75% Cumulative Convertible Non-Voting Preferred Stock are payable only in cash. In January 2016, we suspended dividend payments on our convertible preferred stock to provide additional liquidity in the depressed commodity price environment. In the first quarter of 2017, we reinstated the payment of dividends on each series of our outstanding convertible preferred stock and paid our dividends in arrears. Accumulated Other Comprehensive Income (Loss) For the years ended December 31, 2017 and 2016, changes in accumulated other comprehensive income (loss) for cash flow hedges, net of tax, are detailed below: Years Ended December 31, 2017 2016 ($ in millions) Balance, as of January 1 $ (96 ) $ (99 ) Other comprehensive income (loss) before reclassifications 5 (13 ) Amounts reclassified from accumulated other comprehensive income 34 16 Net other comprehensive income (loss) 39 3 Balance, as of December 31 $ (57 ) $ (96 ) For the years ended December 31, 2017 and 2016, 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 consolidated statements of operations were $34 million and $16 million , respectively. Noncontrolling Interests Chesapeake Granite Wash Trust. In 2011, Chesapeake Granite Wash Trust (the Trust) sold 23,000,000 common units representing beneficial interests in the Trust to the public. Prior to June 30, 2017, we owned 12,062,500 common units and as well as 11,687,500 subordinated units representing a 51% beneficial interest in the Trust. On June 30, 2017, the Trust’s subordinated units, all of which were held by us, converted to common units. The Trust has a total of 46,750,000 units outstanding. Prior to their conversion on June 30, 2017, as holder of the subordinated units, we were entitled to receive pro rata distributions from the Trust each quarter if and to the extent there was sufficient cash. We were also entitled to receive, prior to their termination on June 30, 2017, incentive distributions, to the extent of sufficient cash, as defined. No subordinated unit or incentive distributions were made by the Trust. During our review of the carrying amount of the Trust’s noncontrolling interests, we identified errors related to the allocation of impairment expense between Chesapeake and the Trust’s noncontrolling interests during previously reported periods. We have determined that these errors are immaterial to previously issued financial statements and therefore, have revised the previously reported financial statements below. We have also determined that these errors did not relate to periods prior to 2015. December 31, 2016 CONSOLIDATED BALANCE SHEETS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (17,603 ) $ 129 $ (17,474 ) Total Chesapeake stockholders’ equity (deficit) $ (1,460 ) $ 129 $ (1,331 ) Noncontrolling interests $ 257 $ (129 ) $ 128 Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Net (income) loss attributable to noncontrolling interest $ (2 ) $ 11 $ 9 Net income (loss) attributable to Chesapeake $ (4,401 ) $ 11 $ (4,390 ) Net income (loss) available to common stockholders $ (4,926 ) $ 11 $ (4,915 ) Loss per common share basic $ (6.45 ) $ 0.02 $ (6.43 ) Loss per common share diluted $ (6.45 ) $ 0.02 $ (6.43 ) Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Net (income) loss attributable to noncontrolling interest $ (50 ) $ 118 $ 68 Net income (loss) attributable to Chesapeake $ (14,685 ) $ 118 $ (14,567 ) Net income (loss) available to common stockholders $ (14,856 ) $ 118 $ (14,738 ) Loss per common share basic $ (22.43 ) $ 0.17 $ (22.26 ) Loss per common share diluted $ (22.43 ) $ 0.17 $ (22.26 ) Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Comprehensive (income) loss attributable to noncontrolling interests $ (2 ) $ 11 $ 9 Comprehensive income (loss) attributable to Chesapeake $ (4,398 ) $ 11 $ (4,387 ) Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Comprehensive (income) loss attributable to noncontrolling interests $ (50 ) $ 118 $ 68 Comprehensive income (loss) attributable to Chesapeake $ (14,641 ) $ 118 $ (14,523 ) Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (17,603 ) $ 129 $ (17,474 ) Noncontrolling interests $ 257 $ (129 ) $ 128 Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (13,202 ) $ 118 $ (13,084 ) Noncontrolling interests $ 259 $ (118 ) $ 141 We have determined that the Trust is a VIE and that we are the primary beneficiary. As a result, the Trust is included in our consolidated financial statements. As of December 31, 2017 and 2016, we had $124 million and $128 million , respectively, of noncontrolling interests on our consolidated balance sheets attributable to the Trust. Net income attributable to the Trust’s noncontrolling interest was $4 million for the year ended December 31, 2017 and net loss attributable to the Trust’s noncontrolling interest was $9 million and $68 million for the years ended December 31, 2016 and 2015, respectively. The Trust’s 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. We have presented parenthetically on the face of the 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. Cleveland Tonkawa Financial Transaction. We formed CHK C-T in 2012 to continue development of a portion of our oil and natural gas assets in our Cleveland and Tonkawa plays, in which third-party investors contributed $1.25 billion in cash to CHK C-T in exchange for (i) 1.25 million preferred shares, and (ii) our obligation to deliver a 3.75% overriding royalty interest (ORRI) in the existing wells and up to 1,000 future net wells to be drilled on the contributed play leasehold. During 2015, CHK C-T sold all of its oil and natural gas properties to FourPoint Energy, LLC. See Note 12 for further discussion of this transaction. In connection with this transaction, we eliminated all related future drilling and ORRI commitments attributable to CHK C-T. Net income attributable to the noncontrolling interests of CHK C-T was $50 million for the year ended December 31, 2015.

Share-Based Compensation (Notes

Share-Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments	Share-Based Compensation Our share-based compensation program consists of restricted stock, stock options and performance share units (PSUs) granted to employees and restricted stock granted to non-employee directors under our long term incentive plans. The restricted stock and stock options are equity-classified awards and the PSUs are liability-classified awards. Share-Based Compensation Plans 2014 Long Term Incentive Plan . Our 2014 Long Term Incentive Plan (2014 LTIP), which is administered by the Compensation Committee of our Board of Directors, became effective on June 13, 2014 after it was approved by shareholders at our 2014 Annual Meeting. The 2014 LTIP replaced our Amended and Restated Long Term Incentive Plan which was adopted in 2005. The 2014 LTIP provides for up to 71,600,000 shares of common stock that may be issued as long-term incentive compensation to our employees and non-employee directors; provided, however, that the 2014 LTIP uses a fungible share pool under which (i) each share issued pursuant to a stock option or stock appreciation right (SAR) reduces the number of shares available under the 2014 LTIP by 1.0 share; (ii) each share issued pursuant to awards other than options and SARs reduces the number of shares available by 2.12 shares; (iii) if any awards of restricted stock under the 2014 LTIP, or its predecessor plan, are forfeited, expire, are settled for cash, or are tendered by the participant or withheld by us to satisfy any tax withholding obligation, then the shares subject to the award may be used again for awards; and (iv) PSUs and other performance awards which are payable solely in cash are not counted against the aggregate number of shares issuable. In addition, the 2014 LTIP prohibits the reuse of shares withheld or delivered to satisfy the exercise price of, or to satisfy tax withholding requirements for, an option or SAR. The 2014 LTIP also prohibits “net share counting” upon the exercise of options or SARs. The 2014 LTIP authorizes the issuance of the following types of awards: (i) nonqualified and incentive stock options; (ii) SARs; (iii) restricted stock; (iv) performance awards, including PSUs; and (v) other stock-based awards. For both stock options and SARs, the exercise price may not be less than the fair market value of our common stock on the date of grant and the maximum exercise period may not exceed ten years from the date of grant. Awards granted under the plan vest at specified dates and/or upon the satisfaction of certain performance or other criteria, as determined by the Compensation Committee. As of December 31, 2017, 40,574,965 shares of common stock remained issuable under the 2014 LTIP. Equity-Classified Awards Restricted Stock. We grant restricted stock units to employees and non-employee directors. A summary of the changes in unvested restricted stock during 2017, 2016 and 2015 is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value (in thousands) Unvested restricted stock as of January 1, 2017 9,092 $ 11.39 Granted 9,872 $ 5.40 Vested (4,573 ) $ 13.73 Forfeited (1,213 ) $ 8.32 Unvested restricted stock as of December 31, 2017 13,178 $ 6.37 Unvested restricted stock as of January 1, 2016 10,455 $ 17.31 Granted 4,604 $ 4.58 Vested (4,692 ) $ 17.23 Forfeited (1,275 ) $ 13.91 Unvested restricted stock as of December 31, 2016 9,092 $ 11.39 Unvested restricted stock as of January 1, 2015 10,091 $ 21.20 Granted 7,095 $ 13.90 Vested (4,157 ) $ 21.70 Forfeited (2,574 ) $ 16.98 Unvested restricted stock as of December 31, 2015 10,455 $ 17.31 The aggregate intrinsic value of restricted stock that vested during 2017 was approximately $26 million based on the stock price at the time of vesting. As of December 31, 2017 , there was approximately $47 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 1.88 years. Stock Options. In 2017, 2016 and 2015, we granted members of management stock options that vest ratably over a three -year period. Each stock option award has an exercise price equal to the closing price of our common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant. We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on an average of historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account our dividend policy, over the expected life of the option. The Company used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in 2017: Expected option life – years 6.0 Volatility 62.42 % Risk-free interest rate 2.17 % Dividend yield — % The following table provides information related to stock option activity for 2017, 2016 and 2015: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2017 8,593 $ 11.88 7.22 $ 14 Granted 9,226 $ 5.45 Exercised — $ — $ — Expired (435 ) $ 18.51 Forfeited (1,099 ) $ 9.12 Outstanding as of December 31, 2017 16,285 $ 8.25 7.73 $ 1 Exercisable as of December 31, 2017 4,474 $ 15.15 5.26 $ — Outstanding as of January 1, 2016 5,377 $ 19.37 5.80 $ — Granted 4,932 $ 3.71 Exercised — $ — $ — Expired (771 ) $ 19.46 Forfeited (945 ) $ 5.66 Outstanding as of December 31, 2016 8,593 $ 11.88 7.22 $ 14 Exercisable as of December 31, 2016 2,844 $ 19.60 5.53 $ — Outstanding as of January 1, 2015 4,599 $ 19.55 7.03 $ 5 Granted 1,208 $ 18.37 Exercised (14 ) $ 18.13 $ — Expired (416 ) $ 18.46 Forfeited — $ — Outstanding as of December 31, 2015 5,377 $ 19.37 5.80 $ — Exercisable as of December 31, 2015 2,045 $ 19.61 5.07 $ — ___________________________________________ (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 December 31, 2017 , there was $22 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 2.08 years . Restricted Stock and Stock Option Compensation. We recognized the following compensation costs related to restricted stock and stock options for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ 37 $ 38 $ 43 Oil and natural gas properties 12 16 23 Oil, natural gas and NGL production expenses 12 13 18 Marketing, gathering and compression expenses — 1 5 Total restricted stock and stock option compensation $ 61 $ 68 $ 89 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 2017 and 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% . 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% . Compensation expense associated with PSU grants is recognized over the service period based on the graded-vesting method. The value of the PSU awards at the end of each reporting period is dependent upon our estimates of the underlying performance measures. The payout percentage for all PSU grants is capped at 100% if the Company’s absolute TSR is less than zero . We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 83.97 % Risk-free interest rate 1.89 % Dividend yield for value of awards — % The following table presents a summary of our 2017, 2016 and 2015 PSU awards: Grant Date Fair Value December 31, 2017 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2017 Awards: Payable 2020 1,217,774 $ 8 $ 5 $ 3 2016 Awards: Payable 2019 2,348,893 $ 10 $ 9 $ 8 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1 PSU Compensation. We recognized the following compensation costs (credits) related to PSUs for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ (4 ) $ 14 $ (19 ) Restructuring and other termination costs — 1 (19 ) Marketing, gathering and compression — — (1 ) Oil and natural gas properties — — (2 ) Total PSU compensation $ (4 ) $ 15 $ (41 )

Employee Benefit Plans (Notes)

Employee Benefit Plans (Notes)	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [Abstract]
Pension and Other Postretirement Benefits Disclosure	Employee Benefit Plans Our qualified 401(k) profit sharing plan (401(k) Plan) is the Chesapeake Energy Corporation Savings and Incentive Stock Bonus Plan, which is open to employees of Chesapeake and all our subsidiaries. Eligible employees may elect to defer compensation through voluntary contributions to their 401(k) Plan accounts, subject to plan limits and those set by the IRS. We match employee contributions dollar for dollar (subject to a maximum contribution of 15% of an employee's base salary and performance bonus) in cash. We contributed $35 million , $39 million and $52 million to the 401(k) Plan in 2017, 2016 and 2015, respectively. We also maintain a nonqualified deferred compensation plan (DC Plan). To be eligible to participate in the DC Plan, an active employee must have a base salary of at least $150,000 , have a hire date on or before December 1, immediately preceding the year in which the employee is able to participate, or be designated as eligible to participate. Only the top 10% of our wage earners are eligible to participate. We match 100% of employee contributions up to 15% of base salary and performance bonus in the aggregate for the DC Plan with Chesapeake common stock, and an employee who is at least age 55 may elect for the matching contributions to be made in any one of the DC Plan’s investment options. The maximum compensation that can be deferred by employees under all of our deferred compensation plans, including the Chesapeake 401(k) Plan, is a total of 75% of base salary and 100% of performance bonus. We contributed $8 million , $9 million and $11 million to the DC Plan during 2017, 2016 and 2015, respectively, to fund the match. Beginning in 2016, the DC Plan was no longer a spillover plan from the 401(k) Plan. The participant may choose separate deferral election percentages for both plans. The deferred compensation company match of 15% has a five -year vesting schedule based on years of service. Any participant who is active on December 31 of the plan year will receive the deferred compensation company match which will be awarded on an annual basis. Any assets placed in trust by us to fund future obligations of our nonqualified deferred compensation plan is subject to the claims of creditors in the event of insolvency or bankruptcy, and participants are general creditors of the Company as to their deferred compensation in the plan.

Derivative and Hedging Activiti

Derivative and Hedging Activities (Notes)	12 Months Ended
	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Hedging Activities Disclosure	Derivative and Hedging Activities We use derivative instruments to reduce our exposure to fluctuations in future commodity prices and to protect our expected operating cash flow against significant market movements or volatility. All of our oil, natural gas and NGL derivative instruments are net settled based on the difference between the fixed-price payment and the floating-price payment, resulting in a net amount due to or from the counterparty. None of our oil, natural gas and NGL derivative instruments were designated for hedge accounting as of December 31, 2017 and 2016. Oil, Natural Gas and NGL Derivatives As of December 31, 2017 and 2016, our oil, natural gas and NGL derivative instruments consisted of the following types of instruments: • Swaps : We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options and call swaptions. • Options : We sell, 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, we pay the counterparty the excess on sold call options and we receive the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party. • Call Swaptions : We sell call swaptions to counterparties that allow the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time. • Collars : These instruments contain a fixed floor price (put) and ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pays the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price. • Basis Protection Swaps : These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and 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 December 31, 2017 and 2016 are provided below: December 31, 2017 December 31, 2016 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 21 $ (151 ) 23 $ (140 ) Three-way collars 2 (10 ) — — Call options — — 5 (1 ) Call swaptions 2 (13 ) — — Basis protection swaps 11 (9 ) — — Total oil 36 (183 ) 28 (141 ) Natural gas (tbtu): Fixed-price swaps 532 149 719 (349 ) Collars 47 11 60 (9 ) Call options 110 (3 ) 114 — Basis protection swaps 65 (7 ) 31 (5 ) Total natural gas 754 150 924 (363 ) NGL (mmgal): Fixed-price swaps 33 (2 ) 53 — Total estimated fair value $ (35 ) $ (504 ) We have terminated certain commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. See further discussion below under Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) . Foreign Currency Derivatives During 2017, both our 6.25% Euro-denominated Senior Notes due 2017 and cross currency swaps for the same principal amount matured. Upon maturity of the notes, t he counterparties paid us €246 million and we paid the counterparties $327 million . The terms of the cross currency swaps were based on the dollar/euro exchange rate on the issuance date of $1.3325 to €1.00. The swaps were designated as cash flow hedges and, because they were entirely effective in having eliminated any potential variability in our expected cash flows related to changes in foreign exchange rates, changes in their fair value did not impact earnings. The fair values of the cross currency swaps were recorded on the consolidated balance sheet as a liability of $73 million as of December 31, 2016. Supply Contract Derivatives In 2016, we sold a long-term natural gas supply contract to a third party for cash proceeds of $146 million , which is included in marketing, gathering and compression revenues as a realized gain. We reversed the cumulative unrealized gains, resulting in an unrealized loss of $297 million . Effect of Derivative Instruments – Consolidated Balance Sheets The following table presents the fair value and location of each classification of derivative instrument included in the consolidated balance sheets as of December 31, 2017 and 2016 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of December 31, 2017 Commodity Contracts: Short-term derivative asset $ 157 $ (130 ) $ 27 Short-term derivative liability (188 ) 130 (58 ) Long-term derivative liability (4 ) — (4 ) Total commodity contracts (35 ) — (35 ) Total derivatives $ (35 ) $ — $ (35 ) As of December 31, 2016 Commodity Contracts: Short-term derivative asset $ 1 $ (1 ) $ — Short-term derivative liability (490 ) 1 (489 ) Long-term derivative liability (15 ) — (15 ) Total commodity contracts (504 ) — (504 ) Foreign Currency Contracts: (a) Short-term derivative liability (73 ) — (73 ) Total foreign currency contracts (73 ) — (73 ) Total derivatives $ (577 ) $ — $ (577 ) ____________________________________________ (a) Designated as cash flow hedging instruments. As of December 31, 2017 and 2016, we did not have any cash collateral balances for these derivatives. Effect of Derivative Instruments – Consolidated Statements of Operations The components of oil, natural gas and NGL revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Oil, natural gas and NGL revenues 4,574 3,866 4,767 Gains (losses) on undesignated oil, natural gas and NGL derivatives 445 (545 ) 661 Losses on terminated cash flow hedges (34 ) (33 ) (37 ) Total oil, natural gas and NGL revenues $ 4,985 $ 3,288 $ 5,391 The components of marketing, gathering and compression revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 4,511 $ 4,881 $ 7,077 Losses on undesignated supply contract derivatives — (297 ) 296 Total marketing, gathering and compression revenues $ 4,511 $ 4,584 $ 7,373 Effect of Derivative Instruments – Accumulated Other Comprehensive Income (Loss) A reconciliation of the changes in accumulated other comprehensive income (loss) in our consolidated statements of stockholders’ equity related to our cash flow hedges is presented below: Years Ended December 31, 2017 2016 2015 Before After Before After Before After ($ in millions) Balance, beginning of period $ (153 ) $ (96 ) $ (160 ) $ (99 ) $ (231 ) $ (143 ) Net change in fair value 5 5 (27 ) (13 ) 32 20 Losses reclassified to income 34 34 34 16 39 24 Balance, end of period $ (114 ) $ (57 ) $ (153 ) $ (96 ) $ (160 ) $ (99 ) The accumulated other comprehensive loss as of December 31, 2017 represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. Remaining deferred gain or loss amounts will be recognized in earnings in the month for which the original contract months are to occur. As of December 31, 2017 , we expect to transfer approximately $17 million of net loss included in accumulated other comprehensive income to net income (loss) during the next 12 months. The remaining amounts will be transferred by December 31, 2022. Credit Risk Considerations Our derivative instruments expose us to our counterparties’ credit risk. To mitigate this risk, we enter into derivative contracts only with counterparties that are highly rated or deemed by us to have acceptable credit strength and deemed by management to be competent and competitive market-makers, and we attempt to limit our exposure to non-performance by any single counterparty. As of December 31, 2017 , our oil, natural gas and NGL derivative instruments were spread among 11 counterparties. Hedging Arrangements Certain of our hedging arrangements are with counterparties that are also lenders (or affiliates of lenders) under our revolving credit facility. The contracts entered into with these counterparties are secured by the same collateral that secures our revolving credit facility, which allows us to reduce any letters of credit posted as security with those counterparties. In addition, we enter into bilateral hedging agreements with other counterparties. The counterparties’ and our obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts owed to us or by us exceed defined thresholds. Fair Value The fair value of our derivatives is based on third-party pricing models which utilize inputs that are either readily available in the public market, such as oil, natural gas and NGL forward curves and discount rates, or can be corroborated from active markets or broker quotes. These values are compared to the values given by our counterparties for reasonableness. Since oil, natural gas, NGL and cross currency swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. All other derivatives have some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivatives are also subject to the risk that either party to a contract will be unable to meet its obligations. We factor non-performance risk into the valuation of our derivatives using current published credit default swap rates. To date, this has not had a material impact on the values of our derivatives. The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during 2017 and 2016 is presented below: Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 2 — Total purchases, issuances, sales and settlements: Settlements (7 ) — Balance, as of December 31, 2017 $ (15 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 6 (118 ) Total purchases, issuances, sales and settlements: Settlements 75 (33 ) Sales — (146 ) Balance, as of December 31, 2016 $ (10 ) $ — ___________________________________________ (a) Commodity Derivatives Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 2 $ 6 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (14 ) $ (7 ) $ — $ — Qualitative and Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements The significant unobservable inputs for Level 3 derivative contracts include unpublished forward prices of natural gas, market volatility and credit risk of counterparties. Changes in these inputs impact the fair value measurement of our derivative contracts, which is based on an estimate derived from option models. For example, an increase or decrease in the forward prices and volatility of oil and natural gas prices decreases or increases the fair value of oil and natural gas derivatives, and adverse changes to our counterparties’ creditworthiness decreases the fair value of our derivatives. The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of December 31, 2017 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 13.14% – 24.93% 22.43% $ (23 ) Natural gas trades Natural gas price volatility curves 18.82% – 82.61% 38.06% $ 8

