Expand Energy (EXE) 10-Q 1 Aug 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 25, 2018
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Trading Symbol	CHK
Entity Registrant Name	CHESAPEAKE ENERGY CORPORATION
Entity Central Index Key	895,126
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		912,274,017

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
CURRENT ASSETS:
Cash and cash equivalents ($2 and $2 attributable to our VIE)	$ 3	$ 5
Accounts receivable, net	1,060	1,322
Short-term derivative assets	0	27
Other current assets	177	171
Total Current Assets	1,240	1,525
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)	69,976	68,858
Unproved properties	3,226	3,484
Other property and equipment	1,822	1,986
Total Property and Equipment, at Cost	75,024	74,328
Less: accumulated depreciation, depletion and amortization (($463) and ($461) attributable to our VIE)	(64,185)	(63,664)
Property and equipment held for sale, net	11	16
Total Property and Equipment, Net	10,850	10,680
LONG-TERM ASSETS:
Other long-term assets	251	220
TOTAL ASSETS	12,341	12,425
CURRENT LIABILITIES:
Accounts payable	742	654
Current maturities of long-term debt, net	432	52
Accrued interest	125	137
Short-term derivative liabilities	297	58
Other current liabilities ($2 and $3 attributable to our VIE)	1,277	1,455
Total Current Liabilities	2,873	2,356
LONG-TERM LIABILITIES:
Long-term debt, net	9,238	9,921
Long-term derivative liabilities	21	4
Asset retirement obligations, net of current portion	149	162
Other long-term liabilities	177	354
Total Long-Term Liabilities	9,585	10,441
CONTINGENCIES AND COMMITMENTS (Note 4)
Chesapeake Stockholders’ Equity (Deficit):
Preferred stock, $0.01 par value, 20,000,000 shares authorized: 5,603,458 shares outstanding	1,671	1,671
Common stock, $0.01 par value, 2,000,000,000 shares authorized: 913,271,035 and 908,732,809 shares issued	9	9
Additional paid-in capital	14,408	14,437
Accumulated deficit	(16,257)	(16,525)
Accumulated other comprehensive loss	(40)	(57)
Less: treasury stock, at cost; 3,319,061 and 2,240,394 common shares	(31)	(31)
Total Chesapeake Stockholders’ Equity (Deficit)	(240)	(496)
Noncontrolling interests	123	124
Total Equity (Deficit)	(117)	(372)
TOTAL LIABILITIES AND EQUITY	$ 12,341	$ 12,425

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
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)	5,603,468	5,603,458
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized	2,000,000,000	2,000,000,000
Common stock, shares issued	913,271,035	908,732,809
Treasury stock, common shares	3,319,061	2,240,394
VIE, cash and cash equivalents	$ 3	$ 5
VIE, proved oil and natural gas properties	69,976	68,858
VIE, accumulated depreciation, depletion and amortization	(64,185)	(63,664)
VIE, other current liabilities	1,277	1,455
Variable Interest Entities, Primary Beneficiary [Member]
VIE, cash and cash equivalents	2	2
VIE, proved oil and natural gas properties	488	488
VIE, accumulated depreciation, depletion and amortization	(463)	(461)
VIE, other current liabilities	$ 2	$ 3

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
REVENUES:
Revenues	$ 2,255	$ 2,281	$ 4,744	$ 5,034
OPERATING EXPENSES:
Oil, natural gas and NGL production	138	140	285	275
Oil, natural gas and NGL gathering, processing and transportation	340	357	696	712
Production taxes	26	21	57	43
General and administrative	91	70	163	135
Restructuring and other termination costs	0	0	38	0
Provision for legal contingencies, net	4	17	9	15
Oil, natural gas and NGL depreciation, depletion and amortization	271	202	539	399
Depreciation and amortization of other assets	19	21	37	42
Impairments	46	0	46	0
Other operating (income) expense	(1)	26	(1)	417
Net (gains) losses on sales of fixed assets	(1)	1	7	1
Total Operating Expenses	2,225	1,882	4,436	4,394
INCOME FROM OPERATIONS	30	399	308	640
OTHER INCOME (EXPENSE):
Interest expense	(117)	(93)	(240)	(188)
Gains on investments	0	0	139	0
Gains on purchases or exchanges of debt	0	191	0	184
Other income (expense)	62	(1)	62	2
Total Other Income (Expense)	(55)	97	(39)	(2)
INCOME (LOSS) BEFORE INCOME TAXES	(25)	496	269	638
Income tax expense (benefit)	(9)	1	(9)	2
NET INCOME (LOSS)	(16)	495	278	636
Net income attributable to noncontrolling interests	(1)	(1)	(2)	(2)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(17)	494	276	634
Preferred stock dividends	(23)	(16)	(46)	(39)
Loss on exchange of preferred stock	0	0	0	(41)
Earnings allocated to participating securities	0	(8)	(2)	(7)
NET INCOME (LOSS) AVAILABLE TO COMMON STOCKHOLDERS	$ (40)	$ 470	$ 228	$ 547
EARNINGS (LOSS) PER COMMON SHARE:
Earnings per common share, basic (in dollars per share)	$ (0.04)	$ 0.52	$ 0.25	$ 0.60
Earnings per common share, diluted (in dollars per share)	$ (0.04)	$ 0.47	$ 0.25	$ 0.59
WEIGHTED AVERAGE COMMON AND COMMON EQUIVALENT SHARES OUTSTANDING (in millions):
Weighted average common and common equivalent shares outstanding, basic (in shares)	909	908	908	907
Weighted average common and common equivalent shares outstanding, diluted (in shares)	909	1,114	908	1,053
Oil, natrual gas and NGL [Member]
REVENUES:
Revenues	$ 982	$ 1,279	$ 2,225	$ 2,748
Marketing [Member]
REVENUES:
Revenues	1,273	1,002	2,519	2,286
OPERATING EXPENSES:
Marketing	$ 1,292	$ 1,027	$ 2,560	$ 2,355

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
NET INCOME (LOSS)		$ (16)	$ 495	$ 278	$ 636
OTHER COMPREHENSIVE INCOME, NET OF INCOME TAX:
Unrealized gains on derivative instruments	[1]	0	0	0	4
Reclassification of losses on settled derivative instruments	[1]	7	7	17	17
Other Comprehensive Income		7	7	17	21
COMPREHENSIVE INCOME (LOSS)		(9)	502	295	657
COMPREHENSIVE INCOME ATTRIBUTABLE TO NONCONTROLLING INTERESTS		(1)	(1)	(2)	(2)
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE		$ (10)	$ 501	$ 293	$ 655
[1]	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
CASH FLOWS FROM OPERATING ACTIVITIES:
NET INCOME (LOSS)	$ 278	$ 636
ADJUSTMENTS TO RECONCILE NET INCOME TO CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES:
Depreciation, depletion and amortization	576	441
Derivative (gains) losses, net	368	(522)
Cash payments on derivative settlements, net	(55)	(66)
Stock-based compensation	18	27
Net (gains) losses on sales of fixed assets	7	1
Impairments	46	0
Gains on investments	(139)	0
Gains on purchases or exchanges of debt	0	(185)
Other	(102)	(43)
Changes in assets and liabilities	94	(347)
Net Cash Provided By (Used In) Operating Activities	1,091	(58)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(979)	(1,031)
Acquisitions of proved and unproved properties	(191)	(162)
Proceeds from divestitures of proved and unproved properties	384	951
Additions to other property and equipment	(5)	(7)
Proceeds from sales of other property and equipment	74	26
Proceeds from sales of investments	74	0
Net Cash Used In Investing Activities	(643)	(223)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	6,118	2,551
Payments on revolving credit facility borrowings	(6,393)	(1,976)
Proceeds from issuance of senior notes, net	0	742
Payment for Debt Extinguishment or Debt Prepayment Cost	(122)	0
Cash paid to purchase debt	0	(1,746)
Cash paid for preferred stock dividends	(46)	(137)
Distributions to noncontrolling interest owners	(3)	(5)
Other	(4)	(17)
Net Cash Used In Financing Activities	(450)	(588)
Net decrease in cash and cash equivalents	(2)	(869)
Cash and cash equivalents, beginning of period	5	882
Cash and cash equivalents, end of period	3	13
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid, net of capitalized interest	276	217
Income taxes paid, net of refunds received	(7)	(14)
Change in accrued drilling and completion costs [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in non-cash investing and financing activities	109	87
Change in accrued acquisitions of proved and unproved properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in non-cash investing and financing activities	1	4
Change in divested proved and unproved properties [Member]
SUPPLEMENTAL DISCLOSURE OF SIGNIFICANT NON-CASH INVESTING AND FINANCING ACTIVITIES:
Change in non-cash investing and financing activities	$ (21)	$ 16

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]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Preferred Stock, Exchanged for Shares of Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Stock - Common [Member]	Parent [Member]	Noncontrolling Interest [Member]
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2016		$ 1,771			$ 14,486		$ (17,603)	$ (96)	$ (27)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exchange/conversions of 0 and 236,048 shares of preferred stock for common stock			$ (100)
Stock-based compensation					29
Exchange of preferred stock for 0 and 9,965,835 shares of common stock						$ 100
Equity component of contingent convertible notes repurchased, net of tax					(20)
Dividends on preferred stock					(137)
Net income attributable to Chesapeake	$ 634						634
Cumulative effect of accounting change							0
Hedging activity								21
Purchase of 1,468,524 and 1,189,813 shares for company benefit plans									(6)
Release of 389,857 and 73,990 shares from company benefit plans									1
Chesapeake stockholders’ equity, end of period at Jun. 30, 2017		1,671		$ 9	14,458		(16,969)	(75)	(32)	$ (938)
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2016											$ 257
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	(2)										2
Distributions to noncontrolling interest owners											(5)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2017											254
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	(684)
TOTAL EQUITY (DEFICIT)	(372)
Chesapeake stockholders’ equity, beginning of period at Dec. 31, 2017	(496)	1,671			14,437		(16,525)	(57)	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exchange/conversions of 0 and 236,048 shares of preferred stock for common stock			$ 0
Stock-based compensation					17
Exchange of preferred stock for 0 and 9,965,835 shares of common stock						$ 0
Equity component of contingent convertible notes repurchased, net of tax					0
Dividends on preferred stock					(46)
Net income attributable to Chesapeake	276						276
Cumulative effect of accounting change							(8)
Hedging activity								17
Purchase of 1,468,524 and 1,189,813 shares for company benefit plans									(4)
Release of 389,857 and 73,990 shares from company benefit plans									4
Chesapeake stockholders’ equity, end of period at Jun. 30, 2018	(240)	$ 1,671		$ 9	$ 14,408		$ (16,257)	$ (40)	$ (31)	$ (240)
Stockholders' equity attributable to noncontrolling interest, beginning of period at Dec. 31, 2017	124										124
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to noncontrolling interests	(2)										2
Distributions to noncontrolling interest owners											(3)
Stockholders' equity attributable to noncontrolling interest, end of period at Jun. 30, 2018	123										$ 123
Increase (Decrease) in Stockholders' Equity [Roll Forward]
TOTAL EQUITY (DEFICIT)	$ (117)