Oil and Natural Gas Property Tr

Oil and Natural Gas Property Transactions (Notes)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Mergers, Acquisitions and Dispositions Disclosure	Oil and Natural Gas Property Transactions Under full cost accounting rules, we accounted for the sales of oil and natural gas properties discussed below as adjustments to capitalized costs, with no recognition of gain or loss as the sales did not involve a significant change in proved reserves or significantly alter the relationship between costs and proved reserves. 2017 Transactions We sold portions of our acreage and producing properties in our Haynesville Shale operating area in northern Louisiana for approximately $915 million , subject to certain customary closing adjustments. Included in the sales were approximately 119,500 net acres and interests in 576 wells that were producing approximately 80 mmcf of gas per day at the time of closing. We received proceeds of approximately $350 million , net of post-closing adjustments, for the sale of other oil and natural gas properties covering various operating areas. 2016 Transactions We conveyed our interests in the Barnett Shale operating area located in north central Texas and received from the buyer aggregate net proceeds of approximately $218 million . We sold approximately 212,000 net developed and undeveloped acres along with other property and equipment. We simultaneously terminated most of our future commitments associated with this asset. In connection with this disposition, we paid $361 million to terminate certain natural gas gathering and transportation agreements and paid $58 million to restructure a long-term sales agreement. We recognized $361 million of expense for the termination of contracts and deferred charges of $58 million for the restructured contract. The deferred charges will be amortized to marketing, gathering and compression revenue over the life of the agreement. We may be required to pay additional amounts in respect of certain title and environmental contingencies. Additionally, we recognized a charge of $284 million in 2016 related to the impairment of other fixed assets sold in the divestiture. We sold the majority of our upstream and midstream assets in the Devonian Shale located in West Virginia, Kentucky and Virginia for proceeds of $140 million . We sold an interest in approximately 1.3 million net acres, retaining all rights below the base of the Kope formation, and approximately 5,300 wells along with related gathering assets, and other property and equipment. Additionally, we recognized an impairment charge of $142 million in 2016 related to other fixed assets sold in the divestiture. In connection with this divestiture, we purchased the underlying interests in one of our remaining VPP transactions for $127 million . All of the acquired interests were conveyed in our divestiture and we no longer have any future obligations related to this VPP. We acquired oil and natural gas properties in the Haynesville Shale for approximately $85 million . We sold certain of our other noncore oil and natural gas properties for net proceeds of approximately $1.048 billion , after post-closing adjustments. In conjunction with certain of these sales, we purchased oil and natural gas interests previously sold to third parties in connection with four of our VPP transactions for approximately $259 million . Substantially all 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. 2015 Transactions CHK Cleveland Tonkawa, L.L.C. (CHK C-T) sold all of its oil and natural gas properties to FourPoint Energy, LLC and immediately used the consideration, plus other cash it had on hand, to repurchase and cancel all of CHK C-T’s outstanding preferred shares. In a related transaction, we sold noncore properties adjacent to the CHK C-T properties to FourPoint Energy, LLC for approximately $90 million . Excluding proceeds received from selling additional interests in our joint venture leasehold described under Joint Ventures below, we received proceeds related to divestitures of other noncore oil and natural gas properties of approximately $66 million . Joint Ventures In 2017, 2016 and 2015, we sold interests in additional leasehold we acquired in the Marcellus, Barnett, Utica, Eagle Ford shales and Mid-Continent plays to our joint venture partners for approximately $10 million , $7 million and $33 million , respectively. Volumetric Production Payments 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. 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 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. Our commitment to bear the costs on any future production of VPP volumes is not reflected as a liability on our balance sheet. Future costs will depend on the actual production volumes as well as the production costs and taxes in effect during the periods in which the production actually occurs, which could differ materially from our current and historical costs, and production may not occur at the times or in the quantities projected, or at all. We have 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. In connection with certain asset divestitures in 2016, we purchased the remaining oil and natural gas interests previously sold in connection with VPP #10, VPP #4, VPP #3, VPP #2 and VPP #1. A majority of the oil and natural gas interests purchased were subsequently sold to the buyers of the assets. VPP#8 expired in August 2015. As of December 31, 2017 , we had the following VPP outstanding: Volume Sold VPP # Date of VPP Location Proceeds Oil Natural Gas NGL Total ($ in millions) (mmbbl) (bcf) (mmbbl) (bcfe) 9 May 2011 Mid-Continent $ 853 1.7 138 4.8 177 The volumes remaining to be delivered on behalf of our VPP buyers as of December 31, 2017 were as follows: Volume Remaining as of December 31, 2017 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 38 0.4 34.1 0.9 41.7

Other Property and Equipment (N

Other Property and Equipment (Notes)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Other Property and Equipment Disclosure	Other Property and Equipment Other Property and Equipment A summary of other property and equipment held for use and the estimated useful lives thereof is as follows: December 31, Estimated Useful Life 2017 2016 ($ in millions) (in years) Buildings and improvements $ 1,093 $ 1,119 10 – 39 Computer equipment 345 337 5 Natural gas compressors 235 251 3 – 20 Land 126 139 Gathering systems and treating plants 2 2 20 Other 185 205 5 – 10 Total other property and equipment, at cost 1,986 2,053 Less: accumulated depreciation (672 ) (632 ) Total other property and equipment, net $ 1,314 $ 1,421 Net (Gains) Losses on Sales of Fixed Assets A summary by asset class of (gains) or losses on sales of fixed assets for the years ended December 31, 2017, 2016 and 2015 is as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Buildings and land $ (4 ) $ (1 ) $ 3 Natural gas compressors 1 (10 ) — Gathering systems and treating plants — — 1 Other — (1 ) — Total net (gains) losses on sales of fixed assets $ (3 ) $ (12 ) $ 4 Assets Held for Sale We are continuing to pursue the sale of buildings and land located primarily in Oklahoma and West Virginia. These assets are being actively marketed, and we believe it is probable they will be sold over the next 12 months. As a result, these assets are reflected as held for sale as of December 31, 2017. Oil and natural gas properties that we intend to sell are not presented as held for sale pursuant to the rules governing full cost accounting for oil and gas properties. As of December 31, 2017 and 2016, we had $16 million and $29 million , respectively, of buildings, land and compressors net of accumulated depreciation, classified as assets held for sale on our consolidated balance sheets.

Impairments (Notes)

Impairments (Notes)	12 Months Ended
	Dec. 31, 2017
Asset Impairment Charges [Abstract]
Asset Impairment Charges Disclosure	Impairments Impairments of Oil and Natural Gas Properties Our proved oil and natural gas properties are subject to quarterly full cost ceiling tests. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. Estimated future net revenues for the quarterly ceiling limit are calculated using the average of commodity prices on the first day of the month over the trailing 12-month period. In 2017, we did not have an impairment for our oil and natural gas properties. In 2016 and 2015, capitalized costs of oil and natural gas properties exceeded the ceiling, resulting in an impairment in the carrying value of our oil and natural gas properties of $2.564 billion and $18.238 billion , respectively. Impairments of Fixed Assets and Other We review our long-lived assets, other than oil and natural gas properties, for recoverability whenever events or changes in circumstances indicate that carrying amounts may not be recoverable. We recognize an impairment if the carrying amount of a long-lived asset is not recoverable and exceeds its fair value. A summary of our impairments of fixed assets by asset class and other charges for the years ended December 31, 2017, 2016 and 2015 is as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Barnett Shale exit costs $ — $ 645 $ — Devonian Shale exit costs — 142 — Gathering systems — 3 — Natural gas compressors — 21 21 Buildings and land 5 11 — Other charges 416 16 173 Total impairments of fixed assets and other $ 421 $ 838 $ 194 Barnett Shale Exit Costs. In 2016, we conveyed our interests in the Barnett Shale operating area located in north central Texas and simultaneously terminated most of our future commitments associated with this asset. As a result of this transaction, we recognized $361 million of charges related to the termination of natural gas gathering and transportation agreements. We also recognized an impairment charge of $284 million in 2016 related to other fixed assets sold in the divestiture. Devonian Shale Exit Costs. In 2016, we sold the majority of our upstream and midstream assets in the Devonian Shale located in West Virginia and Kentucky. We recognized an impairment charge of $142 million in 2016 related to other fixed assets sold in the divestiture. Natural Gas Compressors. In 2016, we recorded a $13 million impairment related to obsolescence of 205 compressors. Additionally, we recorded an $8 million impairment related to 155 compressors for the difference between the aggregate sales price and carrying value. Other. In 2017, we terminated future natural gas transportation commitments related to divested assets for cash payments of $126 million . In 2017, we also paid $290 million to assign an oil transportation agreement to a third party. In 2015, we recorded a $47 million loss contingency related to contract disputes. In 2015, we recorded a $22 million impairment of a note receivable as a result of the increased credit risk associated with declining commodity prices. In addition, under the terms of our joint venture agreements, we are required to extend, renew or replace certain expiring joint leasehold, at our cost, to ensure that the net acreage is maintained in certain designated areas. In 2015, we entered into a settlement with Total regarding our acreage maintenance commitment in our Barnett Shale joint venture and accrued a $70 million charge. In 2015, as a result of reductions in our planned drilling activity in response to declines in oil and natural gas prices, we terminated contracts with drilling contractors and incurred charges of $18 million . Nonrecurring Fair Value Measurements. Fair value measurements for certain of the impairments were based on recent sales information for comparable assets. As the fair value was estimated using the market approach based on recent prices from orderly sales transactions for comparable assets between market participants, these values were classified as Level 2 in the fair value hierarchy. Other inputs used were not observable in the market; these values were classified as Level 3 in the fair value hierarchy.

Restructuring and Other Termina

Restructuring and Other Termination Costs (Notes)	12 Months Ended
	Dec. 31, 2017
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure	Restructuring and Other Termination Costs Workforce Reductions In 2016, we recognized $6 million of charges related to a reduction of workforce in connection with the restructuring of our compressor manufacturing subsidiary and the reductions of workforce resulting from the conveyance of our interests in the Barnett Shale and Devonian Shale operating areas. On September 29, 2015, we reduced our workforce by approximately 15% as part of an overall plan to reduce costs and better align our workforce with the needs of our business and current oil and natural gas commodity prices. In connection with the reduction, we incurred a total charge of approximately $55 million in 2015 for one-time termination benefits. This charge consisted of $47 million in salary expense and $8 million in other termination benefits. Other We recognized credits of $19 million in 2015 related to negative fair value adjustments to PSUs granted to former executives of the Company which corresponded to a decrease in the trading price of our common stock. For further discussion of our PSUs, see Note 9.

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements Disclosure	Fair Value Measurements Recurring Fair Value Measurements Other Current Assets. Assets related to our deferred compensation plan are included in other current assets. The fair value of these assets is determined using quoted market prices as they consist of exchange-traded securities. Other Current Liabilities . Liabilities related to our deferred compensation plan are included in other current liabilities. The fair values of these liabilities are determined using quoted market prices as the plan consists of exchange-traded mutual funds. Financial Assets (Liabilities) . The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 ) See Note 3 for information regarding fair value measurement of our debt instruments. See Note 11 for information regarding fair value measurement of our derivatives. Nonrecurring Fair Value Measurements See Note 14 regarding nonrecurring fair value measurements.

(Asset Retirement Obligations N

(Asset Retirement Obligations Notes)	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure	Asset Retirement Obligations The components of the change in our asset retirement obligations are shown below: Years Ended December 31, 2017 2016 ($ in millions) Asset retirement obligations, beginning of period $ 261 $ 473 Additions 5 4 Revisions (34 ) (58 ) Settlements and disposals (70 ) (182 ) Accretion expense 15 24 Asset retirement obligations, end of period 177 261 Less current portion 15 14 Asset retirement obligation, long-term $ 162 $ 247

Major Customers

Major Customers	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Major Customers	Major Customers Sales to Royal Dutch Shell PLC constituted approximately 10% of our total revenues (before the effects of hedging) for the year ended December 31, 2017. Sales to BP PLC constituted approximately 10% and 14% of our total revenues (before the effects of hedging) for the years ended December 31, 2016 and 2015, respectively.

Condensed Consolidating Financi

Condensed Consolidating Financial Information (Notes)	12 Months Ended
	Dec. 31, 2017
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Financial Information of Parent Company Only Disclosure	Condensed Consolidating Financial Information Chesapeake Energy Corporation is a holding company, owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under our outstanding senior notes and contingent convertible senior notes listed in Note 3 are fully and unconditionally guaranteed, jointly and severally, by certain of our 100% owned subsidiaries on a senior unsecured basis. Subsidiaries with noncontrolling interests, consolidated variable interest entities and certain de minimis subsidiaries are non-guarantors. The tables below are condensed consolidating financial statements for Chesapeake Energy Corporation (parent) on a stand-alone, unconsolidated basis, and its combined guarantor and combined non-guarantor subsidiaries as of December 31, 2017 and for the year ended December 31, 2017. This financial information may not necessarily be indicative of our results of operations, cash flows or financial position had these subsidiaries operated as independent entities. CONDENSED CONSOLIDATING BALANCE SHEET AS OF DECEMBER 31, 2017 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 5 $ 1 $ 2 $ (3 ) $ 5 Other current assets 154 1,364 3 (1 ) 1,520 Intercompany receivable, net 8,697 436 — (9,133 ) — Total Current Assets 8,856 1,801 5 (9,137 ) 1,525 PROPERTY AND EQUIPMENT: Oil and natural gas properties at cost, based on full cost accounting, net 435 8,888 27 — 9,350 Other property and equipment, net — 1,314 — — 1,314 Property and equipment held for sale, net — 16 — — 16 Total Property and Equipment, Net 435 10,218 27 — 10,680 LONG-TERM ASSETS: Other long-term assets 52 168 — — 220 Investments in subsidiaries and intercompany advances 806 (146 ) — (660 ) — TOTAL ASSETS $ 10,149 $ 12,041 $ 32 $ (9,797 ) $ 12,425 CURRENT LIABILITIES: Current liabilities $ 190 $ 2,168 $ 2 $ (4 ) $ 2,356 Intercompany payable, net 433 8,648 52 (9,133 ) — Total Current Liabilities 623 10,816 54 (9,137 ) 2,356 LONG-TERM LIABILITIES: Long-term debt, net 9,921 — — — 9,921 Other long-term liabilities 101 419 — — 520 Total Long-Term Liabilities 10,022 419 — — 10,441 EQUITY: Chesapeake stockholders’ equity (deficit) (496 ) 806 (146 ) (660 ) (496 ) Noncontrolling interests — — 124 — 124 Total Equity (Deficit) (496 ) 806 (22 ) (660 ) (372 ) TOTAL LIABILITIES AND EQUITY $ 10,149 $ 12,041 $ 32 $ (9,797 ) $ 12,425 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS YEAR ENDED DECEMBER 31, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 4,962 $ 23 $ — $ 4,985 Marketing, gathering and compression — 4,511 — — 4,511 Total Revenues — 9,473 23 — 9,496 OPERATING EXPENSES: Oil, natural gas and NGL production — 562 — — 562 Oil, natural gas and NGL gathering, processing and transportation — 1,463 8 — 1,471 Production taxes — 88 1 — 89 Marketing, gathering and compression — 4,598 — — 4,598 General and administrative 1 259 2 — 262 Restructuring and other termination costs — — — — — Provision for legal contingencies, net (79 ) 41 — — (38 ) Oil, natural gas and NGL depreciation, depletion and amortization — 909 4 — 913 Depreciation and amortization of other assets — 82 — — 82 Impairments of fixed assets and other — 421 — — 421 Net gains on sales of fixed assets — (3 ) — — (3 ) Total Operating Expenses (78 ) 8,420 15 — 8,357 INCOME FROM OPERATIONS 78 1,053 8 — 1,139 OTHER INCOME (EXPENSE): Interest expense (424 ) (2 ) — — (426 ) Gains on purchases or exchanges of debt 233 — — — 233 Other income 1 8 — — 9 Equity in net earnings (losses) of subsidiary 1,063 4 — (1,067 ) — Total Other Income (Expense) 873 10 — (1,067 ) (184 ) INCOME BEFORE INCOME TAXES 951 1,063 8 (1,067 ) 955 INCOME TAX EXPENSE (BENEFIT) 2 — — — 2 NET INCOME 949 1,063 8 (1,067 ) 953 Net income attributable to noncontrolling interests — — (4 ) — (4 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 949 1,063 4 (1,067 ) 949 Other comprehensive income — 39 — — 39 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 949 $ 1,102 $ 4 $ (1,067 ) $ 988 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS YEAR ENDED DECEMBER 31, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 5 $ 736 $ 14 $ (10 ) $ 745 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (2,186 ) — — (2,186 ) Acquisitions of proved and unproved properties — (285 ) — — (285 ) Proceeds from divestitures of proved and unproved properties — 1,249 — — 1,249 Additions to other property and equipment — (21 ) — — (21 ) Other investing activities — 55 — — 55 Net Cash Used In Investing Activities — (1,188 ) — — (1,188 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 7,771 — — — 7,771 Payments on revolving credit facility borrowings (6,990 ) — — — (6,990 ) Proceeds from issuance of senior notes, net 1,585 — — — 1,585 Cash paid to purchase debt (2,592 ) — — — (2,592 ) Cash paid for preferred stock dividends (183 ) — — — (183 ) Other financing activities (39 ) (5 ) (13 ) 32 (25 ) Intercompany advances, net (456 ) 456 — — — Net Cash Provided by (Used In) Financing Activities (904 ) 451 (13 ) 32 (434 ) Net increase (decrease) in cash and cash equivalents (899 ) (1 ) 1 22 (877 ) Cash and cash equivalents, beginning of period 904 2 1 (25 ) 882 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (3 ) $ 5

Subsequent Events (Notes)

Subsequent Events (Notes)	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Subsequent to December 31, 2017, we underwent a reduction in workforce impacting approximately 13% of employees across all functions, primarily on our Oklahoma City campus. Subsequent to December 31, 2017, we sold approximately 4.3 million shares of FTSI International for net proceeds of approximately $74 million . We continue to hold approximately 22.0 million shares in the publicly traded company. Subsequent to December 31, 2017, we entered into agreements for the sale of properties in the Mid-Continent, including our Mississippian Lime assets, for expected aggregate proceeds of approximately $500 million . We expect to close these sales by the end of the 2018 second quarter, subject to customary closing conditions.