CONSOLIDATED STATEMENTS OF STO8

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - shares	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Treasury Stock - Common [Member]
Purchase of shares for company benefit plans (in shares)	1,468,524	1,189,813
Release of shares from company benefit plans (in shares)	389,857	73,990
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Preferred stock [Member]
Conversion of stock, shares converted (in shares)	0	236,048
Preferred Stock, Exchanged for Shares of Common Stock [Member] | Additional Paid-in Capital [Member]
Exchange of preferred stock (in shares)	0	9,965,835

Basis of Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Basis of Presentation The accompanying condensed consolidated financial statements of Chesapeake were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures have been condensed or omitted. This Form 10-Q relates to the three and six months ended June 30, 2018 (the “Current Quarter” and the “Current Period”, respectively) and the three and six months ended June 30, 2017 (the “Prior Quarter” and the “Prior Period”, respectively). Our annual report on Form 10-K for the year ended December 31, 2017 (“2017 Form 10-K”) should be read in conjunction with this Form 10-Q. The accompanying condensed consolidated financial statements reflect all normal recurring adjustments which, in the opinion of management, are necessary for a fair statement of our condensed consolidated financial statements and accompanying notes and include the accounts of our direct and indirect wholly owned subsidiaries and entities in which we have a controlling financial interest. Intercompany accounts and balances have been eliminated . Recently Issued Accounting Standards The Financial Accounting Standards Board (FASB) issued Revenue from Contracts with Customers (Topic 606) superseding virtually all existing revenue recognition guidance. We adopted this new standard in the first quarter of 2018 using the modified retrospective approach. We applied the new standard to all contracts that were not completed as of January 1, 2018 and reflected the aggregate effect of all modifications in determining and allocating the transaction price. See Note 10 for further details regarding our adoption of Topic 606. In February 2018, the FASB issued Accounting Standards Update (ASU) 2018-02, Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income . The new standard allows for stranded tax effects resulting from tax reform legislation known as the Tax Cuts and Jobs Act of 2017 (the “Tax Act”) previously recognized in accumulated other comprehensive income to be reclassified to retained earnings. For public business entities, the amendments are effective for annual periods, including interim periods within the annual periods, beginning after December 15, 2018. Early adoption is permitted in any interim or annual period, 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. 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. 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 for leases with terms in excess of 12 months. In January 2018, the FASB issued an update permitting an entity to elect an optional transition practical expedient to not evaluate land easements that existed or expired before the adoption of Topic 842 and were not previously accounted for as leases. Currently the guidance would be applied using a modified retrospective transition method, which requires applying the new guidance to leases that exist or are entered into after the beginning of the earliest period in the financial statements. However, the FASB recently issued Proposed ASU No. 2018-200, Leases (Topic 842), Targeted Improvements which would allow entities to apply the transition provisions of the new standard at its adoption date instead of at the earliest comparative period presented in the consolidated financial statements. The proposed ASU will allow entities to continue to apply the legacy guidance in Topic 840, including its disclosure requirements, in the comparative periods presented in the year the new leases standard is adopted. Entities that elect this option would still adopt the new leases standard using a modified retrospective transition method, but would recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption rather than in the earliest period presented. Early adoption is permitted, but we do not plan to early adopt . The standard will not apply to our leases of mineral rights. Using the revised framework, we have completed our assessment of lease categories that we believe will be affected by the new standard. We are continuing to assess the accounting treatment for these leases and the resulting impacts to our consolidated financial statements and related disclosures.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2018
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share (EPS) is calculated using the weighted average number of common shares outstanding during the period and includes the effect of any participating securities as appropriate. Participating securities consist of unvested restricted stock issued to our employees and non-employee directors that provide dividend rights. Diluted EPS is calculated assuming the issuance of common shares for all potentially dilutive securities, provided the effect is not antidilutive. For all periods presented, our 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. A reconciliation of basic EPS and diluted EPS is as follows: Three Months Ended Six Months Ended 2018 2017 2018 2017 (in millions, except per share data) Net income (loss) available to common stockholders $ (40 ) $ 470 $ 228 $ 547 Effect of dilutive securities — 59 — 72 Diluted income (loss) available to common stockholders $ (40 ) $ 529 $ 228 $ 619 Weighted average common and common equivalent shares outstanding - basic 909 908 908 907 Effect of dilutive securities — 206 — 146 Weighted average common and common equivalent shares outstanding - diluted 909 1,114 908 1,053 Net income per share attributable to Chesapeake: Basic $ (0.04 ) $ 0.52 $ 0.25 $ 0.60 Diluted $ (0.04 ) $ 0.47 $ 0.25 $ 0.59 Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive: Common stock equivalent of our preferred stock outstanding 60 — 60 60 Common stock equivalent of our convertible senior notes outstanding 146 — 146 — Common stock equivalent of our preferred stock outstanding prior to exchange — — — 1 Participating securities 1 1 1 1

Debt

Debt	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Debt	Debt Our long-term debt consisted of the following as of June 30, 2018 and December 31, 2017: June 30, 2018 December 31, 2017 Principal Amount Carrying Principal Carrying ($ in millions) 7.25% senior notes due 2018 $ 44 $ 44 $ 44 $ 44 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 437 437 437 437 6.875% senior notes due 2020 227 227 227 227 6.125% senior notes due 2021 548 548 548 548 5.375% senior notes due 2021 267 267 267 267 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 1,416 1,847 1,416 1,895 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,300 1,290 1,300 1,290 5.5% convertible senior notes due 2026 (a)(b) 1,250 852 1,250 837 8.00% senior notes due 2027 1,300 1,298 1,300 1,298 2.25% contingent convertible senior notes due 2038 (a) 9 8 9 8 Term loan due 2021 1,233 1,233 1,233 1,233 Revolving credit facility 506 506 781 781 Debt issuance costs — (57 ) — (63 ) Interest rate derivatives — 1 — 2 Total debt, net 9,706 9,670 9,981 9,973 Less current maturities of long-term debt, net (c) (433 ) (432 ) (53 ) (52 ) Total long-term debt, net $ 9,273 $ 9,238 $ 9,928 $ 9,921 ___________________________________________ (a) 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. (b) Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. During the Current Quarter, the price of our common stock was below the threshold level for conversion and, as a result, the holders do not have the option to convert their notes in the third quarter of 2018. (c) As of June 30, 2018 , current maturities of long-term debt, net includes our 7.25% Senior Notes due December 2018, our Floating Rate Senior Notes due April 2019, and due to the holders’ put option, our 2.25% Contingent Convertible Notes due December 2038. Debt Retirements In the Prior Period, we retired $1.604 billion principal amount of our outstanding senior notes, senior secured second lien notes and contingent convertible notes through purchases in the open market, tender offers or repayment upon maturity for $1.746 billion . For the open market repurchases and tender offers, we recorded aggregate net gains of approximately $191 million and $184 million in the Prior Quarter and the Prior Period, respectively. Revolving Credit Facility We have a senior secured revolving credit facility currently subject to a $3.8 billion borrowing base that matures in December 2019. As of June 30, 2018 , we had outstanding borrowings of $506 million under the revolving credit facility and had used $183 million of the revolving credit facility for various letters of credit. Borrowings under the revolving credit facility bear interest at a variable rate. In the Current Quarter, we completed a scheduled borrowing base redetermination review and our lenders reaffirmed our $3.8 billion borrowing base. Our next scheduled borrowing base redetermination is scheduled for the fourth quarter of 2018. Our revolving credit facility is subject to various financial and other covenants. The terms of the revolving credit facility include covenants limiting, among other things, our ability to incur additional indebtedness, make investments or loans, create liens, consummate mergers and similar fundamental changes, make restricted payments, make investments in unrestricted subsidiaries and enter into transactions with affiliates. As of June 30, 2018 , we were in compliance with all applicable financial covenants under the credit agreement and we were able to borrow up to the full availability under the revolving credit facility. Fair Value of Debt We estimate the fair value of our senior notes based on the market value of our publicly traded debt as determined based on the yield of our senior notes (Level 1). The fair value of all other debt is based on a market approach using estimates provided by an independent investment financial data services firm (Level 2). Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: June 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 432 $ 432 $ 52 $ 53 Long-term debt (Level 1) $ 2,256 $ 2,261 $ 2,633 $ 2,629 Long-term debt (Level 2) $ 6,982 $ 7,215 $ 7,286 $ 7,301

Contingencies and Commitments

Contingencies and Commitments	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Contingencies and Commitments	Contingencies and Commitments There have been no material developments in previously reported legal or environmental contingencies or commitments other than the items discussed below. For a discussion of commitments and contingencies, see “Contingencies and Commitments,” Note 4 to the Consolidated Financial Statements in our 2017 Form 10-K. Contingencies Regulatory and Related Proceedings . We have previously disclosed receiving U.S. Postal Service and state subpoenas seeking information on our royalty payment practices. The U.S. Postal Service inquiry and all such outstanding state subpoenas have been resolved. We have also previously disclosed 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. On April 12, 2018, we reached a tentative settlement to resolve substantially all Oklahoma civil class action antitrust cases for an immaterial amount. On July 28, 2017, OOGC America LLC (OOGC) filed a demand for arbitration with the American Arbitration Association against Chesapeake Exploration, L.L.C., our wholly owned subsidiary, in connection with OOGC’s purchase of certain oil and gas leases and other assets pursuant to a Purchase and Sale Agreement entered into on October 10, 2010. In connection with the sale, we also entered into a Development Agreement with OOGC, dated November 15, 2010 (the “Development Agreement”), which governs each of our rights and obligations with respect to the sale, including the transportation and marketing of oil and gas. OOGC’s breach of contract, breach of agency and fiduciary duties and other claims generally allege, among other things, that we subjected OOGC to excessive rates for gathering and other services provided for under the Development Agreement and interfered with OOGC’s right to audit the documents that supported those rates. OOGC seeks relief that may be material, including unspecified damages, attorneys’ fees, costs and expenses, disgorgement and various declaratory judgments. We intend to vigorously defend these claims. On July 24, 2018, Healthcare of Ontario Pension Plan (HOOPP) filed a demand for arbitration with the American Arbitration Association regarding HOOPP’s purchase of our interest in Chaparral Energy, Inc. stock for $215 million on January 5, 2014. HOOPP claims that the Company engaged in material misrepresentations and fraud, and that we violated the Exchange Act and Oklahoma Uniform Securities Act. HOOPP seeks either rescission or $215 million in monetary damages, and in either case, interest, attorney’s fees, disgorgement and punitive damages. We intend to vigorously defend these claims. Commitments Gathering, Processing and Transportation Agreements We have contractual commitments with midstream service companies and pipeline carriers for future gathering, processing and transportation of oil, natural gas and NGL to move certain of our production to market. Working interest owners and royalty interest owners, where appropriate, will be responsible for their proportionate share of these costs. Commitments related to gathering, processing and transportation agreements are not recorded as obligations in the accompanying consolidated balance sheets; however, they are reflected in our estimates of proved reserves. The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: June 30, ($ in millions) 2018 $ 537 2019 1,047 2020 992 2021 900 2022 792 2023 – 2035 4,434 Total $ 8,702 In addition, we have entered into long-term agreements for certain natural gas gathering and related services within specified acreage dedication areas in exchange for cost-of-service based fees redetermined annually, or tiered fees based on volumes delivered relative to scheduled volumes. Future gathering fees may vary with the applicable agreement.