Basis of Presentation and Sum30

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Basis of Accounting, Policy	The accompanying consolidated financial statements of Chesapeake were prepared in accordance with 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.
Accounting Estimates, Policy	Accounting Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the related disclosures in the financial statements. Management evaluates its estimates and related assumptions regularly, including those related to the impairment of oil and natural gas properties, oil and natural gas reserves, derivatives, income taxes, collectibility of accounts receivable, impairment of other property and equipment, environmental remediation costs, asset retirement obligations, litigation and regulatory proceedings and fair values. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ significantly from these estimates.
Consolidation, Policy	Consolidation We consolidate entities in which we have a controlling financial interest. We consolidate subsidiaries in which we hold, directly or indirectly, more than 50% of the voting rights and variable interest entities (VIEs) in which we are the primary beneficiary. We use the equity method of accounting to record our net interests where we have the ability to exercise significant influence through our investment. Under the equity method, our share of net income (loss) is included in our consolidated statements of operations according to our equity ownership or according to the terms of the applicable governing instrument. Undivided interests in oil and natural gas properties are consolidated on a proportionate basis.
Segments, Policy	Segments Operating segments are defined as components of an enterprise that engage in activities from which it may earn revenues and incur expenses for which separate operational financial information is available and is regularly evaluated by the chief operating decision maker for the purpose of allocating an enterprise’s resources and assessing its operating performance. We have historically presented two reportable operating segments: (i) exploration and production and (ii) marketing, gathering and compression. In the fourth quarter of 2017, we completed the realignment of our marketing, gathering and compression operations to serve as an ancillary service integral to our exploration and production activities. Following this realignment, we have a single, company-wide management team that administers all activities as a whole rather than through discrete operating units, with an emphasis on allocating capital focused on the expansion of our exploration and production assets. As a result, we have concluded that we have only one reportable operating segment, which is exploration and production. Prior year financial information for our previous marketing, gathering and compression reportable operating segment has been eliminated.
Noncontrolling Interests, Policy	Noncontrolling Interests Noncontrolling interests represent third-party equity ownership in certain of our consolidated subsidiaries and are presented as a component of equity. See Note 8 for further discussion of noncontrolling interests.
Variable Interest Entity, Policy	Variable Interest Entities VIEs are entities that, by design, either (i) lack sufficient equity to permit the entity to finance its activities independently, or (ii) have equity holders that do not have the power to direct the activities of the entity that most significantly impact its economic performance, the obligation to absorb the entity’s losses, or the right to receive the entity’s residual returns. We consolidate a VIE when we are the primary beneficiary, which is the party that has both (i) the power to direct the activities that most significantly impact the VIE’s economic performance and (ii) through its interests in the VIE, the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether we own a variable interest in a VIE, we perform a qualitative analysis of the entity’s design, organizational structure, primary decision makers and relevant agreements. We continually monitor our consolidated VIE to determine if any events have occurred that could cause the primary beneficiary to change. See Note 8 for further discussion of our VIE
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents For purposes of the consolidated financial statements, we consider investments in all highly liquid instruments with original maturities of three months or less at the date of purchase to be cash equivalents Accounts Payable Included in accounts payable as of December 31, 2017 and 2016 are liabilities of approximately $92 million and $77 million , respectively, representing the amount by which checks issued, but not yet presented to our banks for collection, exceeded balances in applicable bank accounts.
Receivables, Policy	Accounts Receivable Our accounts receivable are primarily from purchasers of oil, natural gas and NGL and from exploration and production companies that own interests in properties we operate. This industry concentration could affect our overall exposure to credit risk, either positively or negatively, because our purchasers and joint working interest owners may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated. We utilize an allowance method in accounting for bad debt based on historical trends in addition to specifically identifying receivables that we believe may be uncollectible. Accounts receivable as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) Oil, natural gas and NGL sales $ 959 $ 840 Joint interest 209 156 Other 184 93 Allowance for doubtful accounts (30 ) (32 ) Total accounts receivable, net $ 1,322 $ 1,057
Oil and Gas Properties, Policy	Oil and Natural Gas Properties We follow the full cost method of accounting under which all costs associated with oil and natural gas property acquisition, exploration and development activities are capitalized. We capitalize internal costs that can be directly identified with these activities and do not capitalize any costs related to production, general corporate overhead or similar activities (see Supplementary Information – Supplemental Disclosures About Oil, Natural Gas and NGL Producing Activities ). Capitalized costs are amortized on a composite unit-of-production method based on proved oil and natural gas reserves. Estimates of our proved reserves as of December 31, 2017 were prepared by an independent engineering firm and our internal staff. In addition, our internal engineers review and update our reserves on a quarterly basis. Proceeds from the sale of oil and natural gas properties are accounted for as reductions of capitalized costs unless these sales involve a significant change in proved reserves and significantly alter the relationship between costs and proved reserves, in which case a gain or loss is recognized. The costs of unproved properties are excluded from amortization until the properties are evaluated. We review all of our unproved properties quarterly to determine whether or not and to what extent proved reserves have been assigned to the properties and otherwise if impairment has occurred. Unproved properties are grouped by major prospect area in circumstances where individual property costs are not significant. In addition, we analyze our unproved leasehold and transfer to proved properties that portion of our leasehold that expired in the quarter, or leasehold that is no longer part of our development strategy and will be abandoned. The table below sets forth the cost of unproved properties excluded from the amortization base as of December 31, 2017 and the year in which the associated costs were incurred: Year of Acquisition 2017 2016 2015 Prior Total ($ in millions) Leasehold cost $ 70 $ 89 $ 87 $ 2,368 $ 2,614 Exploration cost 50 9 33 11 103 Capitalized interest 154 116 120 377 767 Total $ 274 $ 214 $ 240 $ 2,756 $ 3,484 We also review, on a quarterly basis, the carrying value of our oil and natural gas properties under the full cost accounting rules of the SEC. This quarterly review is referred to as a ceiling test. 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 oil and natural gas derivatives designated as cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. The ceiling test calculation uses costs as of the end of the applicable quarterly period and the unweighted arithmetic average of oil, natural gas and NGL prices on the first day of each month within the 12-month period prior to the ending date of the quarterly period. These prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives designated as cash flow hedges. As of December 31, 2017, none of our open derivative instruments were designated as cash flow hedges. Our oil and natural gas hedging activities are discussed in Note 11. Two primary factors impacting the ceiling test are reserve levels and oil, natural gas and NGL prices, and their associated impact on the present value of estimated future net revenues. Revisions to estimates of oil and natural gas reserves and/or an increase or decrease in prices can have a material impact on the present value of our estimated future net revenues. Any excess of the net book value over the ceiling is written off as an impairment expense. We account for seismic costs as part of our oil and natural gas properties. Exploration costs may be incurred both before acquiring the related property and after acquiring the property. Further, exploration costs include, among other things, geological and geophysical studies and salaries and other expenses of geologists, geophysical crews and others conducting those studies. These costs are capitalized as incurred. We review our unproved properties and associated seismic costs quarterly to determine whether impairment has occurred. To the extent that seismic costs cannot be directly associated with specific unproved properties, they are included in the amortization base as incurred.
Other Property and Equipment, Policy	Other Property and Equipment Other property and equipment consists primarily of natural gas compressors, buildings and improvements, land, vehicles, computers and office equipment. Major renewals and betterments are capitalized while the costs of repairs and maintenance are charged to expense as incurred. The costs of assets retired or otherwise disposed of and the applicable accumulated depreciation are removed from the accounts, and the resulting gain or loss is reflected in operating expenses. Other property and equipment costs, excluding land, are depreciated on a straight-line basis. Realization of the carrying value of other property and equipment is reviewed for possible impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Assets are determined to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset, including any disposal value, is less than the carrying amount of the asset. If any asset is determined to be impaired, the loss is measured as the amount by which the carrying amount of the asset exceeds its fair value. An estimate of fair value is based on the best information available, including prices for similar assets and discounted cash flow.
Capitalized Interest, Policy	Capitalized Interest Interest from external borrowings is capitalized on significant investments in unproved properties and major development projects until the asset is ready for service using the weighted average borrowing rate of outstanding borrowings. Capitalized interest is determined by multiplying our weighted-average borrowing cost on debt by the average amount of qualifying costs incurred. Capitalized interest is depreciated over the useful lives of the assets in the same manner as the depreciation of the underlying asset.
Accounts Payable, Policy	Cash and Cash Equivalents For purposes of the consolidated financial statements, we consider investments in all highly liquid instruments with original maturities of three months or less at the date of purchase to be cash equivalents Accounts Payable Included in accounts payable as of December 31, 2017 and 2016 are liabilities of approximately $92 million and $77 million , respectively, representing the amount by which checks issued, but not yet presented to our banks for collection, exceeded balances in applicable bank accounts.
Debt, Policy	Debt Issuance Costs Included in other long-term assets are costs associated with the issuance and amendments of our revolving credit facility. The remaining unamortized issuance costs as of December 31, 2017 and 2016, totaled $22 million and $32 million , respectively, and are being amortized over the life of credit facility using the straight-line method. Included in debt are costs associated with the issuance of our senior notes and term loan. The remaining unamortized issuance costs as of December 31, 2017 and 2016, totaled $63 million and $64 million , respectively, and are being amortized over the life of the senior notes using the effective interest method.
Litigation Contingencies, Policy	Litigation Contingencies We are subject to litigation and regulatory proceedings, claims and liabilities that arise in the ordinary course of business. We accrue losses associated with litigation and regulatory claims when such losses are probable and reasonably estimable. If we determine that a loss is probable and cannot estimate a specific amount for that loss but can estimate a range of loss, our best estimate within the range is accrued. Estimates are adjusted as additional information becomes available or circumstances change. Legal defense costs associated with loss contingencies are expensed in the period incurred.
Environmental Remediation Costs, Policy	Environmental Remediation Costs We record environmental reserves for estimated remediation costs related to existing conditions from past operations when the responsibility to remediate is probable and the costs can be reasonably estimated. Expenditures that create future benefits or contribute to future revenue generation are capitalized.
Asset Retirement Obligation, Policy	Asset Retirement Obligations We recognize liabilities for obligations associated with the retirement of tangible long-lived assets that result from the acquisition, construction and development of the assets. We recognize the fair value of a liability for a retirement obligation in the period in which the liability is incurred. For oil and natural gas properties, this is the period in which an oil or natural gas well is acquired or drilled. The liability is then accreted each period until the liability is settled or the well is sold, at which time the liability is removed. The related asset retirement cost is capitalized as part of the carrying amount of our oil and natural gas properties. See Note 17 for further discussion of asset retirement obligations
Revenue Recognition, Policy	Revenue Recognition Oil, Natural Gas and NGL Sales . Revenue from the sale of oil, natural gas and NGL is recognized when title passes, net of royalties due to third parties. Natural Gas Imbalances . We follow the sales method of accounting for our natural gas revenue whereby we recognize sales revenue on all natural gas sold to our purchasers, regardless of whether the sales are proportionate to our ownership in the property. An asset or a liability is recognized to the extent that we have an imbalance in excess of the remaining estimated natural gas reserves on the underlying properties. The natural gas imbalance net liability position as of December 31, 2017 and 2016, was $5 million and $9 million , respectively. Marketing, Gathering and Compression Sales. In connection with the marketing of our production, we take title to the oil, natural gas and NGL we purchase from other interest owners at defined delivery points and deliver the product to third parties, at which time revenues are recorded. In addition, we periodically enter into a variety of oil, natural gas and NGL purchase and sale contracts with third parties for various commercial purposes, primarily for credit risk mitigation and to help meet certain of our pipeline delivery commitments. In circumstances where we act as a principal rather than an agent, our results of operations related to oil, natural gas and NGL marketing activities are presented on a gross basis. Gathering and compression revenues consist of fees billed to other interest owners in operated wells or third-party producers for the gathering, treating and compression of natural gas. Revenues are recognized when the service is performed and are based upon non-regulated rates and the related gathering, treating and compression volumes. All significant intercompany accounts and transactions have been eliminated.
Fair Value Measurement, Policy	Fair Value Measurements Certain financial instruments are reported at fair value on our consolidated balance sheets. Under fair value measurement accounting guidance, fair value is defined as the amount that would be received from the sale of an asset or paid for the transfer of a liability in an orderly transaction between market participants (i.e., an exit price). To estimate an exit price, a three-level hierarchy is used. The fair value hierarchy prioritizes the inputs, which refer broadly to assumptions market participants would use in pricing an asset or a liability, into three levels. Level 1 inputs are unadjusted quoted prices in active markets for identical assets and liabilities and have the highest priority. Level 2 inputs are inputs other than quoted prices within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability and have the lowest priority. The valuation techniques that may be used to measure fair value include a market approach, an income approach and a cost approach. A market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. An income approach uses valuation techniques to convert future amounts to a single present amount based on current market expectations, including present value techniques, option-pricing models and the excess earnings method. The cost approach is based on the amount that currently would be required to replace the service capacity of an asset (replacement cost). The carrying values of financial instruments comprising cash and cash equivalents, accounts payable and accounts receivable approximate fair values due to the short-term maturities of these instruments.
Derivatives, Policy	Derivatives Derivative instruments are recorded at fair value, and changes in fair value are recognized currently in earnings unless specific hedge accounting criteria are followed. For qualifying commodity derivative instruments designated as cash flow hedges, changes in fair value, to the extent the hedge is effective, are recognized in other comprehensive income until the hedged item is recognized in earnings. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings. Locked-in gains and losses of settled cash flow hedges are recorded in accumulated other comprehensive income and are transferred to earnings in the month of production. Changes in the fair value of interest rate derivative instruments designated as fair value hedges are recorded on the consolidated balance sheets as assets or liabilities, and the debt's carrying value amount is adjusted by the change in the fair value of the debt subsequent to the initiation of the derivative. Differences between the changes in the fair values of the hedged item and the derivative instrument, if any, represent hedge ineffectiveness and are recognized currently in earnings. Locked-in gains and losses related to settled fair value hedges are amortized as an adjustment to interest expense over the remaining term of the related debt instrument. We have elected not to designate any of our qualifying commodity and interest rate derivatives as cash flow or fair value hedges. Therefore, changes in fair value of these derivatives that occur prior to their maturity (i.e., temporary fluctuations in value) are recognized in our consolidated statements of operations within oil, natural gas and NGL sales and interest expense, respectively. Derivative instruments reflected as current in the consolidated balance sheets represent the estimated fair value of derivatives scheduled to settle over the next twelve months based on market prices/rates as of the respective balance sheet dates. Cash settlements of our derivative instruments are generally classified as operating cash flows unless the derivatives are deemed to contain, for accounting purposes, a significant financing element at contract inception, in which case these cash settlements are classified as financing cash flows in the accompanying consolidated statement of cash flows. All of our derivative instruments are subject to master netting arrangements by contract type which provide for the offsetting of asset and liability positions within each contract type, as well as related cash collateral if applicable, by counterparty. Therefore, we net the value of our derivative instruments by contract type with the same counterparty in the accompanying consolidated balance sheets. We have established the fair value of our derivative instruments using established index prices, volatility curves and discount factors. These estimates are compared to our counterparty values for reasonableness. The values we report in our financial statements are as of a point in time and subsequently change as these estimates are revised to reflect actual results, changes in market conditions and other factors. Derivative transactions are subject to the risk that counterparties will be unable to meet their obligations. This non-performance risk is considered in the valuation of our derivative instruments, but to date has not had a material impact on the values of our derivatives. See Note 11 for further discussion of our derivative instruments.
Share-based Compensation, Policy	Share-Based Compensation Our share-based compensation program consists of restricted stock, stock options and performance share units granted to employees and restricted stock granted to non-employee directors under our Long Term Incentive Plan. We recognize the cost of employee services received in exchange for restricted stock and stock options based on the fair value of the equity instruments as of the grant date. For employees, this value is amortized over the vesting period, which is generally three or four years from the grant date. For directors, although restricted stock grants vest over three years , this value is recognized immediately as there is a non-substantive service condition for vesting. Because performance share units can only be settled in cash, they are classified as a liability in our consolidated financial statements and are measured at fair value as of the grant date and re-measured at fair value at the end of each reporting period. These fair value adjustments are recognized as general and administrative expense in the consolidated statements of operations. To the extent compensation expense relates to employees directly involved in the acquisition of oil and natural gas leasehold and exploration and development activities, these amounts are capitalized to oil and natural gas properties. Amounts not capitalized to oil and natural gas properties are recognized as general and administrative expenses, oil, natural gas and NGL production expenses, or marketing, gathering and compression expenses, based on the employees involved in those activities. See Note 9 for further discussion of share-based compensation.
Reclassifications, Policy	Reclassifications Certain reclassifications have been made to the consolidated financial statements for 2016 and 2015 to conform to the presentation used for the 2017 consolidated financial statements.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) that supersedes virtually all existing revenue recognition guidance. The new standard includes a five-step revenue recognition model that requires the recognition of revenue to depict the transfer of promised goods to customers in an amount reflecting the consideration we expect to be entitled in exchange for those goods. The standard is required to be adopted using either the full retrospective approach or the modified retrospective approach. We will adopt this new standard in the first quarter of 2018 using the modified retrospective approach. Among other things, the standard requires enhanced disclosures about revenue and provides guidance for transactions that were not previously addressed comprehensively. As of December 31, 2017, we have completed our evaluation of the new standard and have concluded that the cumulative effect of adoption will not have a material impact on our consolidated financial statements. The adoption will result in a change in the gross versus net presentation of certain revenue transactions in our consolidated statements of operations, but any such presentation changes would not have an impact on income (loss) from operations, earnings per share or cash flows. In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU 2016-01, Financial Instruments-Overall (Subtopic 825-10) : Recognition and Measurement of Financial Assets and Financial Liabilities. ASU 2016-01 will require equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) to be measured at fair value with changes in fair value recognized in net income. In addition, ASU 2016-01 changes certain disclosure requirements and other aspects of GAAP. We will adopt ASU 2016-01 on January 1, 2018. As of December 31, 2017, we have completed our evaluation of the new standard and have concluded that the effect on our financial statements is not material, but may be material in the future if we were to sell a portion of our equity method investments such that we no longer had the ability to exercise significant influence over the operating and financial activities of the investee. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) which updated lease accounting guidance requiring lessees to recognize most leases, including operating leases, on the balance sheet as a right of use asset and lease liability. The accounting standards update is effective for fiscal years, and interim periods within those years, beginning after December 15, 2018 and will be adopted using a modified retrospective transition method, which requires applying the new standard to leases that exist or are entered into after the beginning of the earliest period in the financial statements. Early adoption is permitted, but we do not plan to early adopt . The standard will not apply to our leases of mineral rights. We are continuing to evaluate the impact of this standard on our consolidated financial statements and related disclosures. In August 2017, the FASB issued ASU 2017-12 , Derivatives and Hedging (Topic 815) which makes significant changes to the current hedge accounting guidance. The new standard eliminates the requirement to separately measure and report hedge ineffectiveness and generally requires the entire change in the fair value of a hedging instrument to be presented in the same income statement line as the hedged item. The new standard also eases certain documentation and assessment requirements and modifies the accounting for components excluded from the assessment of hedge effectiveness. The new standard update is effective for annual and interim periods beginning after December 15, 2018, including interim periods within those annual periods. Early adoption is permitted, but we do not plan to early adopt. We are currently evaluating the impact of this standard on our consolidated financial statements and related disclosures.

Impairments (Policies)

Impairments (Policies)	12 Months Ended
	Dec. 31, 2017
Asset Impairment Charges [Abstract]
Impairments of Proved Oil and Natural Gas Properties	Our proved oil and natural gas properties are subject to quarterly full cost ceiling tests. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. Estimated future net revenues for the quarterly ceiling limit are calculated using the average of commodity prices on the first day of the month over the trailing 12-month period.

Basis of Presentation and Sum32

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Schedule of Accounts, Notes, Loans and Financing Receivable	Accounts receivable as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) Oil, natural gas and NGL sales $ 959 $ 840 Joint interest 209 156 Other 184 93 Allowance for doubtful accounts (30 ) (32 ) Total accounts receivable, net $ 1,322 $ 1,057
Schedule of Capitalized Costs of Unproved Properties Excluded from Amortization	The table below sets forth the cost of unproved properties excluded from the amortization base as of December 31, 2017 and the year in which the associated costs were incurred: Year of Acquisition 2017 2016 2015 Prior Total ($ in millions) Leasehold cost $ 70 $ 89 $ 87 $ 2,368 $ 2,614 Exploration cost 50 9 33 11 103 Capitalized interest 154 116 120 377 767 Total $ 274 $ 214 $ 240 $ 2,756 $ 3,484

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2017
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Antidilutive Securities Excluded From Computation Of Earnings Per Share	Shares of common stock for the following dilutive securities were excluded from the calculation of diluted EPS as the effect was antidilutive. Years Ended December 31, 2017 2016 2015 (in millions) Common stock equivalent of our preferred stock outstanding 60 63 113 Common stock equivalent of our convertible senior notes outstanding 146 146 — Common stock equivalent of our preferred stock outstanding prior to exchange 1 37 — Participating securities 1 1 1

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Schedule of Debt	Our long-term debt consisted of the following as of December 31, 2017 and 2016: December 31, 2017 December 31, 2016 Principal Amount Carrying Principal Carrying ($ in millions) 6.25% euro-denominated senior notes due 2017 $ — $ — $ 258 $ 258 6.5% senior notes due 2017 — — 134 134 7.25% senior notes due 2018 44 44 64 64 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 437 437 780 780 6.875% senior notes due 2020 227 227 279 278 6.125% senior notes due 2021 548 548 550 550 5.375% senior notes due 2021 267 267 270 270 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 (a) 1,416 1,895 2,419 3,409 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,300 1,290 1,000 985 5.5% convertible senior notes due 2026 (b)(c)(d) 1,250 837 1,250 811 8.00% senior notes due 2027 1,300 1,298 — — 2.75% contingent convertible senior notes due 2035 (d) — — 2 2 2.5% contingent convertible senior notes due 2037 (d) — — 114 112 2.25% contingent convertible senior notes due 2038 (b)(d) 9 8 200 180 Term loan due 2021 1,233 1,233 1,500 1,500 Revolving credit facility 781 781 — — Debt issuance costs — (63 ) — (64 ) Interest rate derivatives — 2 — 3 Total debt, net 9,981 9,973 9,989 10,441 Less current maturities of long-term debt, net (e) (53 ) (52 ) (506 ) (503 ) Total long-term debt, net $ 9,928 $ 9,921 $ 9,483 $ 9,938 ___________________________________________ (a) The carrying amounts as of December 31, 2017 and 2016, include premium amounts of $479 million and $990 million , respectively, associated with a troubled debt restructuring. The premium is being amortized based on the effective yield method. (b) We are required to account for the liability and equity components of our convertible debt instruments separately and to reflect interest expense through the first demand repurchase date, as applicable, at the interest rate of similar nonconvertible debt at the time of issuance. The applicable rates for our 2.25% Contingent Convertible Senior Notes due 2038 and our 5.5% Convertible Senior Notes due 2026 are 8.0% and 11.5% , respectively. (c) The conversion and redemption provisions of our convertible senior notes are as follows: Optional Conversion by Holders . Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. The notes may be converted into cash, our common stock, or a combination of cash and common stock, at our election. One triggering circumstance is when the price of our common stock exceeds a threshold amount during a specified period in a fiscal quarter. Convertibility based on common stock price is measured quarterly. During the fourth quarter of 2017, the price of our common stock was below the threshold level and, as a result, the holders do not have the option to convert their notes in the first quarter of 2018 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 year ended December 31, 2017. Upon conversion of a convertible senior note, the holder will receive cash, common stock or a combination of cash and common stock, at our election, according to the conversion rate specified in the indenture. The common stock price conversion threshold amount for the convertible senior notes is 130% of the conversion price of $8.568 . Optional Redemption by the Company . We may redeem the convertible senior notes for cash on or after September 15, 2019 , if the price of our common stock exceeds 130% of the conversion price during a specified period at a redemption price of 100% of the principal amount of the notes. Holders’ Demand Repurchase Rights. The holders of our convertible senior notes may require us to repurchase, in cash, all or a portion of their notes at 100% of the principal amount of the notes upon certain fundamental changes. (d) The carrying amounts as of December 31, 2017 and 2016, are reflected net of discounts of $414 million and $461 million , respectively, associated with the equity component of our convertible and contingent convertible senior notes. This amount is being amortized based on the effective yield method through the first demand repurchase date as applicable. (e) As of December 31, 2017, current maturities of long-term debt, net includes our 7.25% Senior Notes due December 2018 and our 2.25% Contingent Convertible Notes due 2038 Notes. Deb
Schedule of Maturities of Long-term Debt	maturities for the next five years and thereafter are as follows: Principal Amount of Debt Securities ($ in millions) 2018 $ 53 2019 1,161 2020 664 2021 2,048 2022 1,867 Thereafter 4,188 Total $ 9,981 De
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: December 31, 2017 December 31, 2016 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 52 $ 53 $ 503 $ 511 Long-term debt (Level 1) $ 2,633 $ 2,629 $ 3,271 $ 3,216 Long-term debt (Level 2) $ 7,286 $ 7,301 $ 6,664 $ 6,654

Contingencies and Commitments35

Contingencies and Commitments (Tables)	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Operating Leases 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: December 31, ($ in millions) 2018 $ 1,079 2019 1,051 2020 979 2021 883 2022 771 2023 – 2035 4,404 Total $ 9,167 The aggregate undiscounted minimum future lease payments are presented below: December 31, 2017 ($ in millions) 2018 $ 6 2019 5 2020 2 2021 1 Total $ 14 As of December 31, 2017, the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $23 million .
Gathering, Processing and Transportation Commitments	The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: December 31, ($ in millions) 2018 $ 1,079 2019 1,051 2020 979 2021 883 2022 771 2023 – 2035 4,404 Total $ 9,167 The aggregate undiscounted minimum future lease payments are presented below: December 31, 2017 ($ in millions) 2018 $ 6 2019 5 2020 2 2021 1 Total $ 14 As of December 31, 2017, the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $23 million .
Drilling Contracts Commitments	The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: December 31, ($ in millions) 2018 $ 1,079 2019 1,051 2020 979 2021 883 2022 771 2023 – 2035 4,404 Total $ 9,167 The aggregate undiscounted minimum future lease payments are presented below: December 31, 2017 ($ in millions) 2018 $ 6 2019 5 2020 2 2021 1 Total $ 14 As of December 31, 2017, the aggregate undiscounted minimum future payments under these drilling service commitments were approximately $23 million .