Other Liabilities

Other Liabilities	6 Months Ended
	Jun. 30, 2018
Other Liabilities Disclosure [Abstract]
Other Liabilities	Other Liabilities Other current liabilities as of June 30, 2018 and December 31, 2017 are detailed below: June 30, December 31, ($ in millions) Revenues and royalties due others $ 488 $ 612 Accrued drilling and production costs 261 216 Joint interest prepayments received 81 74 Accrued compensation and benefits 156 214 Other accrued taxes 104 43 Other 187 296 Total other current liabilities $ 1,277 $ 1,455 Other long-term liabilities as of June 30, 2018 and December 31, 2017 are detailed below: June 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ — $ 156 Unrecognized tax benefits 81 101 Other 96 97 Total other long-term liabilities $ 177 $ 354 ____________________________________________ (a) In the Current Quarter, we repurchased previously conveyed overriding royalty interests (ORRI) from the CHK Utica, L.L.C. investors and extinguished our obligation to convey future ORRIs to the CHK Utica, L.L.C. investors for combined consideration of $199 million . The total CHK Utica ORRI conveyance obligation extinguished in the Current Quarter was $183 million , of which, $30 million was recorded in current liabilities and $153 million was recorded in long-term liabilities. The fair value of the consideration allocated to the extinguishment of liability, $122 million , was less than the carrying amount of the conveyance obligation and resulted in a gain of $61 million recognized in other income on our condensed consolidated statement of operations. The fair value of the consideration allocated to the purchase of ORRIs on proved producing properties was $77 million and recorded in proved oil and natural gas properties in our condensed consolidated balance sheet.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We estimate our annual effective tax rate for continuing operations in recording our quarterly income tax provision (or benefit) for the various jurisdictions in which we operate. The tax effects of statutory rate changes, significant unusual or infrequent items, and certain changes in the assessment of the realizability of deferred tax assets are excluded from the determination of our estimated annual effective tax rate as such items are recognized as discrete items in the quarter in which they occur. For the Current Quarter, our estimated annual effective tax rate remains nominal as a result of having a full valuation allowance against our net deferred tax asset. Based on our projected operating results for the subsequent 2018 quarters, we project remaining in a net deferred tax asset position as of December 31, 2018. Based on all available positive and negative evidence, including estimates of future taxable income, we believe it is more-likely-than-not that these deferred tax assets will not be realized. A significant piece of objectively verifiable negative evidence evaluated is the cumulative loss incurred over the rolling three-year period ending June 30, 2018. Such evidence limits our ability to consider various forms of subjective positive evidence, such as our projections for future growth and earnings. A valuation allowance was recorded against substantially all of our net deferred tax asset as of December 31, 2017 and against all of our net deferred tax asset as of June 30, 2018. We are subject to U.S. federal income tax as well as income and capital taxes in various state jurisdictions in which we operate. We recorded a $9 million income tax benefit in the Current Quarter and the Current Period. This benefit was a result of discrete items consisting of a $13 million reduction to the liability for state unrecognized tax benefits due to the expiration of applicable statutes of limitations which was partially offset by eliminating a deferred tax asset for alternative minimum tax carryforwards in the amount of $3 million and recording additional state income tax expense of $1 million relating primarily to amended state income tax returns. A further reduction to the liability for state unrecognized tax benefits was also recorded against interest expense in the amount of $4 million . 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 reducing 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). The various estimates included in determining our tax provision as of December 31, 2017 remain provisional through the six months ended June 30, 2018 and may be adjusted through subsequent events such as the filing of the 2017 consolidated federal income tax return and the issuance of additional guidance such as new Treasury Regulations. Moreover, we are still in the process of evaluating the full impact of the Tax Act both at the federal and state level.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation Our share-based compensation program consists of restricted stock, stock options, performance share units (PSUs) and cash restricted stock units (CRSUs) granted to employees and restricted stock granted to non-employee directors under our long term incentive plans. The restricted stock and stock options are equity-classified awards and the PSUs and CRSUs are liability-classified awards. Equity-Classified Awards Restricted Stock. We grant restricted stock units to employees and non-employee directors. A summary of the changes in unvested restricted stock during the Current Period is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value (in thousands) Unvested restricted stock as of January 1, 2018 13,178 $ 6.37 Granted 4,765 $ 3.57 Vested (5,207 ) $ 7.73 Forfeited (1,295 ) $ 6.13 Unvested restricted stock as of June 30, 2018 11,441 $ 4.61 The aggregate intrinsic value of restricted stock that vested during the Current Period was approximately $17 million based on the stock price at the time of vesting. As of June 30, 2018 , there was approximately $40 million of total unrecognized compensation expense related to unvested restricted stock. The expense is expected to be recognized over a weighted average period of approximately 2.20 years. Stock Options. In the Current Period and the Prior Period, we granted members of management stock options that vest ratably over a three -year period. Each stock option award has an exercise price equal to the closing price of our common stock on the grant date. Outstanding options expire seven years to ten years from the date of grant. We utilize the Black-Scholes option pricing model to measure the fair value of stock options. The expected life of an option is determined using the simplified method. Volatility assumptions are estimated based on an average of historical volatility of Chesapeake stock over the expected life of an option. The risk-free interest rate is based on the U.S. Treasury rate in effect at the time of the grant over the expected life of the option. The dividend yield is based on an annual dividend yield, taking into account our dividend policy, over the expected life of the option. We used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period: Expected option life – years 6.0 Volatility 63.55 % Risk-free interest rate 2.72 % Dividend yield — % The following table provides information related to stock option activity in the Current Period: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2018 16,285 $ 8.25 7.73 $ 1 Granted 3,611 $ 3.01 Exercised — $ — $ — Expired (602 ) $ 13.83 Forfeited (995 ) $ 5.45 Outstanding as of June 30, 2018 18,299 $ 7.18 7.71 $ 14 Exercisable as of June 30, 2018 8,250 $ 10.73 6.34 $ 3 ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option. As of June 30, 2018 , there was $20 million of total unrecognized compensation expense related to stock options. The expense is expected to be recognized over a weighted average period of approximately 1.94 years . Restricted Stock and Stock Option Compensation. We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended Six Months Ended 2018 2017 2018 2017 ($ in millions) General and administrative expenses $ 8 $ 12 $ 15 $ 20 Oil and natural gas properties 2 3 4 7 Oil, natural gas and NGL production expenses 1 4 3 7 Total restricted stock and stock option compensation $ 11 $ 19 $ 22 $ 34 Liability-Classified Awards Performance Share Units. We granted PSUs to senior management that vest ratably over a three -year performance period and are settled in cash. The ultimate amount earned is based on achievement of performance metrics established by the Compensation Committee of the Board of Directors. Compensation expense associated with PSU awards is recognized over the service period based on the graded-vesting method. The value of the PSU awards at the end of each reporting period is dependent upon our estimates of the underlying performance measures. For PSUs granted in 2017 and 2016, performance metrics include a total shareholder return (TSR) component, which can range from 0% to 100% and an operational performance component based on finding and development costs, which can range from 0% to 100% , resulting in a maximum payout of 200% . The payout percentage for the 2016 and 2017 PSU awards is capped at 100% if our absolute TSR is less than zero . The PSUs are settled in cash on the third anniversary of the awards. We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the 2017 and 2016 PSU awards. Grant Date Assumptions Assumption 2017 Awards 2016 Awards Volatility 80.65 % 49.74 % Risk-free interest rate 1.54 % 1.13 % Dividend yield for value of awards — % — % Reporting Period Assumptions Assumption 2017 Awards 2016 Awards Volatility 51.31 % 59.84 % Risk-free interest rate 2.43 % 2.11 % Dividend yield for value of awards — % — % The PSUs are subsequently adjusted, based on adjustments to the above assumptions through the end of each subsequent reporting period, through the end of the performance period. For PSUs granted in 2018, performance metrics include an operational performance component based on a ratio of cumulative earnings before interest expense, income taxes, and depreciation, depletion and amortization expense (EBITDA) to capital expenditures, for which payout can range from 0% to 200% . The vested PSUs are settled in cash on each of the three annual vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the PSUs. The PSUs are subsequently adjusted, based on changes in our stock price through the end of each subsequent reporting period, through the end of the performance period. Cash Restricted Stock Units . In the Current Period, we granted CRSUs to employees that vest straight-line over a three-year period and are settled in cash on each of the three annual vesting dates. The ultimate amount earned is based on the closing price of our common stock on each of the vesting dates. We used the closing price of our common stock on the grant date to determine the grant date fair value of the CRSUs. The CRSUs are subsequently adjusted, based on changes in our stock price through the end of each subsequent reporting period, through the end of each vesting period. The following table presents a summary of our liability-classified awards: Grant Date Fair Value June 30, 2018 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2018 PSU Awards: Payable 2019, 2020 and 2021 3,992,358 $ 12 $ 21 $ — 2017 PSU Awards: Payable 2020 1,217,774 $ 8 $ 8 $ 5 2016 PSU Awards: Payable 2019 2,348,893 $ 10 $ 16 $ 14 2018 CRSU Awards: Payable 2019, 2020 and 2021 16,367,724 $ 49 $ 86 $ —

Derivative and Hedging Activiti

Derivative and Hedging Activities	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Hedging Activities	Derivative and Hedging Activities We use derivative instruments to reduce our exposure to fluctuations in future commodity prices and to protect our expected operating cash flow against significant market movements or volatility. All of our oil, natural gas and NGL derivative instruments are net settled based on the difference between the fixed-price payment and the floating-price payment, resulting in a net amount due to or from the counterparty. None of our open oil, natural gas and NGL derivative instruments were designated for hedge accounting as of June 30, 2018 or December 31, 2017. Oil, Natural Gas and NGL Derivatives As of June 30, 2018 and December 31, 2017, 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 buy, 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 pay the market price. If the market price is between the put and the call strike prices, no payments are due from either party. Three-way collars include the sale by us of an additional put option in exchange for a more favorable strike price on the call option. This eliminates the counterparty’s downside exposure below the second put option strike price. • Basis Protection Swaps : These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity. The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of June 30, 2018 and December 31, 2017 are provided below: June 30, 2018 December 31, 2017 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 26 $ (271 ) 21 $ (151 ) Three-way collars 1 (14 ) 2 (10 ) Call swaptions 2 (32 ) 2 (13 ) Basis protection swaps 11 6 11 (9 ) Total oil 40 (311 ) 36 (183 ) Natural gas (bcf): Fixed-price swaps 240 3 532 149 Three-way collars 87 — — — Collars 24 2 47 11 Call options 77 — 110 (3 ) Basis protection swaps 45 (1 ) 65 (7 ) Total natural gas 473 4 754 150 NGL (mmgal): Fixed-price swaps 114 (11 ) 33 (2 ) Total estimated fair value $ (318 ) $ (35 ) 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) . Effect of Derivative Instruments – Condensed Consolidated Balance Sheets The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2018 and December 31, 2017 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of June 30, 2018 Commodity Contracts: Short-term derivative asset $ 20 $ (20 ) $ — Long-term derivative asset 7 (7 ) — Short-term derivative liability (317 ) 20 (297 ) Long-term derivative liability (28 ) 7 (21 ) Total derivatives $ (318 ) $ — $ (318 ) 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 derivatives $ (35 ) $ — $ (35 ) Effect of Derivative Instruments – Condensed Consolidated Statements of Operations The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2018 2017 2018 2017 ($ in millions) Oil, natural gas and NGL revenues $ 1,233 $ 1,079 $ 2,593 $ 2,226 Gains (losses) on undesignated oil, natural gas and NGL derivatives (244 ) 207 (351 ) 539 Losses on terminated cash flow hedges (7 ) (7 ) (17 ) (17 ) Total oil, natural gas and NGL revenues $ 982 $ 1,279 $ 2,225 $ 2,748 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: Three Months Ended June 30, 2018 2017 Before After Before After ($ in millions) Balance, beginning of period $ (104 ) $ (47 ) $ (139 ) (82 ) Losses reclassified to income 7 7 7 7 Balance, end of period $ (97 ) $ (40 ) (132 ) (75 ) Six Months Ended June 30, 2018 2017 Before After Before After ($ in millions) Balance, beginning of period $ (114 ) $ (57 ) $ (153 ) $ (96 ) Net change in fair value — — 4 4 Losses reclassified to income 17 17 17 17 Balance, end of period $ (97 ) $ (40 ) $ (132 ) $ (75 ) The accumulated other comprehensive loss as of June 30, 2018 represents the net deferred loss associated with commodity derivative contracts that were previously designated as cash flow hedges for which the original contract months are yet to occur. Remaining deferred gain or loss amounts will be recognized in earnings in the month for which the original contract months are to occur. As of June 30, 2018 , we expect to transfer approximately $33 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 June 30, 2018 , 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. In addition, we enter into bilateral hedging agreements with other counterparties. The counterparties’ and our obligations under the bilateral hedging agreements must be secured by cash or letters of credit to the extent that any mark-to-market amounts owed to us or by us exceed defined thresholds. As of June 30, 2018 and December 31, 2017 , we did not have any cash collateral balances for our derivatives. Fair Value The fair value of our derivatives is based on third-party pricing models which utilize inputs that are either readily available in the public market, such as oil, natural gas and NGL forward curves and discount rates, or can be corroborated from active markets or broker quotes. These values are compared to the values given by our counterparties for reasonableness. Since oil, natural gas and NGL swaps do not include optionality and therefore generally have no unobservable inputs, they are classified as Level 2. All other derivatives have some level of unobservable input, such as volatility curves, and are therefore classified as Level 3. Derivatives are also subject to the risk that either party to a contract will be unable to meet its obligations. We factor non-performance risk into the valuation of our derivatives using current published credit default swap rates. To date, this has not had a material impact on the values of our derivatives. The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 20 $ 7 $ 27 Commodity liabilities — (293 ) (52 ) (345 ) Total derivatives $ — $ (273 ) $ (45 ) $ (318 ) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives ($ in millions) Balance, as of January 1, 2018 $ (15 ) Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) Total purchases, issuances, sales and settlements: Settlements 2 Balance, as of June 30, 2018 $ (45 ) Balance, as of January 1, 2017 $ (10 ) Total gains (losses) (realized/unrealized): Included in earnings (a) 19 Total purchases, issuances, sales and settlements: Settlements 1 Balance, as of June 30, 2017 $ 10 ___________________________________________ (a) Commodity Derivatives 2018 2017 ($ in millions) Total gains (losses) included in earnings for the period $ (32 ) $ 19 Change in unrealized gains (losses) related to assets still held at reporting date $ (30 ) $ 12 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 June 30, 2018 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 17.16% – 30.26% 25.01% $ (47 ) Natural gas trades Natural gas price volatility curves 14.23% – 46.86% 18.30% $ 2

Oil and Natural Gas Property Tr

Oil and Natural Gas Property Transactions	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Oil and Natural Gas Property Transactions	Oil and Natural Gas Property Transactions Under full cost accounting rules, we accounted for the sales of oil and natural gas properties discussed below as adjustments to capitalized costs, with no recognition of gain or loss as the sales did not involve a significant change in proved reserves or significantly alter the relationship between costs and proved reserves. In the Current Period, we sold portions of our acreage, producing properties and other related property and equipment in the Mid-Continent, including our Mississippian Lime assets, for approximately $491 million , subject to certain customary closing adjustments. Included in the sales were approximately 238,500 net acres and interests in approximately 3,200 wells. Also, in the Current Quarter and the Current Period, we received proceeds of approximately $5 million and $23 million , respectively, subject to customary closing adjustments, for the sale of other oil and natural gas properties covering various operating areas. In the Prior Period, we sold portions of our acreage and producing properties in our Haynesville Shale operating area in northern Louisiana for approximately $915 million , subject to certain customary closing adjustments. Included in the sales were approximately 119,500 net acres and interests in 576 wells that were producing approximately 80 mmcf of gas per day at the time of closing. Also in the Prior Quarter and the Prior Period, we received proceeds of approximately $63 million and $83 million , respectively, net of post-closing adjustments, for the sale of other oil and natural gas properties covering various operating areas. 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. As of June 30, 2018 , 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 June 30, 2018 were as follows: Volume Remaining as of June 30, 2018 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 32 0.3 28.5 0.8 34.8

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The FASB issued Revenue from Contracts with Customers (Topic 606) superseding virtually all existing revenue recognition guidance. We adopted this new standard in the first quarter of 2018 using the modified retrospective approach. We applied the new standard to all contracts that were not completed as of January 1, 2018 and reflected the aggregate effect of all modifications in determining and allocating the transaction price. The cumulative effect of adoption of $8 million did not have a material impact on our condensed consolidated financial statements. However, the adoption did result in certain purchase and sale contracts being recorded on a net basis, as an agent, rather than on a gross basis, as principal, due to management’s evaluation under new considerations within Topic 606 that indicated we do not have control over the specified commodity in purchase and sale contracts with the same counterparty. Such presentation change did not have an impact on income (loss) from operations, earnings per share or cash flows. In accordance with the new revenue standard requirements, the disclosure of the impact of adoption on our condensed consolidated balance sheet and condensed consolidated statement of operations was as follows: Before adoption of ASC 606 Adjustments As Reported ($ in millions) Balance Sheet as of June 30, 2018 Other current liabilities $ 1,275 $ 2 $ 1,277 Other long-term liabilities $ 172 $ 5 $ 177 Accumulated deficit $ (16,249 ) $ (8 ) $ (16,257 ) Statement of Operations for the Three Months Ended June 30, 2018 Marketing revenues $ 1,449 $ (176 ) $ 1,273 Marketing operating expenses $ 1,469 $ (177 ) $ 1,292 Statement of Operations for the Six Months Ended June 30, 2018 Marketing revenues $ 2,810 $ (291 ) $ 2,519 Marketing operating expenses $ 2,852 $ (292 ) $ 2,560 Revenue from the sale of oil, natural gas and NGL is recognized upon the transfer of control of the products, which is typically when the products are delivered to customers. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration we expect to receive in exchange for those products. Revenue from contracts with customers includes the sale of our oil, natural gas and NGL production (recorded as oil, natural gas and NGL revenues in the condensed consolidated statements of operations) as well as the sale of certain of our joint interest holders’ production which we purchase under joint operating arrangements (recorded in marketing revenues in the condensed consolidated statements of operations). In connection with the marketing of these products, we obtain control of 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. Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 days. There are no significant judgments that significantly affect the amount or timing of revenue from contracts with customers. We also earn revenue from other sources, including from a variety of derivative and hedging activities to reduce our exposure to fluctuations in future commodity prices and to protect our expected operating cash flow against significant market movements or volatility, (recorded within oil, natural gas and NGL revenues in the condensed consolidated statements of operations) as well as a variety of oil, natural gas and NGL purchase and sale contracts with third parties for various commercial purposes, including credit risk mitigation and satisfaction of our pipeline delivery commitments (recorded within marketing revenues in the condensed consolidated statements of operations). In circumstances where we act as an agent rather than a principal, our results of operations related to oil, natural gas and NGL marketing activities are presented on a net basis. These purchase and sales contracts were accounted for as derivatives under Derivatives and Hedging (Topic 815) and were not elected as normal purchase or normal sales. We considered the principal versus agent guidance in Topic 606 in determining whether the gains and losses on these derivatives should be reported on a gross or net basis . The following table shows revenue disaggregated by operating area and product type, for the Current Quarter and the Current Period: Three Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 169 $ — $ 169 Haynesville 1 199 — 200 Eagle Ford 389 42 46 477 Utica 62 103 61 226 Mid-Continent 62 15 12 89 Powder River Basin 52 11 9 72 Revenue from contracts with customers 566 539 128 1,233 Losses on oil, natural gas and NGL derivatives (202 ) (35 ) (14 ) (251 ) Oil, natural gas and NGL revenue $ 364 $ 504 $ 114 $ 982 Marketing revenue from contracts with customers $ 732 $ 235 $ 102 $ 1,069 Other marketing revenue 145 59 — 204 Marketing revenue $ 877 $ 294 $ 102 $ 1,273 Six Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 463 $ — $ 463 Haynesville 2 409 — 411 Eagle Ford 749 84 85 918 Utica 119 219 113 451 Mid-Continent 138 47 30 215 Powder River Basin 95 23 17 135 Revenue from contracts with customers 1,103 1,245 245 2,593 Losses on oil, natural gas and NGL derivatives (288 ) (67 ) (13 ) (368 ) Oil, natural gas and NGL revenue $ 815 $ 1,178 $ 232 $ 2,225 Marketing revenue from contracts with customers $ 1,418 $ 528 $ 212 $ 2,158 Other marketing revenue 262 99 — 361 Marketing revenue $ 1,680 $ 627 $ 212 $ 2,519 Accounts Receivable Our accounts receivable are primarily from purchasers of oil, natural gas and NGL and from exploration and production companies that own interests in properties we operate. This industry concentration could affect our overall exposure to credit risk, either positively or negatively, because our purchasers and joint working interest owners may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of all our counterparties and we generally require letters of credit or parent guarantees for receivables from parties deemed to have sub-standard credit, unless the credit risk can otherwise be mitigated. We utilize an allowance method in accounting for bad debt based on historical trends in addition to specifically identifying receivables that we believe may be uncollectible. Accounts receivable as of June 30, 2018 and December 31, 2017 are detailed below: June 30, 2018 December 31, 2017 ($ in millions) Oil, natural gas and NGL sales $ 801 $ 959 Joint interest 206 209 Other 68 184 Allowance for doubtful accounts (15 ) (30 ) Total accounts receivable, net $ 1,060 $ 1,322

Investments

Investments	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investments	Investments In the Current Period, FTS International, Inc. (NYSE: FTSI) completed an initial public offering. Due to the offering, the ownership percentage of our equity method investment in FTSI decreased from approximately 29% to 24% and resulted in a gain of $78 million . In addition, we sold approximately 4.3 million shares of FTSI in the offering for net proceeds of approximately $74 million and recognized a gain of $61 million decreasing our ownership percentage to approximately 20% . We continue to hold approximately 22.0 million shares in the publicly traded company.