Other Liabilities (Tables)

Other Liabilities (Tables)	12 Months Ended
	Dec. 31, 2017
Other Liabilities Disclosure [Abstract]
Other Current Liabilities	Other current liabilities as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) Revenues and royalties due others $ 612 $ 543 Accrued drilling and production costs 216 169 Joint interest prepayments received 74 71 Accrued compensation and benefits 214 239 Other accrued taxes 43 32 Bank of New York Mellon legal accrual (a) — 440 Other 296 304 Total other current liabilities $ 1,455 $ 1,798 ____________________________________________ (a) In 2017, we received notice from the U.S. Supreme Court that it would not review our appeal of the decision by the U.S. District Court for the Southern District of New York regarding the early redemption of our 6.775% Senior Notes due 2019. As a result of the decision, we paid $441 million with cash on hand and borrowings under the credit facility, and the related supersedeas bond was released.
Other Long-Term Liabilities	Other long-term liabilities as of December 31, 2017 and 2016 are detailed below: December 31, 2017 2016 ($ in millions) CHK Utica ORRI conveyance obligation (a) $ 156 $ 160 Unrecognized tax benefits 101 97 Other 97 126 Total other long-term liabilities $ 354 $ 383 ____________________________________________ (a) The CHK Utica, L.L.C. investors’ right to receive proportionately an overriding royalty interest (ORRI) in the first 1,500 net wells drilled on certain of our Utica Shale leasehold runs through 2023. We have the right to repurchase the ORRIs in the remaining net wells once we have drilled a minimum of 1,300 net wells. As of December 31, 2017, we had drilled 572 net wells. The obligation to deliver future ORRIs, which has been recorded as a liability, will be settled through the future conveyance of the underlying ORRIs to the investors on a net-well basis. As of December 31, 2017 and 2016, approximately $30 million and $43 million of the total ORRI obligations are recorded in other current liabilities, respectively.

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The components of the income tax provision (benefit) for each of the periods presented below are as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Current Federal $ (14 ) $ (14 ) $ — State 5 (5 ) (36 ) Current Income Taxes (9 ) (19 ) (36 ) Deferred Federal 13 (147 ) (4,385 ) State (2 ) (24 ) (42 ) Deferred Income Taxes 11 (171 ) (4,427 ) Total $ 2 $ (190 ) $ (4,463 )
Schedule of Effective Income Tax Rate Reconciliation	The effective income tax expense (benefit) differed from the computed "expected" federal income tax expense on earnings before income taxes for the following reasons: Years Ended December 31, 2017 2016 2015 ($ in millions) Income tax expense (benefit) at the federal statutory rate (35%) $ 333 $ (1,606 ) $ (6,684 ) State income taxes (net of federal income tax benefit) 66 (30 ) (406 ) Remeasurement of deferred tax assets and liabilities 1,266 — — Change in valuation allowance (1,676 ) 1,423 2,727 Other 13 23 (100 ) Total $ 2 $ (190 ) $ (4,463 )
Schedule of Deferred Tax Assets and Liabilities	The tax-effected temporary differences, tax credits and net operating loss carryforwards that comprise our deferred taxes are as follows: Years Ended December 31, 2017 2016 ($ in millions) Deferred tax liabilities: Volumetric production payments $ (129 ) $ (223 ) Other (20 ) (62 ) Deferred tax liabilities (149 ) (285 ) Deferred tax assets: Property, plant and equipment 1 593 Net operating loss carryforwards 2,248 2,587 Carrying value of debt 161 539 Asset retirement obligations 42 98 Investments 161 275 Derivative instruments 17 161 Accrued liabilities 125 319 Other 71 118 Deferred tax assets 2,826 4,690 Valuation allowance (2,674 ) (4,389 ) Net deferred tax assets 152 301 Net deferred tax assets $ 3 $ 16
Schedule of Unrecognized Tax Benefits Roll Forward	A reconciliation of the beginning and ending balances of unrecognized tax benefits is as follows: 2017 2016 2015 ($ in millions) Unrecognized tax benefits at beginning of period $ 202 $ 280 $ 303 Additions based on tax positions related to the current year — — 27 Additions to tax positions of prior years 4 33 — Settlements (100 ) (111 ) — Reductions to tax positions of prior years — — (50 ) Unrecognized tax benefits at end of period $ 106 $ 202 $ 280

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Schedule of Common Stock Outstanding Roll Forward	A summary of the changes in our common shares issued for the years ended December 31, 2017, 2016 and 2015 is detailed below: Years Ended December 31, 2017 2016 2015 (in thousands) Shares issued as of January 1 896,279 664,796 664,944 Exchange of convertible notes — 55,428 — Exchange of senior notes — 53,924 — Exchange/conversion of preferred stock 9,966 120,186 — Restricted stock issuances (net of forfeitures and cancellations) 2,488 1,945 (163 ) Stock option exercises — — 15 Shares issued as of December 31 908,733 896,279 664,796
Schedule of Preferred Stock Outstanding Roll Forward	Following is a summary of our preferred stock, including the primary conversion terms as of December 31, 2017: Preferred Stock Series Issue Date Liquidation Preference per Share Holder's Conversion Right Conversion Rate Conversion Price Company's Conversion Right From Company's Market Conversion Trigger (a) 5.75% cumulative convertible non-voting May and June 2010 $ 1,000 Any time 39.6858 $ 25.1979 May 17, 2015 $ 32.7573 5.75% (series A) cumulative convertible non-voting May 2010 $ 1,000 Any time 38.3508 $ 26.0751 May 17, 2015 $ 33.8976 4.50% cumulative convertible September 2005 $ 100 Any time 2.4561 $ 40.7152 September 15, 2010 $ 52.9298 5.00% cumulative convertible (series 2005B) November 2005 $ 100 Any time 2.7745 $ 36.0431 November 15, 2010 $ 46.8560 ___________________________________________ (a) Convertible at the Company's option if the trading price of the Company's common stock equals or exceeds the trigger price for a specified time period or after the applicable conversion date if there are less than 250,000 shares of 4.50% or 5.00% (Series 2005B) preferred stock outstanding or 25,000 shares of 5.75% or 5.75% (Series A) preferred stock outstanding. Outstanding shares of our preferred stock for the years ended December 31, 2017, 2016 and 2015 are detailed below: 5.75% 5.75% (A) 4.50% 5.00% (2005B) (in thousands) Shares outstanding as of January 1, 2017 843 476 2,559 1,962 Preferred stock conversions/exchanges (a) (73 ) (13 ) — (151 ) Shares outstanding as of December 31, 2017 770 463 2,559 1,811 Shares outstanding as of January 1, 2016 1,497 1,100 2,559 2,096 Preferred stock conversions/exchanges (b) (654 ) (624 ) — (134 ) Shares outstanding as of December 31, 2016 843 476 2,559 1,962 Shares outstanding as of January 1, 2015 and December 31, 2015 1,497 1,100 2,559 2,096 ____________________________________________ (a) During 2017, holders of our 5.75% Cumulative Convertible Preferred Stock exchanged 72,600 shares into 7,442,156 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock exchanged 12,500 shares into 1,205,923 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged 150,948 shares into 1,317,756 shares of common stock. In connection with the exchanges, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $41 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share. (b) During 2016, holders of our 5.75% Cumulative Convertible Preferred Stock converted 653,872 shares into 59,141,429 shares of common stock, holders of our 5.75% (Series A) Cumulative Convertible Preferred Stock converted 624,137 shares into 60,032,734 shares of common stock and holders of our 5.00% (Series 2005B) Cumulative Convertible Preferred Stock exchanged or converted 134,000 shares into 1,012,032 shares of common stock. In connection with the exchanges noted above, we recognized a loss equal to the excess of the fair value of all common stock issued in exchange for the preferred stock over the fair value of the common stock issuable pursuant to the original terms of the preferred stock. The loss of $428 million is reflected as a reduction to net income available to common stockholders for the purpose of calculating earnings per common share.
Schedule of Accumulated Other Comprehensive Income (Loss)	For the years ended December 31, 2017 and 2016, changes in accumulated other comprehensive income (loss) for cash flow hedges, net of tax, are detailed below: Years Ended December 31, 2017 2016 ($ in millions) Balance, as of January 1 $ (96 ) $ (99 ) Other comprehensive income (loss) before reclassifications 5 (13 ) Amounts reclassified from accumulated other comprehensive income 34 16 Net other comprehensive income (loss) 39 3 Balance, as of December 31 $ (57 ) $ (96 )
Schedule of Error Corrections and Prior Period Adjustments	During our review of the carrying amount of the Trust’s noncontrolling interests, we identified errors related to the allocation of impairment expense between Chesapeake and the Trust’s noncontrolling interests during previously reported periods. We have determined that these errors are immaterial to previously issued financial statements and therefore, have revised the previously reported financial statements below. We have also determined that these errors did not relate to periods prior to 2015. December 31, 2016 CONSOLIDATED BALANCE SHEETS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (17,603 ) $ 129 $ (17,474 ) Total Chesapeake stockholders’ equity (deficit) $ (1,460 ) $ 129 $ (1,331 ) Noncontrolling interests $ 257 $ (129 ) $ 128 Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Net (income) loss attributable to noncontrolling interest $ (2 ) $ 11 $ 9 Net income (loss) attributable to Chesapeake $ (4,401 ) $ 11 $ (4,390 ) Net income (loss) available to common stockholders $ (4,926 ) $ 11 $ (4,915 ) Loss per common share basic $ (6.45 ) $ 0.02 $ (6.43 ) Loss per common share diluted $ (6.45 ) $ 0.02 $ (6.43 ) Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF OPERATIONS As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Net (income) loss attributable to noncontrolling interest $ (50 ) $ 118 $ 68 Net income (loss) attributable to Chesapeake $ (14,685 ) $ 118 $ (14,567 ) Net income (loss) available to common stockholders $ (14,856 ) $ 118 $ (14,738 ) Loss per common share basic $ (22.43 ) $ 0.17 $ (22.26 ) Loss per common share diluted $ (22.43 ) $ 0.17 $ (22.26 ) Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Comprehensive (income) loss attributable to noncontrolling interests $ (2 ) $ 11 $ 9 Comprehensive income (loss) attributable to Chesapeake $ (4,398 ) $ 11 $ (4,387 ) Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Comprehensive (income) loss attributable to noncontrolling interests $ (50 ) $ 118 $ 68 Comprehensive income (loss) attributable to Chesapeake $ (14,641 ) $ 118 $ (14,523 ) Year Ended December 31, 2016 CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (17,603 ) $ 129 $ (17,474 ) Noncontrolling interests $ 257 $ (129 ) $ 128 Year Ended December 31, 2015 CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY As Previously Reported Revision Adjustment As Revised ($ in millions except per share data) Accumulated deficit $ (13,202 ) $ 118 $ (13,084 ) Noncontrolling interests $ 259 $ (118 ) $ 141

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Share-Based Compensation, Restricted Stock and Restricted Stock Units Activity	A summary of the changes in unvested restricted stock during 2017, 2016 and 2015 is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value (in thousands) Unvested restricted stock as of January 1, 2017 9,092 $ 11.39 Granted 9,872 $ 5.40 Vested (4,573 ) $ 13.73 Forfeited (1,213 ) $ 8.32 Unvested restricted stock as of December 31, 2017 13,178 $ 6.37 Unvested restricted stock as of January 1, 2016 10,455 $ 17.31 Granted 4,604 $ 4.58 Vested (4,692 ) $ 17.23 Forfeited (1,275 ) $ 13.91 Unvested restricted stock as of December 31, 2016 9,092 $ 11.39 Unvested restricted stock as of January 1, 2015 10,091 $ 21.20 Granted 7,095 $ 13.90 Vested (4,157 ) $ 21.70 Forfeited (2,574 ) $ 16.98 Unvested restricted stock as of December 31, 2015 10,455 $ 17.31
Equity-Classified Share-Based Payment Award Valuation Assumptions	utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 83.97 % Risk-free interest rate 1.89 % Dividend yield for value of awards — % The Company used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in 2017: Expected option life – years 6.0 Volatility 62.42 % Risk-free interest rate 2.17 % Dividend yield — %
Schedule of Share-Based Compensation, Stock Options, Activity	The following table provides information related to stock option activity for 2017, 2016 and 2015: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2017 8,593 $ 11.88 7.22 $ 14 Granted 9,226 $ 5.45 Exercised — $ — $ — Expired (435 ) $ 18.51 Forfeited (1,099 ) $ 9.12 Outstanding as of December 31, 2017 16,285 $ 8.25 7.73 $ 1 Exercisable as of December 31, 2017 4,474 $ 15.15 5.26 $ — Outstanding as of January 1, 2016 5,377 $ 19.37 5.80 $ — Granted 4,932 $ 3.71 Exercised — $ — $ — Expired (771 ) $ 19.46 Forfeited (945 ) $ 5.66 Outstanding as of December 31, 2016 8,593 $ 11.88 7.22 $ 14 Exercisable as of December 31, 2016 2,844 $ 19.60 5.53 $ — Outstanding as of January 1, 2015 4,599 $ 19.55 7.03 $ 5 Granted 1,208 $ 18.37 Exercised (14 ) $ 18.13 $ — Expired (416 ) $ 18.46 Forfeited — $ — Outstanding as of December 31, 2015 5,377 $ 19.37 5.80 $ — Exercisable as of December 31, 2015 2,045 $ 19.61 5.07 $ — ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.
Equity-Classified Stock-Based Compensation	We recognized the following compensation costs related to restricted stock and stock options for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ 37 $ 38 $ 43 Oil and natural gas properties 12 16 23 Oil, natural gas and NGL production expenses 12 13 18 Marketing, gathering and compression expenses — 1 5 Total restricted stock and stock option compensation $ 61 $ 68 $ 89 We recognized the following compensation costs (credits) related to PSUs for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ (4 ) $ 14 $ (19 ) Restructuring and other termination costs — 1 (19 ) Marketing, gathering and compression — — (1 ) Oil and natural gas properties — — (2 ) Total PSU compensation $ (4 ) $ 15 $ (41 )
Liability-Classified Share-Based Payment Award Valuation Assumptions	utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the PSUs. Volatility 83.97 % Risk-free interest rate 1.89 % Dividend yield for value of awards — % The Company used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in 2017: Expected option life – years 6.0 Volatility 62.42 % Risk-free interest rate 2.17 % Dividend yield — %
Schedule of Nonvested Performance-based Units Activity	The following table presents a summary of our 2017, 2016 and 2015 PSU awards: Grant Date Fair Value December 31, 2017 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2017 Awards: Payable 2020 1,217,774 $ 8 $ 5 $ 3 2016 Awards: Payable 2019 2,348,893 $ 10 $ 9 $ 8 2015 Awards: Payable 2018 629,694 $ 13 $ 1 $ 1
Liability-Classified Stock-Based Compensation	We recognized the following compensation costs related to restricted stock and stock options for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ 37 $ 38 $ 43 Oil and natural gas properties 12 16 23 Oil, natural gas and NGL production expenses 12 13 18 Marketing, gathering and compression expenses — 1 5 Total restricted stock and stock option compensation $ 61 $ 68 $ 89 We recognized the following compensation costs (credits) related to PSUs for the years ended December 31, 2017, 2016 and 2015: Years Ended December 31, 2017 2016 2015 ($ in millions) General and administrative expenses $ (4 ) $ 14 $ (19 ) Restructuring and other termination costs — 1 (19 ) Marketing, gathering and compression — — (1 ) Oil and natural gas properties — — (2 ) Total PSU compensation $ (4 ) $ 15 $ (41 )

Derivative and Hedging Activi40

Derivative and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts of Outstanding Derivative Positions	The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of December 31, 2017 and 2016 are provided below: December 31, 2017 December 31, 2016 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 21 $ (151 ) 23 $ (140 ) Three-way collars 2 (10 ) — — Call options — — 5 (1 ) Call swaptions 2 (13 ) — — Basis protection swaps 11 (9 ) — — Total oil 36 (183 ) 28 (141 ) Natural gas (tbtu): Fixed-price swaps 532 149 719 (349 ) Collars 47 11 60 (9 ) Call options 110 (3 ) 114 — Basis protection swaps 65 (7 ) 31 (5 ) Total natural gas 754 150 924 (363 ) NGL (mmgal): Fixed-price swaps 33 (2 ) 53 — Total estimated fair value $ (35 ) $ (504 )
Schedule Of Derivative Instruments In Condensed Consolidated Balance Sheets	The following table presents the fair value and location of each classification of derivative instrument included in the consolidated balance sheets as of December 31, 2017 and 2016 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of December 31, 2017 Commodity Contracts: Short-term derivative asset $ 157 $ (130 ) $ 27 Short-term derivative liability (188 ) 130 (58 ) Long-term derivative liability (4 ) — (4 ) Total commodity contracts (35 ) — (35 ) Total derivatives $ (35 ) $ — $ (35 ) As of December 31, 2016 Commodity Contracts: Short-term derivative asset $ 1 $ (1 ) $ — Short-term derivative liability (490 ) 1 (489 ) Long-term derivative liability (15 ) — (15 ) Total commodity contracts (504 ) — (504 ) Foreign Currency Contracts: (a) Short-term derivative liability (73 ) — (73 ) Total foreign currency contracts (73 ) — (73 ) Total derivatives $ (577 ) $ — $ (577 ) ____________________________________________ (a) Designated as cash flow hedging instruments
Schedule of Derivative Instruments, Oil, Natural Gas and NGL Revenues	The components of marketing, gathering and compression revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 4,511 $ 4,881 $ 7,077 Losses on undesignated supply contract derivatives — (297 ) 296 Total marketing, gathering and compression revenues $ 4,511 $ 4,584 $ 7,373 The components of oil, natural gas and NGL revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Oil, natural gas and NGL revenues 4,574 3,866 4,767 Gains (losses) on undesignated oil, natural gas and NGL derivatives 445 (545 ) 661 Losses on terminated cash flow hedges (34 ) (33 ) (37 ) Total oil, natural gas and NGL revenues $ 4,985 $ 3,288 $ 5,391
Schedule of Derivative Instruments, Marketing, Gathering and Compression Revenues	The components of marketing, gathering and compression revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 4,511 $ 4,881 $ 7,077 Losses on undesignated supply contract derivatives — (297 ) 296 Total marketing, gathering and compression revenues $ 4,511 $ 4,584 $ 7,373 The components of oil, natural gas and NGL revenues for the years ended December 31, 2017, 2016 and 2015 are presented below: Years Ended December 31, 2017 2016 2015 ($ in millions) Oil, natural gas and NGL revenues 4,574 3,866 4,767 Gains (losses) on undesignated oil, natural gas and NGL derivatives 445 (545 ) 661 Losses on terminated cash flow hedges (34 ) (33 ) (37 ) Total oil, natural gas and NGL revenues $ 4,985 $ 3,288 $ 5,391
Interest Income And Interest Expense Disclosure	Years Ended December 31, 2017 2016 2015 ($ in millions) Marketing, gathering and compression revenues $ 4,511 $ 4,881 $ 7,077 Losses on undesignated supply contract derivatives — (297 ) 296 Total marketing, gathering and compression revenues $ 4,511 $ 4,584 $ 7,373
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 consolidated statements of stockholders’ equity related to our cash flow hedges is presented below: Years Ended December 31, 2017 2016 2015 Before After Before After Before After ($ in millions) Balance, beginning of period $ (153 ) $ (96 ) $ (160 ) $ (99 ) $ (231 ) $ (143 ) Net change in fair value 5 5 (27 ) (13 ) 32 20 Losses reclassified to income 34 34 34 16 39 24 Balance, end of period $ (114 ) $ (57 ) $ (153 ) $ (96 ) $ (160 ) $ (99 )
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 December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during 2017 and 2016 is presented below: Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 2 — Total purchases, issuances, sales and settlements: Settlements (7 ) — Balance, as of December 31, 2017 $ (15 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 6 (118 ) Total purchases, issuances, sales and settlements: Settlements 75 (33 ) Sales — (146 ) Balance, as of December 31, 2016 $ (10 ) $ — ___________________________________________ (a) Commodity Derivatives Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 2 $ 6 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (14 ) $ (7 ) $ — $ — 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 December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 )
Fair Value Inputs, Assets, Quantitative Information	The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of December 31, 2017 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 13.14% – 24.93% 22.43% $ (23 ) Natural gas trades Natural gas price volatility curves 18.82% – 82.61% 38.06% $ 8