Impairments

Impairments	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Impairments	Impairments In the Current Quarter, we have determined that certain of our other fixed assets will either be sold or disposed before the end of their useful lives indicating the carrying value may not be recoverable. As a result, we recognized an impairment loss of $42 million in the Current Quarter for the difference between the carrying amount and fair value of the assets.

Other Operating Expenses

Other Operating Expenses	6 Months Ended
	Jun. 30, 2018
Asset Impairment Charges [Abstract]
Other Operating Expenses	Other Operating Expenses In the Prior Quarter and the Prior Period, we terminated future natural gas transportation commitments related to divested assets for cash payments of $23 million and $126 million . In the Prior Period, we paid $290 million to assign an oil transportation agreement to a third party.

Restructuring and Other Termina

Restructuring and Other Termination Costs	6 Months Ended
	Jun. 30, 2018
Restructuring and Related Activities [Abstract]
Restructuring and Other Termination Costs	Restructuring and Other Termination Costs Workforce Reduction On January 30, 2018, we underwent a reduction in workforce impacting approximately 13% of employees across all functions, primarily on our Oklahoma City campus. In connection with the reduction, we incurred a total charge in the Current Period of approximately $38 million for one-time termination benefits. The following table summarizes our restructuring liabilities: Other Current Liabilities ($ in millions) Balance as of December 31, 2017 $ — Initial restructuring recognition on January 30, 2018 38 Termination benefits paid (38 ) Balance as of June 30, 2018 $ —

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Recurring Fair Value Measurements Other Current Assets. Assets related to our deferred compensation plan are included in other current assets. The fair value of these assets is determined using quoted market prices, as they consist of exchange-traded securities. Other Current Liabilities . Liabilities related to our deferred compensation plan are included in other current liabilities. The fair values of these liabilities are determined using quoted market prices, as the plan consists of exchange-traded mutual funds. Financial Assets (Liabilities) . The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Financial Assets (Liabilities): Other current assets $ 53 $ — $ — $ 53 Other current liabilities (52 ) — — (52 ) Total $ 1 $ — $ — $ 1 As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 ) See Note 3 for information regarding fair value measurement of our debt instruments. See Note 8 for information regarding fair value measurement of our derivatives.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2018
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information Chesapeake Energy Corporation is a holding company, owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under our outstanding senior notes, contingent convertible senior notes, term loan and revolving credit facility listed in Note 3 are fully and unconditionally guaranteed, jointly and severally, by certain of our 100% owned subsidiaries. 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 June 30, 2018 and December 31, 2017 and for the three and six months ended June 30, 2018 and 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 JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 5 $ 1 $ 2 $ (5 ) $ 3 Other current assets 63 1,173 1 — 1,237 Intercompany receivable, net 8,132 31 175 (8,338 ) — Total Current Assets 8,200 1,205 178 (8,343 ) 1,240 PROPERTY AND EQUIPMENT: Oil and natural gas properties at cost, based on full cost accounting, net 521 9,129 25 — 9,675 Other property and equipment, net — 1,164 — — 1,164 Property and equipment held for sale, net — 11 — — 11 Total Property and Equipment, Net 521 10,304 25 — 10,850 LONG-TERM ASSETS: Other long-term assets 44 207 — — 251 Investments in subsidiaries and intercompany advances 907 78 — (985 ) — TOTAL ASSETS $ 9,672 $ 11,794 $ 203 $ (9,328 ) $ 12,341 CURRENT LIABILITIES: Current liabilities $ 561 $ 2,315 $ 2 $ (5 ) $ 2,873 Intercompany payable, net 32 8,306 — (8,338 ) — Total Current Liabilities 593 10,621 2 (8,343 ) 2,873 LONG-TERM LIABILITIES: Long-term debt, net 9,238 — — — 9,238 Other long-term liabilities 81 266 — — 347 Total Long-Term Liabilities 9,319 266 — — 9,585 EQUITY: Chesapeake stockholders’ equity (deficit) (240 ) 907 78 (985 ) (240 ) Noncontrolling interests — — 123 — 123 Total Equity (Deficit) (240 ) 907 201 (985 ) (117 ) TOTAL LIABILITIES AND EQUITY $ 9,672 $ 11,794 $ 203 $ (9,328 ) $ 12,341 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 THREE MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 978 $ 4 $ — $ 982 Marketing — 1,273 — — 1,273 Total Revenues — 2,251 4 — 2,255 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 — — 138 Oil, natural gas and NGL gathering, processing and transportation — 338 2 — 340 Production taxes — 26 — — 26 Marketing — 1,292 — — 1,292 General and administrative — 90 1 — 91 Provision for legal contingencies, net — 4 — — 4 Oil, natural gas and NGL depreciation, depletion and amortization — 270 1 — 271 Depreciation and amortization of other assets — 19 — — 19 Impairments — 46 — — 46 Other operating income — (1 ) — — (1 ) Net gains on sales of fixed assets — (1 ) — — (1 ) Total Operating Expenses — 2,221 4 — 2,225 INCOME FROM OPERATIONS — 30 — — 30 OTHER INCOME (EXPENSE): Interest expense (117 ) — — — (117 ) Other income — 62 — — 62 Equity in net earnings (losses) of subsidiary 91 (1 ) — (90 ) — Total Other Income (Expense) (26 ) 61 — (90 ) (55 ) INCOME (LOSS) BEFORE INCOME TAXES (26 ) 91 — (90 ) (25 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME (LOSS) (17 ) 91 — (90 ) (16 ) Net income attributable to noncontrolling interests — — (1 ) — (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE (17 ) 91 (1 ) (90 ) (17 ) Other comprehensive income — 7 — — 7 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ (17 ) $ 98 $ (1 ) $ (90 ) $ (10 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 1,273 $ 6 $ — $ 1,279 Marketing — 1,002 — — 1,002 Total Revenues — 2,275 6 — 2,281 OPERATING EXPENSES: Oil, natural gas and NGL production — 140 — — 140 Oil, natural gas and NGL gathering, processing and transportation — 355 2 — 357 Production taxes — 21 — — 21 Marketing — 1,027 — — 1,027 General and administrative 3 67 — — 70 Provision for legal contingencies, net — 17 — — 17 Oil, natural gas and NGL depreciation, depletion and amortization — 202 — — 202 Depreciation and amortization of other assets — 21 — — 21 Net losses on sales of fixed assets — 1 — — 1 Other operating expense — 26 — — 26 Total Operating Expenses 3 1,877 2 — 1,882 INCOME (LOSS) FROM OPERATIONS (3 ) 398 4 — 399 OTHER INCOME (EXPENSE): Interest income (expense) (95 ) 2 — — (93 ) Gains on purchases or exchanges of debt 191 — — — 191 Other expense — (1 ) — — (1 ) Equity in net earnings of subsidiary 402 3 — (405 ) — Total Other Income 498 4 — (405 ) 97 INCOME BEFORE INCOME TAXES 495 402 4 (405 ) 496 INCOME TAX EXPENSE 1 — — — 1 NET INCOME 494 402 4 (405 ) 495 Net income attributable to noncontrolling interests — — (1 ) — (1 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 494 402 3 (405 ) 494 Other comprehensive income — 7 — — 7 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 494 $ 409 $ 3 $ (405 ) $ 501 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,216 $ 9 $ — $ 2,225 Marketing — 2,519 — — 2,519 Total Revenues — 4,735 9 — 4,744 OPERATING EXPENSES: Oil, natural gas and NGL production — 285 — — 285 Oil, natural gas and NGL gathering, processing and transportation — 693 3 — 696 Production taxes — 57 — — 57 Marketing — 2,560 — — 2,560 General and administrative — 162 1 — 163 Restructuring and other termination costs — 38 — — 38 Provision for legal contingencies, net — 9 — — 9 Oil, natural gas and NGL depreciation, depletion and amortization — 537 2 — 539 Depreciation and amortization of other assets — 37 — — 37 Impairments — 46 — — 46 Other operating income — (1 ) — — (1 ) Net losses on sales of fixed assets — 7 — — 7 Total Operating Expenses — 4,430 6 — 4,436 INCOME FROM OPERATIONS — 305 3 — 308 OTHER INCOME (EXPENSE): Interest expense (240 ) — — — (240 ) Gains on investments — 139 — — 139 Other income — 62 — — 62 Equity in net earnings (losses) of subsidiary 507 1 — (508 ) — Total Other Income (Expense) 267 202 — (508 ) (39 ) INCOME BEFORE INCOME TAXES 267 507 3 (508 ) 269 INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME 276 507 3 (508 ) 278 Net income attributable to noncontrolling interests — — (2 ) — (2 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 276 507 1 (508 ) 276 Other comprehensive income — 17 — — 17 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 276 $ 524 $ 1 $ (508 ) $ 293 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,736 $ 12 $ — $ 2,748 Marketing — 2,286 — — 2,286 Total Revenues — 5,022 12 — 5,034 OPERATING EXPENSES: Oil, natural gas and NGL production — 275 — — 275 Oil, natural gas and NGL gathering, processing and transportation — 708 4 — 712 Production taxes — 43 — — 43 Marketing — 2,355 — — 2,355 General and administrative 3 131 1 — 135 Provision for legal contingencies, net — 15 — — 15 Oil, natural gas and NGL depreciation, depletion and amortization — 397 2 — 399 Depreciation and amortization of other assets — 42 — — 42 Other operating expense — 417 — — 417 Net losses on sales of fixed assets — 1 — — 1 Total Operating Expenses 3 4,384 7 — 4,394 INCOME (LOSS) FROM OPERATIONS (3 ) 638 5 — 640 OTHER INCOME (EXPENSE): Interest expense (190 ) 2 — — (188 ) Gains on purchases or exchanges of debt 184 — — — 184 Other income — 2 — — 2 Equity in net earnings of subsidiary 645 3 — (648 ) — Total Other Income (Expense) 639 7 — (648 ) (2 ) INCOME BEFORE INCOME TAXES 636 645 5 (648 ) 638 INCOME TAX EXPENSE 2 — — — 2 NET INCOME 634 645 5 (648 ) 636 Net income attributable to noncontrolling interests — — (2 ) — (2 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 634 645 3 (648 ) 634 Other comprehensive income — 21 — — 21 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 634 $ 666 $ 3 $ (648 ) $ 655 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 88 $ 1,006 $ 5 $ (8 ) $ 1,091 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (979 ) — — (979 ) Acquisitions of proved and unproved properties — (191 ) — — (191 ) Proceeds from divestitures of proved and unproved properties — 384 — — 384 Additions to other property and equipment — (5 ) — — (5 ) Other investing activities — 148 — — 148 Net Cash Used In Investing Activities — (643 ) — — (643 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — — — 6,118 Payments on revolving credit facility borrowings (6,393 ) — — — (6,393 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (2 ) (126 ) (7 ) 6 (129 ) Intercompany advances, net 235 (237 ) 2 — — Net Cash Used In Financing Activities (88 ) (363 ) (5 ) 6 (450 ) Net decrease in cash and cash equivalents — — — (2 ) (2 ) Cash and cash equivalents, beginning of period 5 1 2 (3 ) 5 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (5 ) $ 3 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By (Used In) Operating Activities $ 2 $ (64 ) $ 8 $ (4 ) $ (58 ) CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (1,031 ) — — (1,031 ) Acquisitions of proved and unproved properties — (162 ) — — (162 ) Proceeds from divestitures of proved and unproved properties — 951 — — 951 Additions to other property and equipment — (7 ) — — (7 ) Other investing activities — 26 — — 26 Net Cash Used In Investing Activities — (223 ) — — (223 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 2,551 — — — 2,551 Payments on revolving credit facility borrowings (1,976 ) — — — (1,976 ) Proceeds from issuance of senior notes, net 742 — — — 742 Cash paid to purchase debt (1,746 ) — — — (1,746 ) Cash paid for preferred stock dividends (137 ) — — — (137 ) Other financing activities (38 ) (2 ) (7 ) 25 (22 ) Intercompany advances, net (287 ) 288 (1 ) — — Net Cash Provided by (Used In) Financing Activities (891 ) 286 (8 ) 25 (588 ) Net increase (decrease) in cash and cash equivalents (889 ) (1 ) — 21 (869 ) Cash and cash equivalents, beginning of period 904 2 1 (25 ) 882 Cash and cash equivalents, end of period $ 15 $ 1 $ 1 $ (4 ) $ 13