Oil and Natural Gas Property 41

Oil and Natural Gas Property Transactions (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
VPP Transactions	As of December 31, 2017 , we had the following VPP outstanding: Volume Sold VPP # Date of VPP Location Proceeds Oil Natural Gas NGL Total ($ in millions) (mmbbl) (bcf) (mmbbl) (bcfe) 9 May 2011 Mid-Continent $ 853 1.7 138 4.8 177
VPP Volumes Produced During Period
VPP Volumes Remaining to Be Delivered	The volumes remaining to be delivered on behalf of our VPP buyers as of December 31, 2017 were as follows: Volume Remaining as of December 31, 2017 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 38 0.4 34.1 0.9 41.7

Other Property and Equipment Ot

Other Property and Equipment Other Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Other Property and Equipment Held for Use and Estimated Useful Lives	A summary by asset class of (gains) or losses on sales of fixed assets for the years ended December 31, 2017, 2016 and 2015 is as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Buildings and land $ (4 ) $ (1 ) $ 3 Natural gas compressors 1 (10 ) — Gathering systems and treating plants — — 1 Other — (1 ) — Total net (gains) losses on sales of fixed assets $ (3 ) $ (12 ) $ 4 A summary of other property and equipment held for use and the estimated useful lives thereof is as follows: December 31, Estimated Useful Life 2017 2016 ($ in millions) (in years) Buildings and improvements $ 1,093 $ 1,119 10 – 39 Computer equipment 345 337 5 Natural gas compressors 235 251 3 – 20 Land 126 139 Gathering systems and treating plants 2 2 20 Other 185 205 5 – 10 Total other property and equipment, at cost 1,986 2,053 Less: accumulated depreciation (672 ) (632 ) Total other property and equipment, net $ 1,314 $ 1,421
Other Property and Equipment Gains (Losses) on Sales of Fixed Assets	A summary by asset class of (gains) or losses on sales of fixed assets for the years ended December 31, 2017, 2016 and 2015 is as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Buildings and land $ (4 ) $ (1 ) $ 3 Natural gas compressors 1 (10 ) — Gathering systems and treating plants — — 1 Other — (1 ) — Total net (gains) losses on sales of fixed assets $ (3 ) $ (12 ) $ 4 A summary of other property and equipment held for use and the estimated useful lives thereof is as follows: December 31, Estimated Useful Life 2017 2016 ($ in millions) (in years) Buildings and improvements $ 1,093 $ 1,119 10 – 39 Computer equipment 345 337 5 Natural gas compressors 235 251 3 – 20 Land 126 139 Gathering systems and treating plants 2 2 20 Other 185 205 5 – 10 Total other property and equipment, at cost 1,986 2,053 Less: accumulated depreciation (672 ) (632 ) Total other property and equipment, net $ 1,314 $ 1,421

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2017
Asset Impairment Charges [Abstract]
Details of Impairment of Long-Lived Assets Held and Used by Asset	A summary of our impairments of fixed assets by asset class and other charges for the years ended December 31, 2017, 2016 and 2015 is as follows: Years Ended December 31, 2017 2016 2015 ($ in millions) Barnett Shale exit costs $ — $ 645 $ — Devonian Shale exit costs — 142 — Gathering systems — 3 — Natural gas compressors — 21 21 Buildings and land 5 11 — Other charges 416 16 173 Total impairments of fixed assets and other $ 421 $ 838 $ 194

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) As of December 31, 2016 Derivative Assets (Liabilities): Commodity assets $ — $ 1 $ — $ 1 Commodity liabilities — (495 ) (10 ) (505 ) Foreign currency liabilities — (73 ) — (73 ) Total derivatives $ — $ (567 ) $ (10 ) $ (577 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during 2017 and 2016 is presented below: Commodity Derivatives Supply Contracts ($ in millions) Balance, as of January 1, 2017 $ (10 ) $ — Total gains (losses) (realized/unrealized): Included in earnings (a) 2 — Total purchases, issuances, sales and settlements: Settlements (7 ) — Balance, as of December 31, 2017 $ (15 ) $ — Balance, as of January 1, 2016 $ (91 ) $ 297 Total gains (losses) (realized/unrealized): Included in earnings (a) 6 (118 ) Total purchases, issuances, sales and settlements: Settlements 75 (33 ) Sales — (146 ) Balance, as of December 31, 2016 $ (10 ) $ — ___________________________________________ (a) Commodity Derivatives Marketing, Gathering and Compression Revenue 2017 2016 2017 2016 ($ in millions) Total gains (losses) included in earnings for the period $ 2 $ 6 $ — $ (118 ) Change in unrealized gains (losses) related to assets still held at reporting date $ (14 ) $ (7 ) $ — $ — 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 December 31, 2017 and 2016: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 ) As of December 31, 2016 Financial Assets (Liabilities): Other current assets $ 49 $ — $ — $ 49 Other current liabilities (51 ) — — (51 ) Total $ (2 ) $ — $ — $ (2 )

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The components of the change in our asset retirement obligations are shown below: Years Ended December 31, 2017 2016 ($ in millions) Asset retirement obligations, beginning of period $ 261 $ 473 Additions 5 4 Revisions (34 ) (58 ) Settlements and disposals (70 ) (182 ) Accretion expense 15 24 Asset retirement obligations, end of period 177 261 Less current portion 15 14 Asset retirement obligation, long-term $ 162 $ 247

Condensed Consolidating Finan46

Condensed Consolidating Financial Information Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2017
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidated Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEET AS OF DECEMBER 31, 2017 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 5 $ 1 $ 2 $ (3 ) $ 5 Other current assets 154 1,364 3 (1 ) 1,520 Intercompany receivable, net 8,697 436 — (9,133 ) — Total Current Assets 8,856 1,801 5 (9,137 ) 1,525 PROPERTY AND EQUIPMENT: Oil and natural gas properties at cost, based on full cost accounting, net 435 8,888 27 — 9,350 Other property and equipment, net — 1,314 — — 1,314 Property and equipment held for sale, net — 16 — — 16 Total Property and Equipment, Net 435 10,218 27 — 10,680 LONG-TERM ASSETS: Other long-term assets 52 168 — — 220 Investments in subsidiaries and intercompany advances 806 (146 ) — (660 ) — TOTAL ASSETS $ 10,149 $ 12,041 $ 32 $ (9,797 ) $ 12,425 CURRENT LIABILITIES: Current liabilities $ 190 $ 2,168 $ 2 $ (4 ) $ 2,356 Intercompany payable, net 433 8,648 52 (9,133 ) — Total Current Liabilities 623 10,816 54 (9,137 ) 2,356 LONG-TERM LIABILITIES: Long-term debt, net 9,921 — — — 9,921 Other long-term liabilities 101 419 — — 520 Total Long-Term Liabilities 10,022 419 — — 10,441 EQUITY: Chesapeake stockholders’ equity (deficit) (496 ) 806 (146 ) (660 ) (496 ) Noncontrolling interests — — 124 — 124 Total Equity (Deficit) (496 ) 806 (22 ) (660 ) (372 ) TOTAL LIABILITIES AND EQUITY $ 10,149 $ 12,041 $ 32 $ (9,797 ) $ 12,425
Condensed Consolidated Income Statements	CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS YEAR ENDED DECEMBER 31, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 4,962 $ 23 $ — $ 4,985 Marketing, gathering and compression — 4,511 — — 4,511 Total Revenues — 9,473 23 — 9,496 OPERATING EXPENSES: Oil, natural gas and NGL production — 562 — — 562 Oil, natural gas and NGL gathering, processing and transportation — 1,463 8 — 1,471 Production taxes — 88 1 — 89 Marketing, gathering and compression — 4,598 — — 4,598 General and administrative 1 259 2 — 262 Restructuring and other termination costs — — — — — Provision for legal contingencies, net (79 ) 41 — — (38 ) Oil, natural gas and NGL depreciation, depletion and amortization — 909 4 — 913 Depreciation and amortization of other assets — 82 — — 82 Impairments of fixed assets and other — 421 — — 421 Net gains on sales of fixed assets — (3 ) — — (3 ) Total Operating Expenses (78 ) 8,420 15 — 8,357 INCOME FROM OPERATIONS 78 1,053 8 — 1,139 OTHER INCOME (EXPENSE): Interest expense (424 ) (2 ) — — (426 ) Gains on purchases or exchanges of debt 233 — — — 233 Other income 1 8 — — 9 Equity in net earnings (losses) of subsidiary 1,063 4 — (1,067 ) — Total Other Income (Expense) 873 10 — (1,067 ) (184 ) INCOME BEFORE INCOME TAXES 951 1,063 8 (1,067 ) 955 INCOME TAX EXPENSE (BENEFIT) 2 — — — 2 NET INCOME 949 1,063 8 (1,067 ) 953 Net income attributable to noncontrolling interests — — (4 ) — (4 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 949 1,063 4 (1,067 ) 949 Other comprehensive income — 39 — — 39 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 949 $ 1,102 $ 4 $ (1,067 ) $ 988
Condensed Consolidated Cash Flow Statements	Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 5 $ 736 $ 14 $ (10 ) $ 745 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (2,186 ) — — (2,186 ) Acquisitions of proved and unproved properties — (285 ) — — (285 ) Proceeds from divestitures of proved and unproved properties — 1,249 — — 1,249 Additions to other property and equipment — (21 ) — — (21 ) Other investing activities — 55 — — 55 Net Cash Used In Investing Activities — (1,188 ) — — (1,188 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 7,771 — — — 7,771 Payments on revolving credit facility borrowings (6,990 ) — — — (6,990 ) Proceeds from issuance of senior notes, net 1,585 — — — 1,585 Cash paid to purchase debt (2,592 ) — — — (2,592 ) Cash paid for preferred stock dividends (183 ) — — — (183 ) Other financing activities (39 ) (5 ) (13 ) 32 (25 ) Intercompany advances, net (456 ) 456 — — — Net Cash Provided by (Used In) Financing Activities (904 ) 451 (13 ) 32 (434 ) Net increase (decrease) in cash and cash equivalents (899 ) (1 ) 1 22 (877 ) Cash and cash equivalents, beginning of period 904 2 1 (25 ) 882 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (3 ) $ 5

Basis of Presentation Basis of

Basis of Presentation Basis of Presentation and Summary of Significant Accounting Policies Accounts Receivable Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Oil, natural gas and NGL sales, receivables	$ 959	$ 840
Oil and Gas Joint Interest Billing Receivables, Current	209	156
Other Receivables	184	93
Allowance for Doubtful Accounts Receivable	(30)	(32)
Accounts Receivable, Net, Current	$ 1,322	$ 1,057

Basis of Presentation Basis o48

Basis of Presentation Basis of Presentation and Summary of Significant Accounting Policies Capitalized Costs of Unproved Properties Table (Details) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Acquisition Costs, Period Cost	$ 70	$ 89	$ 87	$ 2,368
Acquisition Costs, Cumulative	2,614
Exploration Costs, Period Cost	50	9	33	11
Exploration Costs, Cumulative	103
Capitalized Interest of Unproved Properties Excluded from Amortization	154	116	120	377
Capitalized Interest Of Unproved Properties Excluded From Amortization Cumulative	767
Capitalized Costs of Unproved Properties Excluded from Amortization, Period Cost	274	214	$ 240	$ 2,756
Unproved properties	$ 3,484	$ 4,802

Basis of Presentation and Sum49

Basis of Presentation and Summary of Significant Accounting Policies Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)Segment	Dec. 31, 2016USD ($)
Summary of Significant Accounting Policies [Table] [Line Items]
Number of Reportable Segments | Segment	1
Bank Overdrafts	$ 92	$ 77
Deferred Long-term Liability Charges	63	64
Gas Balancing Asset (Liability)	$ 5	(9)
Director [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Other Noncurrent Assets [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Unamortized Debt Issuance Expense	$ 22	$ 32
Minimum [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired	50.00%
Minimum [Member] | Employee [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Maximum [Member] | Employee [Member]
Summary of Significant Accounting Policies [Table] [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities Excluded from Computation of EPS Table (Details) - shares shares in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Convertible Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1	37	0
Convertible Debt Securities [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	146	146	0
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1	1	1
Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	60	63	113

Debt - Long-Term Debt Table (De

Debt - Long-Term Debt Table (Details) $ / shares in Units, $ in Millions	Oct. 13, 2017	Dec. 31, 2017USD ($)day$ / shares	Dec. 31, 2016USD ($)	Dec. 31, 2006$ / €
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 9,981	$ 9,989
Long-term Debt, Gross		9,973	10,441
Deferred Long-term Liability Charges		(63)	(64)
Debt, Current		53	506
Current Maturities of Long-term Debt, Net		(52)	(503)
Long-term Debt, Fair Value		9,928	9,483
Long-term Debt, Net		9,921	9,938
Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		0	0
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		2	3
8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Premium		479	990
5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 1,250
Debt Instrument, Interest Rate, Stated Percentage			5.50%
Senior Notes [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		0	$ 258
Long-term Debt, Gross		$ 0	$ 258
Senior Notes [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Cross Currency Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Derivative, Forward Exchange Rate | $ / €				1.3325
Debt Instrument, Interest Rate, Stated Percentage		6.25%	6.25%
Senior Notes [Member] | 6.5% Senior Notes Due 2017 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 0	$ 134
Long-term Debt, Gross		$ 0	134
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Senior Notes [Member] | 7.25% Senior Notes Due 2018 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 44	64
Long-term Debt, Gross		$ 44	64
Debt Instrument, Interest Rate, Stated Percentage		7.25%
Senior Notes [Member] | Floating Rate Senior Notes Due 2019 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 380	380
Long-term Debt, Gross		380	380
Senior Notes [Member] | 6.625% Senior Notes Due 2020 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		437	780
Long-term Debt, Gross		$ 437	780
Debt Instrument, Interest Rate, Stated Percentage		6.625%
Senior Notes [Member] | 6.875% Senior Notes Due 2020 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 227	279
Long-term Debt, Gross		$ 227	278
Debt Instrument, Interest Rate, Stated Percentage		6.875%
Senior Notes [Member] | 6.125% Senior Notes Due 2021 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 548	550
Long-term Debt, Gross		$ 548	550
Debt Instrument, Interest Rate, Stated Percentage		6.125%
Senior Notes [Member] | 5.375% Senior Notes Due 2021 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 267	270
Long-term Debt, Gross		$ 267	270
Debt Instrument, Interest Rate, Stated Percentage		5.375%
Senior Notes [Member] | 4.875% Senior Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 451	451
Long-term Debt, Gross		$ 451	451
Debt Instrument, Interest Rate, Stated Percentage		4.875%
Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,416	2,419
Long-term Debt, Gross		1,895	3,409
Debt Instrument, Unamortized Premium		$ 374
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Senior Notes [Member] | 5.75% Senior Notes Due 2023 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 338	338
Long-term Debt, Gross		$ 338	338
Debt Instrument, Interest Rate, Stated Percentage		5.75%
Senior Notes [Member] | 8.00% Senior Notes Due 2025 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,300	1,000
Long-term Debt, Gross		$ 1,290	985
Debt Instrument, Redemption Price, Percentage		98.52%
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,300	0
Long-term Debt, Gross		$ 1,298	0
Debt Instrument, Redemption Price, Percentage	99.75%	108.00%
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed		35.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,250	1,250
Long-term Debt, Gross		$ 837	811
Debt Instrument, Interest Rate, Stated Percentage		5.50%
Debt Instrument, Interest Rate, Effective Percentage		11.50%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member] | Optional Conversion by Holders [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Convertible, Terms of Conversion Feature | day		5
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger		130.00%
Debt Instrument, Convertible, Conversion Price | $ / shares		$ 8.568
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed		100.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member] | Optional Redemption by the Company [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Convertible, Threshold Percentage of Stock Price Trigger		130.00%
Debt Instrument, Date of First Required Payment		Sep. 15, 2019
Debt Instrument, Redemption Price, Percentage		100.00%
Convertible Debt [Member] | 2.75% Contingent Convertible Senior Notes Due 2035 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 0	2
Long-term Debt, Gross		$ 0	2
Debt Instrument, Interest Rate, Stated Percentage		2.75%
Convertible Debt [Member] | 2.5% Contingent Convertible Senior Notes Due 2037 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 0	114
Long-term Debt, Gross		$ 0	112
Debt Instrument, Interest Rate, Stated Percentage		2.50%
Convertible Debt [Member] | 2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 9	200
Long-term Debt, Gross		$ 8	180
Debt Instrument, Interest Rate, Stated Percentage		2.25%
Debt Instrument, Interest Rate, Effective Percentage		8.00%
Convertible Debt [Member] | All Convertible and All Contingent Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount		$ 414	461
Term Loan [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		1,233	1,500
Long-term Debt, Gross		$ 1,233	1,500
Debt Instrument, Term		5 years
Line of Credit [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 781	0
Long-term Line of Credit		$ 781	$ 0

Debt - Long Term Debt Table (Ph

Debt - Long Term Debt Table (Phantom) (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2016
Term Loan [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument Maturity Date	Aug. 23, 2021
6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member] | Cross Currency Interest Rate Contract [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.25%		6.25%
Debt Instrument Maturity Date	Jan. 15, 2017
6.5% Senior Notes Due 2017 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Debt Instrument Maturity Date	Aug. 15, 2017
7.25% Senior Notes Due 2018 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.25%
Debt Instrument Maturity Date	Dec. 15, 2018
Floating Rate Senior Notes Due 2019 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument Maturity Date	Apr. 15, 2019
6.625% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.625%
Debt Instrument Maturity Date	Aug. 15, 2020
6.875% Senior Notes Due 2020 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.875%
Debt Instrument Maturity Date	Nov. 15, 2020
6.125% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.125%
Debt Instrument Maturity Date	Feb. 15, 2021
5.375% Senior Notes Due 2021 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.375%
Debt Instrument Maturity Date	Jun. 15, 2021
4.875% Senior Notes Due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.875%
Debt Instrument Maturity Date	Apr. 15, 2022
8.00% Senior Secured Second Lien Notes Due 2022 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%
Debt Instrument Maturity Date	Dec. 15, 2022
5.75% Senior Notes Due 2023 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Debt Instrument Maturity Date	Mar. 15, 2023
8.00% Senior Notes Due 2025 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%
Debt Instrument Maturity Date	Jan. 15, 2025
5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.50%
5.5% Convertible Senior Notes Due 2026 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument Maturity Date	Jun. 15, 2026
8.00% Senior Notes Due 2027 [Member] | Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%
Debt Instrument Maturity Date	Jun. 15, 2027
2.75% Contingent Convertible Senior Notes Due 2035 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.75%
Debt Instrument Maturity Date	Nov. 15, 2035
2.5% Contingent Convertible Senior Notes Due 2037 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Debt Instrument Maturity Date	May 15, 2037
2.25% Contingent Convertible Senior Notes Due 2038 [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument Maturity Date	Dec. 15, 2038
Maximum [Member] | First Lien [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital	0.65
Maximum [Member] | Scenario, Forecast [Member] | First Lien [Member] | Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		0.65

Debt Debt - Debt Maturities Tab

Debt Debt - Debt Maturities Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 53
Long-term Debt, Maturities, Repayments of Principal in Year Two	1,161
Long-term Debt, Maturities, Repayments of Principal in Year Three	664
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,048
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,867
Long-term Debt, Maturities, Repayments of Principal after Year Five	4,188
Debt Instrument, Face Amount	$ 9,981	$ 9,989

Debt Debt - Debt Issuances and

Debt Debt - Debt Issuances and Retirements Narrative (Details) - USD ($) $ in Millions	Oct. 13, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 9,981	$ 9,989
Cash Paid to Purchase Debt		2,592	2,734	$ 508
Gains (Losses) on Purchases or Exchanges of Debt		233	236	$ 279
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt			445
Income Tax Effects Allocated Directly to Equity, Equity Transactions			165
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt, Subsequent Adjustments			26
Income Tax Effects Allocated Directly to Equity, Other			10
8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Unamortized Premium		479	990
8.00% Senior Notes Due 2025 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 1,000
Debt Instrument, Interest Rate, Stated Percentage			8.00%
Proceeds from Issuance of Long-term Debt			$ 975
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed			35.00%
Debt Instrument, Redemption Price, Percentage			108.00%
5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 1,250
Debt Instrument, Interest Rate, Stated Percentage			5.50%
Proceeds from Issuance of Long-term Debt			$ 1,235
Senior Notes [Member] | 8.00% Senior Notes Due 2027 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,300	$ 0
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Debt Instrument, Redemption, Description		Some or all of the notes may be redeemed at any time prior to June 15, 2022, subject to a make-whole premium. We also may redeem some or all of the notes at any time on or after June 15, 2022, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes	Some or all of the notes may be redeemed at any time prior to January 15, 2020, subject to a make-whole premium. In addition, we may redeem some or all of the notes at any time on or after January 15, 2020, at the applicable redemption price in accordance with the terms of the notes and the indenture and supplemental indenture governing the notes.
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed		35.00%
Debt Instrument, Redemption Period, Start Date		Jun. 15, 2020
Debt Instrument, Redemption Price, Percentage	99.75%	108.00%
Senior Notes [Member] | New Eight Point Zero Zero Percent Senior Notes Due Two Thousand Twenty Five [Member] [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 300
Proceeds from Issuance of Senior Long-term Debt		$ 301
Debt Instrument, Redemption Price, Percentage		101.25%
Senior Notes [Member] | 8.00% Senior Notes Due 2025 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,300	$ 1,000
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Debt Instrument, Redemption Price, Percentage		98.52%
Senior Notes [Member] | 8.00% Senior Secured Second Lien Notes Due 2022 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,416	2,419
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Debt Instrument, Unamortized Premium		$ 374
Senior Notes [Member] | 5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		1,285
Term Loan [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		1,233	1,500
Senior Notes, Sr. Secured Notes, Contingent Convertible Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount		2,389
Cash Paid to Purchase Debt		$ 2,592
Senior Notes and Contingent Convertible Senior Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount			2,884
Cash Paid to Purchase Debt			2,734
Senior Notes and Contingent Convertible Senior Notes [Member] | Privately Negotiated Exchanges for Common Stock [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Repurchase Amount			$ 577
Debt Conversion, Converted Instrument, Shares Issued			109,351,707
Debt Instrument, Redemption, Period Three [Member] | 8.00% Senior Notes Due 2025 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Date of First Required Payment			Jan. 15, 2020

Debt - Senior Notes, Contingent

Debt - Senior Notes, Contingent Convertible Senior Notes and Convertible Senior Notes Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 9,981	$ 9,989
5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 1,250
Debt Instrument, Interest Rate, Stated Percentage		5.50%
Convertible Debt [Member] | 2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 9	$ 200
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument, Interest Rate, Effective Percentage	8.00%
Convertible Debt [Member] | 5.5% Convertible Senior Notes Due 2026 [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,250	$ 1,250
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument, Interest Rate, Effective Percentage	11.50%
Minimum [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 50
Maximum [Member] | Convertible Debt [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 75

Debt Debt - Term Loan Narrative

Debt Debt - Term Loan Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Aug. 22, 2019	Aug. 22, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Face Amount			$ 9,981	$ 9,989
Term Loan [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Term			5 years
Debt Instrument, Face Amount			$ 1,233	$ 1,500
Debt Instrument, Covenant Description			The term loan contains covenants limiting our ability to incur additional indebtedness, incur liens, consummate mergers and similar fundamental changes, make restricted payments, sell collateral and use proceeds from such sales, make investments, repay certain subordinate, unsecured or junior lien indebtedness, and enter into transactions with affiliates.
Term Loan [Member] | Scenario, Forecast [Member]
Debt Instrument, Term Loan [Line Items]
Premium to Par Percentage, Prior to 3rd Anniversary		4.25%
Premium to Par Percentage Prior to 4th Anniversary	2.125%
Term Loan [Member] | Minimum [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Event of Default, Cross-Payment Default and Cross Acceleration with Respect to Other Indebtedness, Outstanding Principal Balance			$ 125
Debt Instrument, Event of Default, Judgments Involving Liability			$ 125
Term Loan [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Basis Spread on Variable Rate			7.50%
Debt Instrument, Floor Rate			1.00%
Term Loan [Member] | Alternative Base Rate (ABR) [Member]
Debt Instrument, Term Loan [Line Items]
Debt Instrument, Basis Spread on Variable Rate			6.50%
Debt Instrument, Floor Rate			2.00%

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017USD ($)	Oct. 30, 2017USD ($)	Dec. 31, 2016USD ($)
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 9,981		$ 9,989
Revolving Credit Facility [Member]
Long-Term Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity			$ 3,800	3,800
Letters of Credit Outstanding, Amount		$ 116
Interest Coverage Ratio		1.25 to 1.0
Revolving Credit Facility [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Additional Indebtedness After Term Loan		$ 1,300
Revolving Credit Facility [Member] | First Lien [Member]
Long-Term Debt Instrument [Line Items]
Leverage Ratio		3.50 to 1.0
Revolving Credit Facility [Member] | First Lien [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital		0.65
Revolving Credit Facility [Member] | Scenario, Forecast [Member] | First Lien [Member]
Long-Term Debt Instrument [Line Items]
Leverage Ratio	3.00 to 1.0
Revolving Credit Facility [Member] | Scenario, Forecast [Member] | First Lien [Member] | Maximum [Member]
Long-Term Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital	0.65
Revolving Credit Facility [Member] | Line of Credit [Member]
Long-Term Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 781		$ 0

Debt - Fair Value of Debt Table

Debt - Fair Value of Debt Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 9,928	$ 9,483
Fair Value, Inputs, Level 1 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term Debt, Fair Value	52	503
Long-term Debt, Fair Value	2,633	3,271
Fair Value, Inputs, Level 1 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term Debt, Fair Value	53	511
Long-term Debt, Fair Value	2,629	3,216
Fair Value, Inputs, Level 2 [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	7,286	6,664
Fair Value, Inputs, Level 2 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 7,301	$ 6,654

Contingencies and Commitments C

Contingencies and Commitments Commitments - Operating Leases Table (Details) $ in Millions	Dec. 31, 2017USD ($)
Other Commitments [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 6
Operating Leases, Future Minimum Payments, Due in Two Years	5
Operating Leases, Future Minimum Payments, Due in Three Years	2
Operating Leases, Future Minimum Payments, Due in Four Years	1
Operating Leases, Future Minimum Payments Due	$ 14

Commitments - Gathering Process

Commitments - Gathering Processing and Transportation Commitments Table (Details) $ in Millions	Dec. 31, 2017USD ($)
Other Commitments [Line Items]
Gathering, Processing and Transportation Commitment, Due in Next Twelve Months	$ 6
Gathering, Processing and Transportation Agreement [Member]
Other Commitments [Line Items]
Gathering, Processing and Transportation Commitment, Due in Next Twelve Months	1,079
Gathering, Processing and Transportation Commitment, Due in Second Year	1,051
Gathering, Processing and Transportation Commitment, Due in Third Year	979
Gathering, Processing and Transportation Commitment, Due in Fourth Year	883
Gathering, Processing and Transportation Commitment, Due in Fifth Year	771
Gathering, Processing and Transportation Commitment, Due after Fifth Year	4,404
Gathering, Processing and Transportation Commitment	$ 9,167

Contingencies and Commitments61

Contingencies and Commitments Commitments - Drilling Contracts Table (Details) $ in Millions	Dec. 31, 2017USD ($)
Drilling Rig Leases [Member]
Other Commitments [Line Items]
Drilling Contracts Contractual Obligation, Due in Next Fiscal Year	$ 23

Commitments - Narrative (Detail

Commitments - Narrative (Details) - USD ($) $ in Millions	Dec. 20, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Long-term Purchase Commitment [Line Items]
Settlement amount	$ 30
Operating Leases, Rent Expense		$ 3	$ 5	$ 7

Other Liabilities - Current Tab

Other Liabilities - Current Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Other Current Liabilities [Line Items]
Current revenues and royalties due others	$ 612	$ 543
Accrued drilling and production costs	216	169
Joint interest prepayments received	74	71
Accrued compensation and benefits	214	239
Other accrued taxes	43	32
Bank of New York Mellon legal accrual(a)	0	440
Other	296	304
Current liabilities	$ 1,455	$ 1,798
Senior Notes [Member] | 6.775 Senior Notes due 2019 [Member]
Other Current Liabilities [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.775%
Redemption of 2019 Notes [Member] | Senior Notes [Member] | 6.775 Senior Notes due 2019 [Member]
Other Current Liabilities [Line Items]
Payments for Legal Settlements	$ 441

Other Liabilities - Long-Term T

Other Liabilities - Long-Term Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)well	Dec. 31, 2016USD ($)
Other Long-Term Liabilities [Line Items]
CHK Utica ORRI conveyance obligation	$ 156	$ 160
Unrecognized tax benefits	101	97
Other	97	126
Total other long-term liabilities	354	383
Current revenues and royalties due others	$ 612	543
Noncontrolling Interest, Chesapeake Utica L L C [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Wells | well	1,500
Current revenues and royalties due others	$ 30	$ 43
Minimum [Member] | Noncontrolling Interest, Chesapeake Utica L L C [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Wells | well	1,300
Wells, Drilled Wells [Member] | Noncontrolling Interest, Chesapeake Utica L L C [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Wells | well	572

Income Taxes Income Taxes - Ex

Income Taxes Income Taxes - Expense {Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Current Federal Tax Expense (Benefit)	$ (14)	$ (14)	$ 0
Current State and Local Tax Expense (Benefit)	5	(5)	(36)
Current Income Tax Expense (Benefit)	(9)	(19)	(36)
Deferred Federal Income Tax Expense (Benefit)	13	(147)	(4,385)
Deferred State and Local Income Tax Expense (Benefit)	(2)	(24)	(42)
Deferred Income Tax Expense (Benefit)	11	(171)	(4,427)
Deferred income taxes	$ 2	$ (190)	$ (4,463)

Income Taxes Income Taxes - Eff

Income Taxes Income Taxes - Effective Income Tax Expense (Benefit) Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%	35.00%	35.00%
Income tax expense (benefit) at the federal statutory rate (35%)	$ 333	$ (1,606)	$ (6,684)
State income taxes (net of federal income tax benefit)	66	(30)	(406)
Remeasurement of deferred tax assets and liabilities	1,266	0	0
Change in valuation allowance	(1,676)	1,423	2,727
Other	13	23	(100)
Deferred income taxes	$ 2	$ (190)	$ (4,463)

Income Taxes Income Taxes - Def

Income Taxes Income Taxes - Deferred Tax Assets and Liabilities Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Deferred Tax Liabilities, Deferred Expense, Other Capitalized Costs	$ (129)	$ (223)
Deferred Tax Liabilities, Other	(20)	(62)
Deferred Tax Liabilities, Gross	149	285
Deferred Tax Assets, Property, Plant and Equipment	1	593
Deferred Tax Assets, Operating Loss Carryforwards	2,248	2,587
Deferred Tax Assets, Carrying Value of Debt	161	539
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Asset Retirement Obligations	42	98
Deferred Tax Assets, Investments	161	275
Deferred Tax Assets, Derivative Instruments	17	161
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities	125	319
Deferred Tax Assets, Other	71	118
Deferred Tax Assets, Gross	2,826	4,690
Deferred Tax Assets, Valuation Allowance	(2,674)	(4,389)
Deferred Tax Assets, Net of Valuation Allowance	152	301
Deferred Tax Assets, Net	$ 3	$ 16

Income Taxes Income Taxes - Un

Income Taxes Income Taxes - Unrecognized Tax Benefits Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Unrecognized tax benefits at beginning of period	$ 106	$ 202	$ 280	$ 303
Additions based on tax positions related to the current year	0	0	27
Additions to tax positions of prior years	4	33	0
Settlements	(100)	(111)	0
Reductions to tax positions of prior years	0	0	(50)
Unrecognized tax benefits at end of period	$ 106	$ 202	$ 280

Income Taxes Income Taxes - Nar

Income Taxes Income Taxes - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes Summary [Line Items]
Deferred income taxes	$ 2	$ (190)	$ (4,463)
Income Tax Effects Allocated Directly to Equity, Equity Transactions		165
Income Tax Effects Allocated Directly to Equity, Other		10
Change in valuation allowance	(1,676)	1,423	2,727
Deferred Tax Assets, Operating Loss Carryforwards	2,248	2,587
Deferred Tax Assets, Gross	2,826	4,690
Deferred Tax Assets, Valuation Allowance	2,674	4,389
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ 1,715
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	5.00%
Percentage Of Beneficial Interest Owned	50.00%
Unrecognized tax benefits at beginning of period	$ 106	202	$ 280	$ 303
Unrecognized Tax Benefits, Interest on Income Taxes Accrued	23	20
Domestic Tax Authority [Member]
Income Taxes Summary [Line Items]
Tax Credit Carryforward, Amount	8,100
Deferred Tax Assets, Operating Loss Carryforwards	1,695
State and Local Jurisdiction [Member]
Income Taxes Summary [Line Items]
Tax Credit Carryforward, Amount	10,100
Deferred Tax Assets, Operating Loss Carryforwards	581
Unrecognized tax benefits at beginning of period	$ 74	$ 76

Related Parties Related Parties

Related Parties Related Parties Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
FTS International, Inc. [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 111	$ 3	$ 65

Equity Equity - Common Stock Ta

Equity Equity - Common Stock Table (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	896,279,353
Stock option exercises	0	0	14,000
Common Stock, Shares, Issued End of Period	908,732,809	896,279,353
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Issued Beginning of Period	896,279,000	664,796,000	664,944,000
Restricted stock issuances (net of forfeitures and cancellations)	2,488,000	1,945,000	(163,000)
Stock option exercises	0	0	15,000
Common Stock, Shares, Issued End of Period	908,733,000	896,279,000	664,796,000
Common Stock [Member] | Contingent Convertible Senior Notes Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	55,428,000	0
Common Stock [Member] | Senior Notes Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	0	53,924,000	0
Common Stock [Member] | Preferred Stock, Exchanged for Shares of Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	9,966,000	120,186,000	0

Equity Equity - Preferred Stock

Equity Equity - Preferred Stock Conversion Terms Table (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class of Stock [Line Items]
Preferred Stock Conversions, Inducements	$ 41,000,000	$ 428,000,000	$ 0
5.75% Cumulative Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
4.50% Cumulative Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	4.50%
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Class of Stock [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.00%
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Conversion of Stock, Stock Issue Date	Jun. 1, 2010
Preferred Stock, Liquidation Preference Per Share	$ 1,000
Conversion of Stock, Holders Conversion Right	Any time
Preferred Stock Conversion Rate	39.6858%
Conversion of Stock, Conversion Price	$ 25.1979
Convertible Preferred Stock, Terms of Conversion	May 17, 2015
Preferred Stock Conversions, Inducements	$ 32.7573
Preferred Stock, Dividend Rate, Percentage	5.75%
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock Series A [Member]
Class of Stock [Line Items]
Conversion of Stock, Stock Issue Date	May 10, 2010
Preferred Stock, Liquidation Preference Per Share	$ 1,000
Conversion of Stock, Holders Conversion Right	Any time
Preferred Stock Conversion Rate	38.3508%
Conversion of Stock, Conversion Price	$ 26.0751
Convertible Preferred Stock, Terms of Conversion	May 17, 2015
Preferred Stock Conversions, Inducements	$ 33.8976
Preferred Stock, Dividend Rate, Percentage	5.75%
Preferred Stock [Member] | 4.50% Cumulative Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Conversion of Stock, Stock Issue Date	Sep. 15, 2005
Preferred Stock, Liquidation Preference Per Share	$ 100
Conversion of Stock, Holders Conversion Right	Any time
Preferred Stock Conversion Rate	2.4561%
Conversion of Stock, Conversion Price	$ 40.7152
Convertible Preferred Stock, Terms of Conversion	September 15, 2010
Preferred Stock Conversions, Inducements	$ 52.9298
Preferred Stock [Member] | 5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Class of Stock [Line Items]
Conversion of Stock, Stock Issue Date	Nov. 15, 2005
Preferred Stock, Liquidation Preference Per Share	$ 100
Conversion of Stock, Holders Conversion Right	Any time
Preferred Stock Conversion Rate	2.7745%
Conversion of Stock, Conversion Price	$ 36.0431
Convertible Preferred Stock, Terms of Conversion	November 15, 2010
Preferred Stock Conversions, Inducements	$ 46.8560
Preferred Stock [Member] | Minimum [Member] | 4.50% or 5.00% (Series 2005B) Cumulative Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Conversion of Stock, Company Market Trigger	250,000
Preferred Stock [Member] | Minimum [Member] | 5.75% or 5.75% (Series A) Preferred Stock [Member]
Class of Stock [Line Items]
Conversion of Stock, Company Market Trigger	25,000

Equity - Preferred Stock Table

Equity - Preferred Stock Table (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period	5,839,506
Preferred Stock, Shares Outstanding, End of Period	5,603,458	5,839,506
Loss on Exchange of Preferred Stock	$ (41,000,000)	$ (428,000,000)	$ 0
5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage	5.75%
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage	5.75%
4.50% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage	4.50%
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Dividend Rate, Percentage	5.00%
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period	843,000	1,497,000	1,497,000
Conversion of Stock, Shares Converted	(72,600)	653,872
Preferred Stock, Shares Outstanding, End of Period	770,000	843,000	1,497,000
Preferred Stock, Dividend Rate, Percentage	5.75%
Loss on Exchange of Preferred Stock	$ (32.7573)
Preferred Stock [Member] | 5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period	476,000	1,100,000	1,100,000
Conversion of Stock, Shares Converted	(12,500)	624,137
Preferred Stock, Shares Outstanding, End of Period	463,000	476,000	1,100,000
Preferred Stock, Dividend Rate, Percentage	5.75%
Loss on Exchange of Preferred Stock	$ (33.8976)
Preferred Stock [Member] | 4.50% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period	2,559,000	2,559,000	2,559,000
Conversion of Stock, Shares Converted	0	0
Preferred Stock, Shares Outstanding, End of Period	2,559,000	2,559,000	2,559,000
Loss on Exchange of Preferred Stock	$ (52.9298)
Preferred Stock [Member] | 5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Preferred Stock, Shares Outstanding, Beginning of Period	1,962,000	2,096,000	2,096,000
Conversion of Stock, Shares Converted	(150,948)	134,000
Preferred Stock, Shares Outstanding, End of Period	1,811,000	1,962,000	2,096,000
Loss on Exchange of Preferred Stock	$ (46.8560)
Common Stock [Member] | 5.75% Cumulative Convertible Preferred Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	7,442,156	59,141,429
Common Stock [Member] | 5.75% Cumulative Convertible Preferred Stock Series A [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	1,205,923	60,032,734
Common Stock [Member] | 5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, Conversion of Convertible Securities	1,317,756	1,012,032

Equity - AOCI Changes Net of Ta

Equity - AOCI Changes Net of Tax Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period	$ (96)
Other Comprehensive Income (Loss)	39	$ 3	$ 44
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	(57)	(96)
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period	(96)	(99)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	5	(13)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	34	16
Other Comprehensive Income (Loss)	39	3
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	$ (57)	$ (96)	$ (99)

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Capitalization, Equity [Line Items]
Common Stock, Shares Authorized	2,000,000,000	1,500,000,000
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Noncontrolling interests	$ 124	$ 128
Net income attributable to noncontrolling interests	4	(9)	$ (68)
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest [Member]
Schedule of Capitalization, Equity [Line Items]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	34	16
Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Schedule of Capitalization, Equity [Line Items]
Net income attributable to noncontrolling interests	$ 4	$ 9	$ 68
5.75% Cumulative Convertible Preferred Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
5.75% Cumulative Convertible Preferred Stock Series A [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.75%
4.50% Cumulative Convertible Preferred Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage	4.50%
5.0% Cumulative Convertible Preferred Stock Series 2005 B [Member]
Schedule of Capitalization, Equity [Line Items]
Preferred Stock, Dividend Rate, Percentage	5.00%

Equity - Noncontrolling Interes

Equity - Noncontrolling Interests Narrative (Details) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Mar. 30, 2012USD ($)well	Dec. 31, 2017USD ($)well$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)	Mar. 31, 2012shares	Nov. 30, 2011shares
Noncontrolling Interest [Line Items]
Payments for (Proceeds from) Investments | $		$ 0	$ 0	$ 1
Common Stock, Shares, Issued | shares		908,732,809	896,279,353
Noncontrolling interests | $		$ 124	$ 128
Net income attributable to noncontrolling interests | $		$ 4	$ (9)	(68)
Common Stock, Par or Stated Value Per Share | $ / shares		$ 0.01	$ 0.01
Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Noncontrolling Interest [Line Items]
Net income attributable to noncontrolling interests | $		$ 4	$ 9	68
Common Stock, Shares, Outstanding | shares		46,750,000
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions		51.00%
Noncontrolling Interest, Chesapeake Cleveland Tonkawa Limited Liability Company [Member]
Noncontrolling Interest [Line Items]
Payments for (Proceeds from) Investments | $	$ 1,250
Preferred Stock, Shares Issued | shares					1,250,000
Overriding royalty interest percentage					3.75%
Net income attributable to noncontrolling interests | $				$ 50
Unit Distribution, Common Unit [Member] | Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Noncontrolling Interest [Line Items]
Common Stock, Shares, Issued | shares						23,000,000
Common Stock, Shares, Outstanding | shares		12,062,500
Unit Distribution, Subordinated Units [Member] | Noncontrolling Interest, Chesapeake Granite Wash Trust [Member]
Noncontrolling Interest [Line Items]
Common Stock, Shares, Outstanding | shares		11,687,500
ORRI [Member] | Noncontrolling Interest, Chesapeake Utica L L C [Member]
Noncontrolling Interest [Line Items]
Wells | well		1,500
Minimum [Member] | ORRI [Member] | Noncontrolling Interest, Chesapeake Utica L L C [Member]
Noncontrolling Interest [Line Items]
Wells | well		1,300
Wells, Drilled Wells [Member] | ORRI [Member] | Noncontrolling Interest, Chesapeake Utica L L C [Member]
Noncontrolling Interest [Line Items]
Wells | well		572
Wells, Future Wells [Member] | Noncontrolling Interest, Chesapeake Cleveland Tonkawa Limited Liability Company [Member]
Noncontrolling Interest [Line Items]
Wells | well	1,000