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On July 26, 2018 we entered into a purchase and sale agreement (the “Purchase Agreement”) with EAP Ohio, LLC, a private oil and gas company headquartered in Houston, Texas (“Encino”), pursuant to which Encino agreed to purchase all of our approximately 1,500,000 gross ( 900,000 net) acres in Ohio, of which approximately 320,000 net acres are prospective for the Utica Shale with approximately 920 producing wells, along with related property and equipment (collectively, the “Designated Properties”) for a purchase price of approximately $2.0 billion , with additional contingent payments to us of up to $100 million comprised of $50 million in consideration in each case if, on or prior to December 31, 2019, there is a period of twenty ( 20 ) trading days out of a period of thirty ( 30 ) consecutive trading days where (i) the average of the NYMEX natural gas strip pries for the months comprising the year 2022 equals or exceeds $3.00 /mmbtu as calculated pursuant to the agreement, and (ii) the average of the NYMEX natural gas price strip prices for the months comprising the year 2023 equals or exceeds $3.25 /mmbtu as calculated pursuant to the agreement . Average net daily production from the Designated Properties was approximately 107,000 boe during 2017 consisting of 427,000 mcf of natural gas, 26,000 barrels of natural gas liquids and 10,000 barrels of condensate. As of December 31, 2017, net proved reserves associated with the Designated Properties were 480 million boe ( 72% natural gas, 23% natural gas liquids and 5% oil). Closing of the transaction is subject to customary conditions, including waiver of certain pre-existing preferential purchase rights, expiration or termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, other regulatory approvals and certain other closing conditions. Closing is expected to occur in the fourth quarter of 2018, contingent upon satisfaction of such closing conditions and the absence of termination rights. We expect to apply the net proceeds toward the reduction of debt. Pursuant to the Purchase Agreement, the purchase price is subject to customary adjustment provisions, including for results of operations, adjustments for title and environmental defects and preferential purchase rights. The Purchase Agreement also contains customary representations, warranties, covenants and indemnities.

Basis of Presentation (Policy)

Basis of Presentation (Policy)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying condensed consolidated financial statements of Chesapeake were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures have been condensed or omitted.
Recently Issued Accounting Standards	Recently Issued Accounting Standards The Financial Accounting Standards Board (FASB) issued Revenue from Contracts with Customers (Topic 606) superseding virtually all existing revenue recognition guidance. We adopted this new standard in the first quarter of 2018 using the modified retrospective approach. We applied the new standard to all contracts that were not completed as of January 1, 2018 and reflected the aggregate effect of all modifications in determining and allocating the transaction price. See Note 10 for further details regarding our adoption of Topic 606. In February 2018, the FASB issued Accounting Standards Update (ASU) 2018-02, Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income . The new standard allows for stranded tax effects resulting from tax reform legislation known as the Tax Cuts and Jobs Act of 2017 (the “Tax Act”) previously recognized in accumulated other comprehensive income to be reclassified to retained earnings. For public business entities, the amendments are effective for annual periods, including interim periods within the annual periods, beginning after December 15, 2018. Early adoption is permitted in any interim or annual period, 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. 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. 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 for leases with terms in excess of 12 months. In January 2018, the FASB issued an update permitting an entity to elect an optional transition practical expedient to not evaluate land easements that existed or expired before the adoption of Topic 842 and were not previously accounted for as leases. Currently the guidance would be applied using a modified retrospective transition method, which requires applying the new guidance to leases that exist or are entered into after the beginning of the earliest period in the financial statements. However, the FASB recently issued Proposed ASU No. 2018-200, Leases (Topic 842), Targeted Improvements which would allow entities to apply the transition provisions of the new standard at its adoption date instead of at the earliest comparative period presented in the consolidated financial statements. The proposed ASU will allow entities to continue to apply the legacy guidance in Topic 840, including its disclosure requirements, in the comparative periods presented in the year the new leases standard is adopted. Entities that elect this option would still adopt the new leases standard using a modified retrospective transition method, but would recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption rather than in the earliest period presented. Early adoption is permitted, but we do not plan to early adopt . The standard will not apply to our leases of mineral rights. Using the revised framework, we have completed our assessment of lease categories that we believe will be affected by the new standard. We are continuing to assess the accounting treatment for these leases and the resulting impacts to our consolidated financial statements and related disclosures.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share, Basic and Diluted, Other Disclosures [Abstract]
Reconciliation of basic EPS and diluted EPS	A reconciliation of basic EPS and diluted EPS is as follows: Three Months Ended Six Months Ended 2018 2017 2018 2017 (in millions, except per share data) Net income (loss) available to common stockholders $ (40 ) $ 470 $ 228 $ 547 Effect of dilutive securities — 59 — 72 Diluted income (loss) available to common stockholders $ (40 ) $ 529 $ 228 $ 619 Weighted average common and common equivalent shares outstanding - basic 909 908 908 907 Effect of dilutive securities — 206 — 146 Weighted average common and common equivalent shares outstanding - diluted 909 1,114 908 1,053 Net income per share attributable to Chesapeake: Basic $ (0.04 ) $ 0.52 $ 0.25 $ 0.60 Diluted $ (0.04 ) $ 0.47 $ 0.25 $ 0.59 Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive: Common stock equivalent of our preferred stock outstanding 60 — 60 60 Common stock equivalent of our convertible senior notes outstanding 146 — 146 — Common stock equivalent of our preferred stock outstanding prior to exchange — — — 1 Participating securities 1 1 1 1
Reconciliation of basic EPS and diluted EPS	A reconciliation of basic EPS and diluted EPS is as follows: Three Months Ended Six Months Ended 2018 2017 2018 2017 (in millions, except per share data) Net income (loss) available to common stockholders $ (40 ) $ 470 $ 228 $ 547 Effect of dilutive securities — 59 — 72 Diluted income (loss) available to common stockholders $ (40 ) $ 529 $ 228 $ 619 Weighted average common and common equivalent shares outstanding - basic 909 908 908 907 Effect of dilutive securities — 206 — 146 Weighted average common and common equivalent shares outstanding - diluted 909 1,114 908 1,053 Net income per share attributable to Chesapeake: Basic $ (0.04 ) $ 0.52 $ 0.25 $ 0.60 Diluted $ (0.04 ) $ 0.47 $ 0.25 $ 0.59 Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive: Common stock equivalent of our preferred stock outstanding 60 — 60 60 Common stock equivalent of our convertible senior notes outstanding 146 — 146 — Common stock equivalent of our preferred stock outstanding prior to exchange — — — 1 Participating securities 1 1 1 1

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Schedule of long-term debt	Our long-term debt consisted of the following as of June 30, 2018 and December 31, 2017: June 30, 2018 December 31, 2017 Principal Amount Carrying Principal Carrying ($ in millions) 7.25% senior notes due 2018 $ 44 $ 44 $ 44 $ 44 Floating rate senior notes due 2019 380 380 380 380 6.625% senior notes due 2020 437 437 437 437 6.875% senior notes due 2020 227 227 227 227 6.125% senior notes due 2021 548 548 548 548 5.375% senior notes due 2021 267 267 267 267 4.875% senior notes due 2022 451 451 451 451 8.00% senior secured second lien notes due 2022 1,416 1,847 1,416 1,895 5.75% senior notes due 2023 338 338 338 338 8.00% senior notes due 2025 1,300 1,290 1,300 1,290 5.5% convertible senior notes due 2026 (a)(b) 1,250 852 1,250 837 8.00% senior notes due 2027 1,300 1,298 1,300 1,298 2.25% contingent convertible senior notes due 2038 (a) 9 8 9 8 Term loan due 2021 1,233 1,233 1,233 1,233 Revolving credit facility 506 506 781 781 Debt issuance costs — (57 ) — (63 ) Interest rate derivatives — 1 — 2 Total debt, net 9,706 9,670 9,981 9,973 Less current maturities of long-term debt, net (c) (433 ) (432 ) (53 ) (52 ) Total long-term debt, net $ 9,273 $ 9,238 $ 9,928 $ 9,921 ___________________________________________ (a) 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. (b) Prior to maturity under certain circumstances and at the holder’s option, the notes are convertible. During the Current Quarter, the price of our common stock was below the threshold level for conversion and, as a result, the holders do not have the option to convert their notes in the third quarter of 2018. (c) As of June 30, 2018 , current maturities of long-term debt, net includes our 7.25% Senior Notes due December 2018, our Floating Rate Senior Notes due April 2019, and due to the holders’ put option, our 2.25% Contingent Convertible Notes due December 2038.
Schedule of fair value of debt	Fair value is compared to the carrying value, excluding the impact of interest rate derivatives, in the table below: June 30, 2018 December 31, 2017 Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value ($ in millions) Short-term debt (Level 1) $ 432 $ 432 $ 52 $ 53 Long-term debt (Level 1) $ 2,256 $ 2,261 $ 2,633 $ 2,629 Long-term debt (Level 2) $ 6,982 $ 7,215 $ 7,286 $ 7,301