Equity - Accounting Adjustments

Equity - Accounting Adjustments (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
CONSOLIDATED BALANCE SHEETS
Accumulated deficit	$ (16,525)	$ (17,474)
Chesapeake stockholders’ equity	(496)	(1,331)
Noncontrolling interests	124	128
CONSOLIDATED STATEMENTS OF OPERATIONS
Net (income) loss attributable to noncontrolling interests	(4)	9	$ 68
Net income (loss) attributable to Chesapeake	949	(4,390)	(14,567)
Net income (loss) available to common stockholders	$ 813	$ (4,915)	$ (14,738)
Loss per common share basic (in dollars per share)	$ 0.90	$ (6.43)	$ (22.26)
Loss per common share diluted (in dollars per share)	$ 0.90	$ (6.43)	$ (22.26)
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income attributable to noncontrolling interests	$ (4)	$ 9	$ 68
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	988	(4,387)	(14,523)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity	(496)	(1,331)
Noncontrolling interests	124	128
As Previously Reported
CONSOLIDATED BALANCE SHEETS
Accumulated deficit		(17,603)
Chesapeake stockholders’ equity		(1,460)
Noncontrolling interests		257
CONSOLIDATED STATEMENTS OF OPERATIONS
Net (income) loss attributable to noncontrolling interests		(2)	(50)
Net income (loss) attributable to Chesapeake		(4,401)	(14,685)
Net income (loss) available to common stockholders		$ (4,926)	$ (14,856)
Loss per common share basic (in dollars per share)		$ (6.45)	$ (22.43)
Loss per common share diluted (in dollars per share)		$ (6.45)	$ (22.43)
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income attributable to noncontrolling interests		$ (2)	$ (50)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		(4,398)	(14,641)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity		(1,460)
Noncontrolling interests		257
Revision Adjustment
CONSOLIDATED BALANCE SHEETS
Accumulated deficit		129
Chesapeake stockholders’ equity		129
Noncontrolling interests		(129)
CONSOLIDATED STATEMENTS OF OPERATIONS
Net (income) loss attributable to noncontrolling interests		11	118
Net income (loss) attributable to Chesapeake		11	118
Net income (loss) available to common stockholders		$ 11	$ 118
Loss per common share basic (in dollars per share)		$ 0.02	$ 0.17
Loss per common share diluted (in dollars per share)		$ 0.02	$ 0.17
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income attributable to noncontrolling interests		$ 11	$ 118
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		11	118
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity		129
Noncontrolling interests		(129)
Retained Earnings
CONSOLIDATED BALANCE SHEETS
Chesapeake stockholders’ equity	(16,525)	(17,474)	(13,084)	$ 1,483
CONSOLIDATED STATEMENTS OF OPERATIONS
Net income (loss) attributable to Chesapeake	949	(4,390)	(14,567)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity	(16,525)	(17,474)	(13,084)	1,483
Retained Earnings | As Previously Reported
CONSOLIDATED BALANCE SHEETS
Chesapeake stockholders’ equity		(17,603)	(13,202)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity		(17,603)	(13,202)
Retained Earnings | Revision Adjustment
CONSOLIDATED BALANCE SHEETS
Chesapeake stockholders’ equity		129	118
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Chesapeake stockholders’ equity		129	118
Noncontrolling Interest
CONSOLIDATED BALANCE SHEETS
Noncontrolling interests	124	128	141	1,302
CONSOLIDATED STATEMENTS OF OPERATIONS
Net (income) loss attributable to noncontrolling interests	(4)	9	68
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income attributable to noncontrolling interests	(4)	9	68
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Noncontrolling interests	$ 124	128	141	$ 1,302
Noncontrolling Interest | As Previously Reported
CONSOLIDATED BALANCE SHEETS
Noncontrolling interests		257	259
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Noncontrolling interests		257	259
Noncontrolling Interest | Revision Adjustment
CONSOLIDATED BALANCE SHEETS
Noncontrolling interests		(129)	(118)
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
Noncontrolling interests		$ (129)	$ (118)

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock Table (Details) - Restricted Stock [Member] - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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	9,092	10,455	10,091
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	9,872	4,604	7,095
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(4,573)	(4,692)	(4,157)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(1,213)	(1,275)	(2,574)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Shares, Period End	13,178	9,092	10,455
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	$ 11.39	$ 17.31	$ 21.20
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	5.40	4.58	13.90
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	13.73	17.23	21.70
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	8.32	13.91	16.98
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Period End	$ 6.37	$ 11.39	$ 17.31

Share-Based Compensation - Equi

Share-Based Compensation - Equity-Classified Valuation Table (Details) - Employee Stock Option [Member]	12 Months Ended
	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	6 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	62.42%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	2.17%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	0.00%

Share-Based Compensation - Stoc

Share-Based Compensation - Stock Option Activity Table (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number Period Start					8,593	5,377	4,599
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross					9,226	4,932	1,208
Share Based Compensation Arrangement By Share Based Payment Award Shares Underlying Options Exercised In Period					0	0	(14)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Expirations in Period					(435)	(771)	(416)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested Options Forfeited, Number of Shares					(1,099)	(945)	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number Period End	16,285	8,593	5,377	4,599	16,285	8,593	5,377
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	4,474	2,844	2,045		4,474	2,844	2,045
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price Period Start					$ 11.88	$ 19.37	$ 19.55
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price					5.45	3.71	18.37
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price					0	0	18.13
Share-based Compensation Arrangements by Share-based Payment Award, Options, Expirations in Period, Weighted Average Exercise Price					18.51	19.46	18.46
Share-based Compensation Arrangements by Share-based Payment Award, Options, Forfeitures in Period, Weighted Average Exercise Price					9.12	5.66	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price Period End	$ 8.25	$ 11.88	$ 19.37	$ 19.55	8.25	11.88	19.37
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$ 15.15	$ 19.60	$ 19.61		$ 15.15	$ 19.60	$ 19.61
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	7 years 8 months 23 days	7 years 2 months 20 days	5 years 9 months 19 days	7 years 11 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	5 years 3 months 4 days	5 years 6 months 11 days	5 years 26 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value Period Start					$ 14	$ 0	$ 5
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Intrinsic Value	$ 0	$ 0	$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value Period End	1	14	0	$ 5	1	14	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value	$ 0	$ 0	$ 0		$ 0	$ 0	$ 0

Share-Based Compensation - Eq81

Share-Based Compensation - Equity-Classified Compensation Table (Details) - Restricted Stock and Stock Options [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 61	$ 68	$ 89
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	37	38	43
Oil and Natural Gas Properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	12	16	23
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	12	13	18
Marketing, Gathering and Compression Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 0	$ 1	$ 5

Share-Based Compensation - Liab

Share-Based Compensation - Liability Classified Valuation Table (Details) - Performance Shares [Member]	12 Months Ended
	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	83.97%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.89%
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	Dec. 31, 2017	Jan. 01, 2017	Jan. 01, 2016	Jan. 01, 2015
Award Year 2017, Payable 2020 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	1,217,774
Fair Value of Share Based Award	$ 5	$ 8
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 3
Award Year 2016, Payable 2019 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	2,348,893
Fair Value of Share Based Award	$ 9		$ 10
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 8
Award Year 2015, Payable 2018 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	629,694
Fair Value of Share Based Award	$ 1			$ 13
Deferred Compensation Share-based Arrangements, Liability, Current and Noncurrent	$ 1

Share-Based Compensation - Li84

Share-Based Compensation - Liability-Classified Compensation Table (Details) - Performance Shares [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ (4)	$ 15	$ (41)
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	(4)	14	(19)
Restructuring and Other Termination Costs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	0	1	(19)
Cost of Sales [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	0	0	(1)
Oil and Gas Properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 0	$ 0	$ (2)

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2015	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Shares Authorized	2,000,000,000		1,500,000,000
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$ 26
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 47
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	1 year 10 months 18 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 29 days
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Black-Scholes option pricing model
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Stock Options	$ 22
Employee Stock Option [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	33.30%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Employee Stock Option [Member] | Management [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	7 years
Employee Stock Option [Member] | Management [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	10 years
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Monte Carlo simulation
Performance Shares [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Performance Share Units Maximum Payout Percentage	200.00%	200.00%
Performance Share Grant Maximum Payout Percentage	100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	less than zero
Performance Shares [Member] | Management [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	0.00%	0.00%
Operational Component Percentage Performance Share Units	0.00%	0.00%
Performance Shares [Member] | Management [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	100.00%	100.00%
Operational Component Percentage Performance Share Units	100.00%	50.00%
2014 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	10 years
Reduction due to issuance of stock option or SAR	1
Reduction due to award other than stock option or SAR	2.12
Common Stock, Capital Shares Reserved for Future Issuance	40,574,965
2014 Long Term Incentive Plan [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Shares Authorized	71,600,000

Employee Benefit Plans Employee

Employee Benefit Plans Employee Benefit Plans Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	75.00%
Chesapeake Energy Corporation Savings and Incentive Stock Bonus Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 35,000,000	$ 39,000,000	$ 52,000,000
DC Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	15.00%
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 8,000,000	$ 9,000,000	$ 11,000,000
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	100.00%
Defined Contribution Plan, Description	55
Deferred Compensation Arrangement with Individual, Requisite Service Period	5 years
Maximum [Member] | Chesapeake Energy Corporation Savings and Incentive Stock Bonus Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	15.00%
Maximum [Member] | DC Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Top wage earners percentage of employees eligible to participate	10.00%
Minimum [Member] | DC Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Salaries, Wages and Officers' Compensation	$ 150,000
Deferred Bonus [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	100.00%

Derivative and Hedging Activi87

Derivative and Hedging Activities - Derivative Instruments Table (Details) gal in Millions, MMBbls in Millions, $ in Millions, MMBTU in Trillions	12 Months Ended
	Dec. 31, 2017USD ($)MMBTUMMBblsgal	Dec. 31, 2016USD ($)MMBTUMMBblsgal
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (35)	$ (577)
Energy Related Derivative [Member]
Derivative [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (35)	$ (504)
Energy Related Derivative [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	36	28
Derivative Assets (Liabilities), at Fair Value, Net	$ (183)	$ (141)
Energy Related Derivative [Member] | Oil [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	21	23
Derivative Assets (Liabilities), at Fair Value, Net	$ (151)	$ (140)
Energy Related Derivative [Member] | Oil [Member] | Three Way Collar [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	2	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (10)	$ 0
Energy Related Derivative [Member] | Oil [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	0	5
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ (1)
Energy Related Derivative [Member] | Oil [Member] | Call Swaption [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	2	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (13)	$ 0
Energy Related Derivative [Member] | Oil [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | MMBbls	11	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (9)	$ 0
Energy Related Derivative [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	754	924
Derivative Assets (Liabilities), at Fair Value, Net	$ 150	$ (363)
Energy Related Derivative [Member] | Natural Gas [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	532	719
Derivative Assets (Liabilities), at Fair Value, Net	$ 149	$ (349)
Energy Related Derivative [Member] | Natural Gas [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	110	114
Derivative Assets (Liabilities), at Fair Value, Net	$ (3)	$ 0
Energy Related Derivative [Member] | Natural Gas [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	65	31
Derivative Assets (Liabilities), at Fair Value, Net	$ (7)	$ (5)
Energy Related Derivative [Member] | Natural Gas [Member] | Collar [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	47	60
Derivative Assets (Liabilities), at Fair Value, Net	$ 11	$ (9)
Energy Related Derivative [Member] | NGL [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	33	53
Derivative Assets (Liabilities), at Fair Value, Net	$ (2)	$ 0

Derivative and Hedging Activi88

Derivative and Hedging Activities - Derivative Instruments in Balance Sheet Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		$ (577)
Derivative Asset, Fair Value, Gross Liability		0
Derivative, Fair Value, Net	$ (35)	(577)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	(35)
Derivative Liability, Fair Value, Gross Asset	0
Derivative, Fair Value, Net	(35)
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	(35)	(504)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	(35)	(504)
Designated as Hedging Instrument [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		(73)
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net		(73)
Other Current Assets [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	157	1
Derivative Asset, Fair Value, Gross Liability	(130)	(1)
Derivative, Fair Value, Net	27	0
Other Current Liabilities [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(188)	(490)
Derivative Liability, Fair Value, Gross Asset	130	1
Derivative, Fair Value, Net	(58)	(489)
Other Current Liabilities [Member] | Designated as Hedging Instrument [Member] | Foreign Exchange Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		(73)
Derivative Liability, Fair Value, Gross Asset		0
Derivative, Fair Value, Net		(73)
Other Noncurrent Liabilities [Member] | Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(4)	(15)
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative, Fair Value, Net	$ (4)	$ (15)

Derivative and Hedging Activi89

Derivative and Hedging Activities Derivative and Hedging Activities - Oil, Natural Gas and NGL Revenues Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Oil and Gas Revenue	$ 4,574	$ 3,866	$ 4,767
Oil, natural gas and NGL	4,985	3,288	5,391
Oil, Natural Gas and NGL Sales [Member]
Derivative [Line Items]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	(34)	(33)	(37)
Oil, Natural Gas and NGL Sales [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 445	$ (545)	$ 661

Derivative and Hedging Activi90

Derivative and Hedging Activities Derivative and Hedging Actitities - Marketing, Gathering and Compression Revenues Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Revenues	$ 9,496	$ 7,872	$ 12,764
Marketing, gathering and compression	4,511	4,584	7,373
Marketing, Gathering And Compression [Member]
Derivative [Line Items]
Revenues	4,511	4,881	7,077
Marketing, Gathering And Compression [Member] | Supply Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ (297)	$ 296

Derivative and Hedging Activi91

Derivative and Hedging Activities - Components of Interest Income and Interest Expense Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Total interest expense	$ 426	$ 296	$ 317

Derivative and Hedging Activi92

Derivative and Hedging Activities - Cash Flow Hedges Components of AOCI Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period	$ (96)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Before Tax			$ 32
Other Comprehensive Income (Loss), Net Change in Fair Value, Net of Tax	5	$ (13)	20
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	34	16	24
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	(57)	(96)
Cash Flow Hedging [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Before Tax, Beginning of Periodt	(153)	(160)	(231)
Accumulated Other Comprehensive Income (Loss), Net of Tax Beginning of Period	(96)	(99)	(143)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Before Tax	5	(27)
Other Comprehensive Income (Loss), Losses Reclassified to Income, Before Tax	34	34	39
Other Comprehensive Income (Loss), Losses Reclassified to Income, Net of Tax	34	16	24
Accumulated Other Comprehensive Income (Loss), Before Tax, End of Period	(114)	(153)	(160)
Accumulated Other Comprehensive Income (Loss), Net of Tax End of Period	$ (57)	$ (96)	$ (99)

Derivative and Hedging Activi93

Derivative and Hedging Activities - Fair Value of Recurring Assets and Liabilities Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (35)	$ (577)
Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	8	1
Derivative Liability	(43)	(505)
Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		(73)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Fair Value, Inputs, Level 1 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	0	0
Derivative Liability	0	0
Fair Value, Inputs, Level 1 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(20)	(567)
Fair Value, Inputs, Level 2 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	0	1
Derivative Liability	(20)	(495)
Fair Value, Inputs, Level 2 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		(73)
Fair Value, Inputs, Level 3 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(15)	(10)
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	8	0
Derivative Liability	(23)	(10)
Derivative Assets (Liabilities), at Fair Value, Net	$ (15)	(10)	$ (91)
Fair Value, Inputs, Level 3 [Member] | Foreign Exchange Contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Liability		$ 0

Derivative and Hedging Activi94

Derivative and Hedging Activities - Fair Value Level 3 Measurements Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	$ (577)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(35)	$ (577)
Energy Related Derivative [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(504)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(35)	(504)
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(10)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(15)	(10)
Fair Value, Inputs, Level 3 [Member] | Oil, Natural Gas and NGL Sales [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	2	6
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	(14)	(7)
Fair Value, Inputs, Level 3 [Member] | Marketing, Gathering and Compression Revenue [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	(118)
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	0	0
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	(10)	(91)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	2	6
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	(7)	75
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Sales		0
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	(15)	(10)
Fair Value, Inputs, Level 3 [Member] | Supply Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative Assets (Liabilities), at Fair Value, Net, Beginning of Period	0	297
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	(118)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	0	(33)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Sales		(146)
Derivative Assets (Liabilities), at Fair Value, Net, End of Period	$ 0	$ 0

Derivative and Hedging Activi95

Derivative and Hedging Activities - Quantitative Disclosures Level 3 Table (Details) - Energy Related Derivative [Member] $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Oil [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	22.43%
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (23)
Oil [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	13.14%
Oil [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	24.93%
Natural Gas [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	38.06%
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 8
Natural Gas [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	18.82%
Natural Gas [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Weighted Average Of Price Volatility Curve Percentage	82.61%

Derivative and Hedging Activi96

Derivative and Hedging Activities - Narrative (Details) € in Millions	12 Months Ended
	Dec. 31, 2016USD ($)Derivatives	Dec. 31, 2017USD ($)Derivativescounterparty	Dec. 31, 2017EUR (€)Derivativescounterparty	Dec. 31, 2006$ / €
Derivative [Line Items]
Number of Interest Rate Derivatives Held | Derivatives	0	0	0
Derivative Liability, Fair Value, Gross Liability	$ 577,000,000
Losses on Undesignated Supply Contract Derivatives	(297,000,000)
Cash Collateral for Borrowed Securities	$ 0	$ 0
Expected Amount to be Transferred of During the Next 12 Months		$ 17,000,000
Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, Number of Instruments Held | Derivatives	0	0	0
Interest Rate Contract [Member]
Derivative [Line Items]
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge	$ 3,000,000	$ 2,000,000
Cross Currency Interest Rate Contract [Member] | 6.25% Euro-Denominated Senior Notes Due 2017 [ Member] | Senior Notes [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.25%	6.25%	6.25%
Semi Annual Interest Rate Swap Payments By Counterparty | €			€ 246
Semi Annual Interest Rate Swap Payments by Chesapeake		$ 327,000,000
Derivative, Forward Exchange Rate | $ / €				1.3325
Foreign Exchange Contract [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ 73,000,000
Supply Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative [Line Items]
Gain (Loss) on Sale of Derivatives	$ 146,000,000
Credit Risk [Member]
Derivative [Line Items]
Number of counterparties in hedge facility | counterparty		11	11

Oil and Natural Gas Property 97

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

Oil and Natural Gas Property 98

Oil and Natural Gas Property Transactions - VPP Volume Remaining to Be Delivered Table (Details) - VPP 9 Mid-Continent [Member] MMBbls in Millions, Bcf in Millions, Bcfe in Billions	12 Months Ended
	Dec. 31, 2017BcfeMMBblsBcf	May 31, 2011BcfeMMBblsBcf
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Energy) | Bcfe		177
Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Term Remaining (in Months)	38 months
Proved Developed Reserves (Energy) | Bcfe	41.7
Oil [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)		1.7
Oil [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)	0.4
Natural Gas [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Bcf		138,000
Natural Gas [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume) | Bcf	34.1
NGL [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)		4.8
NGL [Member] | Reserve Volume Remaining [Member]
VPP Volumes Remaining to be Delivered [Line Items]
Proved Developed Reserves (Volume)	0.9

Oil and Natural Gas Property 99

Oil and Natural Gas Property Transactions - Narrative (Details) MMcf in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)awellMMcf	Dec. 31, 2016USD ($)awellVPP	Dec. 31, 2015USD ($)
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties	$ 1,249	$ 1,406	$ 189
Impairments of fixed assets and other	421	$ 838	194
Number of VPP Transactions | VPP		4
Corporate VPP [Member]
Business Acquisition [Line Items]
Payments to Acquire Oil and Gas Property		$ 259
JV Marcellus, Barnett, Utica, Eagle Ford, Mid-Continent [Member]
Business Acquisition [Line Items]
Proceeds from Divestiture of Interest in Joint Venture	10	7	33
Noncontrolling Interest, Chesapeake Cleveland Tonkawa Limited Liability Company [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties			90
Other Customers [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties			$ 66
Haynesville Shale [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties	$ 915
Number Of Net Acres | a	119,500
Productive Gas Wells, Number of Wells, Net | well	576
Payments to Acquire Oil and Gas Property		85
Haynesville Shale [Member] | Natural Gas [Member]
Business Acquisition [Line Items]
Proved Developed Reserves (Volume) | MMcf	80
Other Properties [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties	$ 350
Barnett Shale [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties		$ 218
Number Of Net Acres | a		212,000
Devonian Shale [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties		$ 140
Number Of Net Acres | a		1,300,000
Wells | well		5,300
Number of VPP Transactions | VPP		1
Devonian Shale [Member] | Corporate VPP [Member]
Business Acquisition [Line Items]
Payments to Acquire Oil and Gas Property		$ 127
Other Noncore [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties		1,048
Other, Barnett Shale Exit Costs,Termination of Gathering Agreement [Member]
Business Acquisition [Line Items]
Loss on Contract Termination		361
Payments for Restructuring		58
Impairments of fixed assets and other		361
Increase (Decrease) in Deferred Charges		58
Other, Barnett Shale Exit Costs, Other Property and Equipment [Member]
Business Acquisition [Line Items]
Impairments of fixed assets and other		284
Exploration and Production Equipment, Buildings and Land, Devonian Shale [Member]
Business Acquisition [Line Items]
Impairments of fixed assets and other		$ 142

Other Property and Equipment100

Other Property and Equipment Other Property and Equipment Held for Use and Estimated Useful Lives Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Buildings and improvements	$ 1,093	$ 1,119
Computer equipment	345	337
Natural gas compressors	235	251
Land	126	139
Gathering systems and treating plants	2	2
Other	185	205
Total other property and equipment, at cost	1,986	2,053
Less: accumulated depreciation	(672)	(632)
Total other property and equipment, net	$ 1,314	$ 1,421
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	10 – 39
Computer Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	5
Natural Gas Compressors [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	3 – 20
Gas Gathering and Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	20
Other [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	5 – 10

Other Property and Equipment101

Other Property and Equipment Other Property and Equipment Gains (Losses) on Sales of Fixed Assets Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	$ 3	$ 12	$ (4)
Buildings and Land [Member]
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	4	1	(3)
Natural Gas Compressors [Member]
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	(1)	10	0
Gas Gathering and Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	0	0	(1)
Exploration and Production Equipment [Member]
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	0	1	0
Other Assets [Member]
Property, Plant and Equipment [Line Items]
Net (gains) losses on sales of fixed assets	$ 3	$ 12	$ (4)

Other Property and Equipment102

Other Property and Equipment Other Property and Equipment Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property and equipment held for sale, net	$ 16	$ 29
Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | Buildings and Land [Member]
Property, Plant and Equipment [Line Items]
Property and equipment held for sale, net	$ 16	$ 29

Impairments Impairments - Fixed

Impairments Impairments - Fixed Assets and Other Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	$ 421	$ 838	$ 194
Other, Barnett Shale Exit Costs [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	645	0
Other Devonian Shale Exit Costs [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	142	0
Exploration and Production Equipment [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	3	173
Gas Gathering and Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other			0
Natural Gas Compressor [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	0	21
Natural Gas Compressors [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other			21
Buildings and Land [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	5	11	0
Other [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other	$ 416	$ 16	$ 194

Impairments - Narrative (Detail

Impairments - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)Compressor	Dec. 31, 2015USD ($)
Property, Plant and Equipment [Line Items]
Impairment of Oil and Natural Gas Properties	$ 0	$ 2,564	$ 18,238
Impairments of Fixed Assets and Other	421	838	194
Loss on Transportation Agreement	4,598	4,778	7,130
Provision for legal contingencies, net	(42)	87	340
Gain (Loss) on Contract Termination			18
Contractual Dispute [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other			47
Note Receivable [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other			22
Net Acreage Shortfall [Member] | Total [Member]
Property, Plant and Equipment [Line Items]
Provision for legal contingencies, net			$ 70
Other, Barnett Shale Exit Costs,Termination of Gathering Agreement [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		361
Loss on Contract Termination		361
Other, Barnett Shale Exit Costs, Other Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		284
Exploration and Production Equipment, Buildings and Land, Devonian Shale [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		142
Transportation Equipment [Member] | Natural Gas [Member]
Property, Plant and Equipment [Line Items]
Loss on Contract Termination	126
Transportation Equipment [Member] | Oil [Member]
Property, Plant and Equipment [Line Items]
Loss on Transportation Agreement	$ 290
Natural Gas Compressors, Obsolete [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		$ 13
Equipment, Number of Units | Compressor		205
Natural Gas Compressors, Difference Between Sales Price and Carrying Value [Member]
Property, Plant and Equipment [Line Items]
Impairments of Fixed Assets and Other		$ 8
Equipment, Number of Units | Compressor		155

Restructuring Restructuring and

Restructuring Restructuring and Other Termination Costs Narrative (Details) - USD ($) $ in Millions	Sep. 29, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs		$ 0	$ 6	$ 36
Restructuring and Related Cost, Number of Positions Eliminated, Period Percent	15.00%
Workforce Reduction Plan [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs				55
Employee Severance [Member] | Workforce Reduction Plan [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Incurred Cost				47
Other Restructuring [Member] | Workforce Reduction Plan [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Incurred Cost				8
Other, Including PSU's [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs				$ (19)

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	$ (3)	$ (2)
Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	57	49
Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	(60)	(51)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value, Net Asset (Liability)	(3)	(2)
Fair Value, Inputs, Level 1 [Member] | Other Current Assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Assets, Fair Value Disclosure	57	49
Fair Value, Inputs, Level 1 [Member] | Other Current Liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other Current Liabilities, Fair Value Disclosure	(60)	(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

Asset Retirement Obligations107

Asset Retirement Obligations Asset Retirement Obligations Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations, Beginning of Period	$ 177	$ 261	$ 177	$ 261	$ 473
Asset Retirement Obligation, Liabilities Incurred	5	4
Asset Retirement Obligation, Revision of Estimate	(34)	(58)
Asset Retirement Obligation, Liabilities Settled	(70)	(182)
Asset Retirement Obligation, Accretion Expense	15	24
Asset Retirement Obligations, End of Period	$ 177	$ 261
Asset Retirement Obligation, Current			15	14
Asset Retirement Obligation, Long-Term			$ 162	$ 247

Major Customers - Narrative (De

Major Customers - Narrative (Details) - Segment	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenue, Major Customer [Line Items]
Concentration Risk, Benchmark Description	Sales to Royal Dutch Shell PLC constituted approximately 10% of our total revenues (before the effects of hedging) for the year ended December 31, 2017. Sales to BP PLC constituted approximately 10% and 14% of our total revenues (before the effects of hedging) for the years ended December 31, 2016 and 2015, respectively.
Concentration Risk, Percentage	10.00%
Number of Reportable Segments	1
BP PLC [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage		10.00%	14.00%

Condensed Consolidating Fina109

Condensed Consolidating Financial Information Condensed Consolidating Financial Information Balance Sheets Table (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	$ 5	$ 882
Other current assets	1,520
Intercompany receivable, net	0
Total Current Assets	1,525	2,142
Oil and natural gas properties at cost, based on full cost accounting, net	9,350
Other property and equipment, net	1,314	1,421
Property and equipment held for sale, net	16	29
Total Property and Equipment, Net	10,680	10,609
Other long-term assets	220	277
Investments in subsidiaries and intercompany advances	0
TOTAL ASSETS	12,425	13,028
Current liabilities	2,356
Intercompany payable, net	0
Total Current Liabilities	2,356	3,648
Long-term debt, net	9,921	9,938
Other long-term liabilities	520
Total Long-Term Liabilities	10,441	10,583
Chesapeake stockholders’ equity	(496)	(1,331)
Noncontrolling interests	124	128
Total Equity (Deficit)	(372)	(1,203)	$ 2,397
TOTAL LIABILITIES AND EQUITY	12,425	$ 13,028
Consolidation, Eliminations [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	(3)
Other current assets	(1)
Intercompany receivable, net	(9,133)
Total Current Assets	(9,137)
Oil and natural gas properties at cost, based on full cost accounting, net	0
Other property and equipment, net	0
Property and equipment held for sale, net	0
Total Property and Equipment, Net	0
Other long-term assets	0
Investments in subsidiaries and intercompany advances	(660)
TOTAL ASSETS	(9,797)
Current liabilities	(4)
Intercompany payable, net	(9,133)
Total Current Liabilities	(9,137)
Long-term debt, net	0
Other long-term liabilities	0
Total Long-Term Liabilities	0
Chesapeake stockholders’ equity	(660)
Noncontrolling interests	0
Total Equity (Deficit)	(660)
TOTAL LIABILITIES AND EQUITY	(9,797)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	5
Other current assets	154
Intercompany receivable, net	8,697
Total Current Assets	8,856
Oil and natural gas properties at cost, based on full cost accounting, net	435
Other property and equipment, net	0
Property and equipment held for sale, net	0
Total Property and Equipment, Net	435
Other long-term assets	52
Investments in subsidiaries and intercompany advances	806
TOTAL ASSETS	10,149
Current liabilities	190
Intercompany payable, net	433
Total Current Liabilities	623
Long-term debt, net	9,921
Other long-term liabilities	101
Total Long-Term Liabilities	10,022
Chesapeake stockholders’ equity	(496)
Noncontrolling interests	0
Total Equity (Deficit)	(496)
TOTAL LIABILITIES AND EQUITY	10,149
Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	1
Other current assets	1,364
Intercompany receivable, net	436
Total Current Assets	1,801
Oil and natural gas properties at cost, based on full cost accounting, net	8,888
Other property and equipment, net	1,314
Property and equipment held for sale, net	16
Total Property and Equipment, Net	10,218
Other long-term assets	168
Investments in subsidiaries and intercompany advances	(146)
TOTAL ASSETS	12,041
Current liabilities	2,168
Intercompany payable, net	8,648
Total Current Liabilities	10,816
Long-term debt, net	0
Other long-term liabilities	419
Total Long-Term Liabilities	419
Chesapeake stockholders’ equity	806
Noncontrolling interests	0
Total Equity (Deficit)	806
TOTAL LIABILITIES AND EQUITY	12,041
Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	2
Other current assets	3
Intercompany receivable, net	0
Total Current Assets	5
Oil and natural gas properties at cost, based on full cost accounting, net	27
Other property and equipment, net	0
Property and equipment held for sale, net	0
Total Property and Equipment, Net	27
Other long-term assets	0
Investments in subsidiaries and intercompany advances	0
TOTAL ASSETS	32
Current liabilities	2
Intercompany payable, net	52
Total Current Liabilities	54
Long-term debt, net	0
Other long-term liabilities	0
Total Long-Term Liabilities	0
Chesapeake stockholders’ equity	(146)
Noncontrolling interests	124
Total Equity (Deficit)	(22)
TOTAL LIABILITIES AND EQUITY	$ 32

Condensed Consolidating Fina110

Condensed Consolidating Financial Information Condensed Consolidating Financial Information Income Statements Table (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Income Statements, Captions [Line Items]
Oil, natural gas and NGL	$ 4,985	$ 3,288	$ 5,391
Marketing, gathering and compression	4,511	4,584	7,373
Total Revenues	9,496	7,872	12,764
Oil, natural gas and NGL production	562	710	1,046
Oil, natural gas and NGL gathering, processing and transportation	1,471	1,855	2,119
Production taxes	89	74	99
Marketing, gathering and compression	4,598	4,778	7,130
General and administrative	262	240	235
Restructuring and other termination costs	0	6	36
Provision for legal contingencies, net	(38)	123	353
Oil, natural gas and NGL depreciation, depletion and amortization	913	1,003	2,099
Depreciation and amortization of other assets	82	104	130
Impairment of oil and natural gas properties	0	2,564	18,238
Impairments of fixed assets and other	421	838	194
Net gains (losses) on sales of fixed assets	(3)	(12)	4
Total Operating Expenses	8,357	12,283	31,683
INCOME (LOSS) FROM OPERATIONS	1,139	(4,411)	(18,919)
Interest expense	(426)	(296)	(317)
Losses on investments	0	(8)	(96)
Impairments of investments	0	(119)	(53)
Loss on sale of investment	0	(10)	0
Gains on purchases or exchanges of debt	233	236	279
Other income	9	19	8
Equity in net earnings (losses) of subsidiary	0
Total Other Expense	(184)	(178)	(179)
INCOME (LOSS) BEFORE INCOME TAXES	955	(4,589)	(19,098)
INCOME TAX EXPENSE (BENEFIT)	2	(190)	(4,463)
NET INCOME (LOSS)	953	(4,399)	(14,635)
Net (income) loss attributable to noncontrolling interests	(4)	9	68
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	949	(4,390)	(14,567)
Other comprehensive income	39	3	44
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	988	$ (4,387)	$ (14,523)
Consolidation, Eliminations [Member]
Condensed Income Statements, Captions [Line Items]
Oil, natural gas and NGL	0
Marketing, gathering and compression	0
Total Revenues	0
Oil, natural gas and NGL production	0
Oil, natural gas and NGL gathering, processing and transportation	0
Production taxes	0
Marketing, gathering and compression	0
General and administrative	0
Restructuring and other termination costs	0
Provision for legal contingencies, net	0
Oil, natural gas and NGL depreciation, depletion and amortization	0
Depreciation and amortization of other assets	0
Impairments of fixed assets and other	0
Net gains (losses) on sales of fixed assets	0
Total Operating Expenses	0
INCOME (LOSS) FROM OPERATIONS	0
Interest expense	0
Gains on purchases or exchanges of debt	0
Other income	0
Equity in net earnings (losses) of subsidiary	(1,067)
Total Other Expense	(1,067)
INCOME (LOSS) BEFORE INCOME TAXES	(1,067)
INCOME TAX EXPENSE (BENEFIT)	0
NET INCOME (LOSS)	(1,067)
Net (income) loss attributable to noncontrolling interests	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(1,067)
Other comprehensive income	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(1,067)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Oil, natural gas and NGL	0
Marketing, gathering and compression	0
Total Revenues	0
Oil, natural gas and NGL production	0
Oil, natural gas and NGL gathering, processing and transportation	0
Production taxes	0
Marketing, gathering and compression	0
General and administrative	1
Restructuring and other termination costs	0
Provision for legal contingencies, net	(79)
Oil, natural gas and NGL depreciation, depletion and amortization	0
Depreciation and amortization of other assets	0
Impairments of fixed assets and other	0
Net gains (losses) on sales of fixed assets	0
Total Operating Expenses	(78)
INCOME (LOSS) FROM OPERATIONS	78
Interest expense	(424)
Gains on purchases or exchanges of debt	233
Other income	1
Equity in net earnings (losses) of subsidiary	1,063
Total Other Expense	873
INCOME (LOSS) BEFORE INCOME TAXES	951
INCOME TAX EXPENSE (BENEFIT)	2
NET INCOME (LOSS)	949
Net (income) loss attributable to noncontrolling interests	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	949
Other comprehensive income	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	949
Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Oil, natural gas and NGL	4,962
Marketing, gathering and compression	4,511
Total Revenues	9,473
Oil, natural gas and NGL production	562
Oil, natural gas and NGL gathering, processing and transportation	1,463
Production taxes	88
Marketing, gathering and compression	4,598
General and administrative	259
Restructuring and other termination costs	0
Provision for legal contingencies, net	41
Oil, natural gas and NGL depreciation, depletion and amortization	909
Depreciation and amortization of other assets	82
Impairments of fixed assets and other	421
Net gains (losses) on sales of fixed assets	(3)
Total Operating Expenses	8,420
INCOME (LOSS) FROM OPERATIONS	1,053
Interest expense	(2)
Gains on purchases or exchanges of debt	0
Other income	8
Equity in net earnings (losses) of subsidiary	4
Total Other Expense	10
INCOME (LOSS) BEFORE INCOME TAXES	1,063
INCOME TAX EXPENSE (BENEFIT)	0
NET INCOME (LOSS)	1,063
Net (income) loss attributable to noncontrolling interests	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	1,063
Other comprehensive income	39
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	1,102
Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Oil, natural gas and NGL	23
Marketing, gathering and compression	0
Total Revenues	23
Oil, natural gas and NGL production	0
Oil, natural gas and NGL gathering, processing and transportation	8
Production taxes	1
Marketing, gathering and compression	0
General and administrative	2
Restructuring and other termination costs	0
Provision for legal contingencies, net	0
Oil, natural gas and NGL depreciation, depletion and amortization	4
Depreciation and amortization of other assets	0
Impairments of fixed assets and other	0
Net gains (losses) on sales of fixed assets	0
Total Operating Expenses	15
INCOME (LOSS) FROM OPERATIONS	8
Interest expense	0
Gains on purchases or exchanges of debt	0
Other income	0
Equity in net earnings (losses) of subsidiary	0
Total Other Expense	0
INCOME (LOSS) BEFORE INCOME TAXES	8
INCOME TAX EXPENSE (BENEFIT)	0
NET INCOME (LOSS)	8
Net (income) loss attributable to noncontrolling interests	(4)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	4
Other comprehensive income	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	$ 4

Condensed Consolidating Fina111

Condensed Consolidating Financial Information Condensed Consolidating Financial Information Statements of Cash Flows Tables (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided By (Used In) Operating Activities	$ 745	$ (204)	$ 1,234
Drilling and completion costs	(2,186)	(1,295)	(3,095)
Acquisitions of proved and unproved properties	(285)	(788)	(533)
Proceeds from divestitures of proved and unproved properties	1,249	1,406	189
Additions to other property and equipment	(21)	(37)	(143)
Other Investing Activities Intercompany	55
Net Cash Used In Investing Activities	(1,188)	(660)	(3,451)
Proceeds from revolving credit facility borrowings	7,771	5,146	0
Payments on revolving credit facility borrowings	(6,990)	(5,146)	0
Proceeds from issuance of senior notes, net	1,585	2,210	0
Proceeds from issuance of term loan, net	0	1,476	0
Cash paid to purchase debt	(2,592)	(2,734)	(508)
Cash paid for preferred stock dividends	(183)	0	(171)
Other Financing Activities Intercompany	(25)
Payments for Repurchase of Redeemable Noncontrolling Interest	0	0	143
Intercompany advances, net	0
Net Cash Provided By (Used In) Financing Activities	(434)	921	(1,066)
Net increase (decrease) in cash and cash equivalents	(877)	57	(3,283)
Cash and cash equivalents, beginning of period	882	825	4,108
Cash and cash equivalents, end of period	5	882	$ 825
Consolidation, Eliminations [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided By (Used In) Operating Activities	(10)
Drilling and completion costs	0
Acquisitions of proved and unproved properties	0
Proceeds from divestitures of proved and unproved properties	0
Additions to other property and equipment	0
Other Investing Activities Intercompany	0
Net Cash Used In Investing Activities	0
Proceeds from revolving credit facility borrowings	0
Payments on revolving credit facility borrowings	0
Proceeds from issuance of senior notes, net	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0
Other Financing Activities Intercompany	32
Intercompany advances, net	0
Net Cash Provided By (Used In) Financing Activities	32
Net increase (decrease) in cash and cash equivalents	22
Cash and cash equivalents, beginning of period	(25)
Cash and cash equivalents, end of period	(3)	(25)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided By (Used In) Operating Activities	5
Drilling and completion costs	0
Acquisitions of proved and unproved properties	0
Proceeds from divestitures of proved and unproved properties	0
Additions to other property and equipment	0
Other Investing Activities Intercompany	0
Net Cash Used In Investing Activities	0
Proceeds from revolving credit facility borrowings	7,771
Payments on revolving credit facility borrowings	(6,990)
Proceeds from issuance of senior notes, net	1,585
Cash paid to purchase debt	(2,592)
Cash paid for preferred stock dividends	(183)
Other Financing Activities Intercompany	(39)
Intercompany advances, net	456
Net Cash Provided By (Used In) Financing Activities	(904)
Net increase (decrease) in cash and cash equivalents	(899)
Cash and cash equivalents, beginning of period	904
Cash and cash equivalents, end of period	5	904
Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided By (Used In) Operating Activities	736
Drilling and completion costs	(2,186)
Acquisitions of proved and unproved properties	(285)
Proceeds from divestitures of proved and unproved properties	1,249
Additions to other property and equipment	(21)
Other Investing Activities Intercompany	55
Net Cash Used In Investing Activities	(1,188)
Proceeds from revolving credit facility borrowings	0
Payments on revolving credit facility borrowings	0
Proceeds from issuance of senior notes, net	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0
Other Financing Activities Intercompany	(5)
Intercompany advances, net	(456)
Net Cash Provided By (Used In) Financing Activities	451
Net increase (decrease) in cash and cash equivalents	(1)
Cash and cash equivalents, beginning of period	2
Cash and cash equivalents, end of period	1	2
Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Cash Provided By (Used In) Operating Activities	14
Drilling and completion costs	0
Acquisitions of proved and unproved properties	0
Proceeds from divestitures of proved and unproved properties	0
Additions to other property and equipment	0
Other Investing Activities Intercompany	0
Net Cash Used In Investing Activities	0
Proceeds from revolving credit facility borrowings	0
Payments on revolving credit facility borrowings	0
Proceeds from issuance of senior notes, net	0
Cash paid to purchase debt	0
Cash paid for preferred stock dividends	0
Other Financing Activities Intercompany	(13)
Intercompany advances, net	0
Net Cash Provided By (Used In) Financing Activities	(13)
Net increase (decrease) in cash and cash equivalents	1
Cash and cash equivalents, beginning of period	1
Cash and cash equivalents, end of period	$ 2	$ 1

Condensed Consolidating Fina112

Condensed Consolidating Financial Information Condensed Consolidating Financial Informaiton Narrative (Details)	Dec. 31, 2017
Senior Notes [Member]
Condensed Financial Statements, Captions [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent	100.00%

Subsequent Events Subsequent Ev

Subsequent Events Subsequent Events - Narrative (Details) - USD ($) shares in Millions, $ in Millions	Sep. 29, 2015	Feb. 22, 2018	Jun. 30, 2018
Subsequent Event [Line Items]
Reduction in workforce	15.00%
Subsequent Event
Subsequent Event [Line Items]
Reduction in workforce		13.00%
FTS International, Inc. [Member] | Subsequent Event
Subsequent Event [Line Items]
Sale of stock (shares)		4.3
Proceeds from sale of stock		$ 74
Shares owned (shares)		22
Scenario, Forecast [Member]
Subsequent Event [Line Items]
Expected aggregate proceeds from sale of properties			$ 500