Contingencies and Commitments (

Contingencies and Commitments (Tables)	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule of contractual obligation	The aggregate undiscounted commitments under our gathering, processing and transportation agreements, excluding any reimbursement from working interest and royalty interest owners, credits for third-party volumes or future costs under cost-of-service agreements, are presented below: June 30, ($ in millions) 2018 $ 537 2019 1,047 2020 992 2021 900 2022 792 2023 – 2035 4,434 Total $ 8,702

Other Liabilities (Tables)

Other Liabilities (Tables)	6 Months Ended
	Jun. 30, 2018
Other Liabilities Disclosure [Abstract]
Other current liabilities	Other current liabilities as of June 30, 2018 and December 31, 2017 are detailed below: June 30, December 31, ($ in millions) Revenues and royalties due others $ 488 $ 612 Accrued drilling and production costs 261 216 Joint interest prepayments received 81 74 Accrued compensation and benefits 156 214 Other accrued taxes 104 43 Other 187 296 Total other current liabilities $ 1,277 $ 1,455
Other long-term liabilities	Other long-term liabilities as of June 30, 2018 and December 31, 2017 are detailed below: June 30, December 31, ($ in millions) CHK Utica ORRI conveyance obligation (a) $ — $ 156 Unrecognized tax benefits 81 101 Other 96 97 Total other long-term liabilities $ 177 $ 354 ____________________________________________ (a) In the Current Quarter, we repurchased previously conveyed overriding royalty interests (ORRI) from the CHK Utica, L.L.C. investors and extinguished our obligation to convey future ORRIs to the CHK Utica, L.L.C. investors for combined consideration of $199 million . The total CHK Utica ORRI conveyance obligation extinguished in the Current Quarter was $183 million , of which, $30 million was recorded in current liabilities and $153 million was recorded in long-term liabilities. The fair value of the consideration allocated to the extinguishment of liability, $122 million , was less than the carrying amount of the conveyance obligation and resulted in a gain of $61 million recognized in other income on our condensed consolidated statement of operations. The fair value of the consideration allocated to the purchase of ORRIs on proved producing properties was $77 million and recorded in proved oil and natural gas properties in our condensed consolidated balance sheet.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of the changes in unvested restricted stock	A summary of the changes in unvested restricted stock during the Current Period is presented below: Shares of Unvested Restricted Stock Weighted Average Grant Date Fair Value (in thousands) Unvested restricted stock as of January 1, 2018 13,178 $ 6.37 Granted 4,765 $ 3.57 Vested (5,207 ) $ 7.73 Forfeited (1,295 ) $ 6.13 Unvested restricted stock as of June 30, 2018 11,441 $ 4.61
Weighted average assumptions to estimate grant date fair value of the stock options granted	We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the 2017 and 2016 PSU awards. Grant Date Assumptions Assumption 2017 Awards 2016 Awards Volatility 80.65 % 49.74 % Risk-free interest rate 1.54 % 1.13 % Dividend yield for value of awards — % — % Reporting Period Assumptions Assumption 2017 Awards 2016 Awards Volatility 51.31 % 59.84 % Risk-free interest rate 2.43 % 2.11 % Dividend yield for value of awards — % — % We used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period: Expected option life – years 6.0 Volatility 63.55 % Risk-free interest rate 2.72 % Dividend yield — %
Schedule of stock option activity	The following table provides information related to stock option activity in the Current Period: Number of Shares Underlying Options Weighted Average Exercise Price Per Share Weighted Average Contract Life in Years Aggregate Intrinsic Value (a) (in thousands) ($ in millions) Outstanding as of January 1, 2018 16,285 $ 8.25 7.73 $ 1 Granted 3,611 $ 3.01 Exercised — $ — $ — Expired (602 ) $ 13.83 Forfeited (995 ) $ 5.45 Outstanding as of June 30, 2018 18,299 $ 7.18 7.71 $ 14 Exercisable as of June 30, 2018 8,250 $ 10.73 6.34 $ 3 ___________________________________________ (a) The intrinsic value of a stock option is the amount by which the current market value or the market value upon exercise of the underlying stock exceeds the exercise price of the option.
Restricted stock and stock option compensation	We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended Six Months Ended 2018 2017 2018 2017 ($ in millions) General and administrative expenses $ 8 $ 12 $ 15 $ 20 Oil and natural gas properties 2 3 4 7 Oil, natural gas and NGL production expenses 1 4 3 7 Total restricted stock and stock option compensation $ 11 $ 19 $ 22 $ 34
Assumptions and TSR performance measure to determine grant date fair value of PSUs	We utilized a Monte Carlo simulation for the TSR performance measure and the following assumptions to determine the grant date fair value of the 2017 and 2016 PSU awards. Grant Date Assumptions Assumption 2017 Awards 2016 Awards Volatility 80.65 % 49.74 % Risk-free interest rate 1.54 % 1.13 % Dividend yield for value of awards — % — % Reporting Period Assumptions Assumption 2017 Awards 2016 Awards Volatility 51.31 % 59.84 % Risk-free interest rate 2.43 % 2.11 % Dividend yield for value of awards — % — % We used the following weighted average assumptions to estimate the grant date fair value of the stock options granted in the Current Period: Expected option life – years 6.0 Volatility 63.55 % Risk-free interest rate 2.72 % Dividend yield — %
Schedule of PSU awards	The following table presents a summary of our liability-classified awards: Grant Date Fair Value June 30, 2018 Units Fair Value Vested Liability ($ in millions) ($ in millions) 2018 PSU Awards: Payable 2019, 2020 and 2021 3,992,358 $ 12 $ 21 $ — 2017 PSU Awards: Payable 2020 1,217,774 $ 8 $ 8 $ 5 2016 PSU Awards: Payable 2019 2,348,893 $ 10 $ 16 $ 14 2018 CRSU Awards: Payable 2019, 2020 and 2021 16,367,724 $ 49 $ 86 $ —
PSU compensation	We recognized the following compensation costs related to restricted stock and stock options for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period: Three Months Ended Six Months Ended 2018 2017 2018 2017 ($ in millions) General and administrative expenses $ 8 $ 12 $ 15 $ 20 Oil and natural gas properties 2 3 4 7 Oil, natural gas and NGL production expenses 1 4 3 7 Total restricted stock and stock option compensation $ 11 $ 19 $ 22 $ 34

Derivative and Hedging Activi32

Derivative and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of estimated fair values of oil, natural gas and NGL derivative instruments	The estimated fair values of our oil, natural gas and NGL derivative instrument assets (liabilities) as of June 30, 2018 and December 31, 2017 are provided below: June 30, 2018 December 31, 2017 Notional Volume Fair Value Notional Volume Fair Value ($ in millions) ($ in millions) Oil (mmbbl): Fixed-price swaps 26 $ (271 ) 21 $ (151 ) Three-way collars 1 (14 ) 2 (10 ) Call swaptions 2 (32 ) 2 (13 ) Basis protection swaps 11 6 11 (9 ) Total oil 40 (311 ) 36 (183 ) Natural gas (bcf): Fixed-price swaps 240 3 532 149 Three-way collars 87 — — — Collars 24 2 47 11 Call options 77 — 110 (3 ) Basis protection swaps 45 (1 ) 65 (7 ) Total natural gas 473 4 754 150 NGL (mmgal): Fixed-price swaps 114 (11 ) 33 (2 ) Total estimated fair value $ (318 ) $ (35 )
Schedule of effect of derivative instruments, condensed consolidated balance sheets	The following table presents the fair value and location of each classification of derivative instrument included in the condensed consolidated balance sheets as of June 30, 2018 and December 31, 2017 on a gross basis and after same-counterparty netting: Balance Sheet Classification Gross Fair Value Amounts Netted in the Consolidated Balance Sheets Net Fair Value Presented in the Consolidated Balance Sheet ($ in millions) As of June 30, 2018 Commodity Contracts: Short-term derivative asset $ 20 $ (20 ) $ — Long-term derivative asset 7 (7 ) — Short-term derivative liability (317 ) 20 (297 ) Long-term derivative liability (28 ) 7 (21 ) Total derivatives $ (318 ) $ — $ (318 ) 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 derivatives $ (35 ) $ — $ (35 )
Schedule of effect of derivative instruments, condensed consolidated statements of operations	The components of oil, natural gas and NGL revenues for the Current Quarter, the Prior Quarter, the Current Period and the Prior Period are presented below: Three Months Ended Six Months Ended 2018 2017 2018 2017 ($ in millions) Oil, natural gas and NGL revenues $ 1,233 $ 1,079 $ 2,593 $ 2,226 Gains (losses) on undesignated oil, natural gas and NGL derivatives (244 ) 207 (351 ) 539 Losses on terminated cash flow hedges (7 ) (7 ) (17 ) (17 ) Total oil, natural gas and NGL revenues $ 982 $ 1,279 $ 2,225 $ 2,748
Schedule of 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: Three Months Ended June 30, 2018 2017 Before After Before After ($ in millions) Balance, beginning of period $ (104 ) $ (47 ) $ (139 ) (82 ) Losses reclassified to income 7 7 7 7 Balance, end of period $ (97 ) $ (40 ) (132 ) (75 ) Six Months Ended June 30, 2018 2017 Before After Before After ($ in millions) Balance, beginning of period $ (114 ) $ (57 ) $ (153 ) $ (96 ) Net change in fair value — — 4 4 Losses reclassified to income 17 17 17 17 Balance, end of period $ (97 ) $ (40 ) $ (132 ) $ (75 )
Schedule of financial assets (liabilities)	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 20 $ 7 $ 27 Commodity liabilities — (293 ) (52 ) (345 ) Total derivatives $ — $ (273 ) $ (45 ) $ (318 ) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives ($ in millions) Balance, as of January 1, 2018 $ (15 ) Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) Total purchases, issuances, sales and settlements: Settlements 2 Balance, as of June 30, 2018 $ (45 ) Balance, as of January 1, 2017 $ (10 ) Total gains (losses) (realized/unrealized): Included in earnings (a) 19 Total purchases, issuances, sales and settlements: Settlements 1 Balance, as of June 30, 2017 $ 10 ___________________________________________ (a) Commodity Derivatives 2018 2017 ($ in millions) Total gains (losses) included in earnings for the period $ (32 ) $ 19 Change in unrealized gains (losses) related to assets still held at reporting date $ (30 ) $ 12 The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Financial Assets (Liabilities): Other current assets $ 53 $ — $ — $ 53 Other current liabilities (52 ) — — (52 ) Total $ 1 $ — $ — $ 1 As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 )
Schedule of quantitative information about level 3 inputs used	The following table presents quantitative information about Level 3 inputs used in the fair value measurement of our commodity derivative contracts at fair value as of June 30, 2018 : Instrument Type Unobservable Input Range Weighted Average Fair Value ($ in millions) Oil trades Oil price volatility curves 17.16% – 30.26% 25.01% $ (47 ) Natural gas trades Natural gas price volatility curves 14.23% – 46.86% 18.30% $ 2

Oil and Natural Gas Property 33

Oil and Natural Gas Property Transactions (Tables)	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
VPP Transactions	As of June 30, 2018 , 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 Remaining to Be Delivered	The volumes remaining to be delivered on behalf of our VPP buyers as of June 30, 2018 were as follows: Volume Remaining as of June 30, 2018 VPP # Term Remaining Oil Natural Gas NGL Total (in months) (mmbbl) (bcf) (mmbbl) (bcfe) 9 32 0.3 28.5 0.8 34.8

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Adoption of new revenue standard	In accordance with the new revenue standard requirements, the disclosure of the impact of adoption on our condensed consolidated balance sheet and condensed consolidated statement of operations was as follows: Before adoption of ASC 606 Adjustments As Reported ($ in millions) Balance Sheet as of June 30, 2018 Other current liabilities $ 1,275 $ 2 $ 1,277 Other long-term liabilities $ 172 $ 5 $ 177 Accumulated deficit $ (16,249 ) $ (8 ) $ (16,257 ) Statement of Operations for the Three Months Ended June 30, 2018 Marketing revenues $ 1,449 $ (176 ) $ 1,273 Marketing operating expenses $ 1,469 $ (177 ) $ 1,292 Statement of Operations for the Six Months Ended June 30, 2018 Marketing revenues $ 2,810 $ (291 ) $ 2,519 Marketing operating expenses $ 2,852 $ (292 ) $ 2,560
Disaggregation of revenue	The following table shows revenue disaggregated by operating area and product type, for the Current Quarter and the Current Period: Three Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 169 $ — $ 169 Haynesville 1 199 — 200 Eagle Ford 389 42 46 477 Utica 62 103 61 226 Mid-Continent 62 15 12 89 Powder River Basin 52 11 9 72 Revenue from contracts with customers 566 539 128 1,233 Losses on oil, natural gas and NGL derivatives (202 ) (35 ) (14 ) (251 ) Oil, natural gas and NGL revenue $ 364 $ 504 $ 114 $ 982 Marketing revenue from contracts with customers $ 732 $ 235 $ 102 $ 1,069 Other marketing revenue 145 59 — 204 Marketing revenue $ 877 $ 294 $ 102 $ 1,273 Six Months Ended June 30, 2018 Oil Natural Gas NGL Total ($ in millions) Marcellus $ — $ 463 $ — $ 463 Haynesville 2 409 — 411 Eagle Ford 749 84 85 918 Utica 119 219 113 451 Mid-Continent 138 47 30 215 Powder River Basin 95 23 17 135 Revenue from contracts with customers 1,103 1,245 245 2,593 Losses on oil, natural gas and NGL derivatives (288 ) (67 ) (13 ) (368 ) Oil, natural gas and NGL revenue $ 815 $ 1,178 $ 232 $ 2,225 Marketing revenue from contracts with customers $ 1,418 $ 528 $ 212 $ 2,158 Other marketing revenue 262 99 — 361 Marketing revenue $ 1,680 $ 627 $ 212 $ 2,519
Accounts receivable	Accounts receivable as of June 30, 2018 and December 31, 2017 are detailed below: June 30, 2018 December 31, 2017 ($ in millions) Oil, natural gas and NGL sales $ 801 $ 959 Joint interest 206 209 Other 68 184 Allowance for doubtful accounts (15 ) (30 ) Total accounts receivable, net $ 1,060 $ 1,322

Restructuring and Other Termi35

Restructuring and Other Termination Costs (Tables)	6 Months Ended
	Jun. 30, 2018
Restructuring and Related Activities [Abstract]
Summary of restructuring liabilities	The following table summarizes our restructuring liabilities: Other Current Liabilities ($ in millions) Balance as of December 31, 2017 $ — Initial restructuring recognition on January 30, 2018 38 Termination benefits paid (38 ) Balance as of June 30, 2018 $ —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of fair value measurement of financial assets (liabilities) measured at fair value on a recurring basis	The following table provides information for financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Derivative Assets (Liabilities): Commodity assets $ — $ 20 $ 7 $ 27 Commodity liabilities — (293 ) (52 ) (345 ) Total derivatives $ — $ (273 ) $ (45 ) $ (318 ) As of December 31, 2017 Derivative Assets (Liabilities): Commodity assets $ — $ — $ 8 $ 8 Commodity liabilities — (20 ) (23 ) (43 ) Total derivatives $ — $ (20 ) $ (15 ) $ (35 ) A summary of the changes in the fair values of our financial assets (liabilities) classified as Level 3 during the Current Period and the Prior Period is presented below: Commodity Derivatives ($ in millions) Balance, as of January 1, 2018 $ (15 ) Total gains (losses) (realized/unrealized): Included in earnings (a) (32 ) Total purchases, issuances, sales and settlements: Settlements 2 Balance, as of June 30, 2018 $ (45 ) Balance, as of January 1, 2017 $ (10 ) Total gains (losses) (realized/unrealized): Included in earnings (a) 19 Total purchases, issuances, sales and settlements: Settlements 1 Balance, as of June 30, 2017 $ 10 ___________________________________________ (a) Commodity Derivatives 2018 2017 ($ in millions) Total gains (losses) included in earnings for the period $ (32 ) $ 19 Change in unrealized gains (losses) related to assets still held at reporting date $ (30 ) $ 12 The following table provides fair value measurement information for the above-noted financial assets (liabilities) measured at fair value on a recurring basis as of June 30, 2018 and December 31, 2017: Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Fair Value ($ in millions) As of June 30, 2018 Financial Assets (Liabilities): Other current assets $ 53 $ — $ — $ 53 Other current liabilities (52 ) — — (52 ) Total $ 1 $ — $ — $ 1 As of December 31, 2017 Financial Assets (Liabilities): Other current assets $ 57 $ — $ — $ 57 Other current liabilities (60 ) — — (60 ) Total $ (3 ) $ — $ — $ (3 )

Condensed Consolidating Finan37

Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2018
Condensed Financial Information Disclosure [Abstract]
Condensed Consolidated Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEET AS OF JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated CURRENT ASSETS: Cash and cash equivalents $ 5 $ 1 $ 2 $ (5 ) $ 3 Other current assets 63 1,173 1 — 1,237 Intercompany receivable, net 8,132 31 175 (8,338 ) — Total Current Assets 8,200 1,205 178 (8,343 ) 1,240 PROPERTY AND EQUIPMENT: Oil and natural gas properties at cost, based on full cost accounting, net 521 9,129 25 — 9,675 Other property and equipment, net — 1,164 — — 1,164 Property and equipment held for sale, net — 11 — — 11 Total Property and Equipment, Net 521 10,304 25 — 10,850 LONG-TERM ASSETS: Other long-term assets 44 207 — — 251 Investments in subsidiaries and intercompany advances 907 78 — (985 ) — TOTAL ASSETS $ 9,672 $ 11,794 $ 203 $ (9,328 ) $ 12,341 CURRENT LIABILITIES: Current liabilities $ 561 $ 2,315 $ 2 $ (5 ) $ 2,873 Intercompany payable, net 32 8,306 — (8,338 ) — Total Current Liabilities 593 10,621 2 (8,343 ) 2,873 LONG-TERM LIABILITIES: Long-term debt, net 9,238 — — — 9,238 Other long-term liabilities 81 266 — — 347 Total Long-Term Liabilities 9,319 266 — — 9,585 EQUITY: Chesapeake stockholders’ equity (deficit) (240 ) 907 78 (985 ) (240 ) Noncontrolling interests — — 123 — 123 Total Equity (Deficit) (240 ) 907 201 (985 ) (117 ) TOTAL LIABILITIES AND EQUITY $ 9,672 $ 11,794 $ 203 $ (9,328 ) $ 12,341 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 THREE MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 978 $ 4 $ — $ 982 Marketing — 1,273 — — 1,273 Total Revenues — 2,251 4 — 2,255 OPERATING EXPENSES: Oil, natural gas and NGL production — 138 — — 138 Oil, natural gas and NGL gathering, processing and transportation — 338 2 — 340 Production taxes — 26 — — 26 Marketing — 1,292 — — 1,292 General and administrative — 90 1 — 91 Provision for legal contingencies, net — 4 — — 4 Oil, natural gas and NGL depreciation, depletion and amortization — 270 1 — 271 Depreciation and amortization of other assets — 19 — — 19 Impairments — 46 — — 46 Other operating income — (1 ) — — (1 ) Net gains on sales of fixed assets — (1 ) — — (1 ) Total Operating Expenses — 2,221 4 — 2,225 INCOME FROM OPERATIONS — 30 — — 30 OTHER INCOME (EXPENSE): Interest expense (117 ) — — — (117 ) Other income — 62 — — 62 Equity in net earnings (losses) of subsidiary 91 (1 ) — (90 ) — Total Other Income (Expense) (26 ) 61 — (90 ) (55 ) INCOME (LOSS) BEFORE INCOME TAXES (26 ) 91 — (90 ) (25 ) INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME (LOSS) (17 ) 91 — (90 ) (16 ) Net income attributable to noncontrolling interests — — (1 ) — (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE (17 ) 91 (1 ) (90 ) (17 ) Other comprehensive income — 7 — — 7 COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE $ (17 ) $ 98 $ (1 ) $ (90 ) $ (10 ) CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS THREE MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 1,273 $ 6 $ — $ 1,279 Marketing — 1,002 — — 1,002 Total Revenues — 2,275 6 — 2,281 OPERATING EXPENSES: Oil, natural gas and NGL production — 140 — — 140 Oil, natural gas and NGL gathering, processing and transportation — 355 2 — 357 Production taxes — 21 — — 21 Marketing — 1,027 — — 1,027 General and administrative 3 67 — — 70 Provision for legal contingencies, net — 17 — — 17 Oil, natural gas and NGL depreciation, depletion and amortization — 202 — — 202 Depreciation and amortization of other assets — 21 — — 21 Net losses on sales of fixed assets — 1 — — 1 Other operating expense — 26 — — 26 Total Operating Expenses 3 1,877 2 — 1,882 INCOME (LOSS) FROM OPERATIONS (3 ) 398 4 — 399 OTHER INCOME (EXPENSE): Interest income (expense) (95 ) 2 — — (93 ) Gains on purchases or exchanges of debt 191 — — — 191 Other expense — (1 ) — — (1 ) Equity in net earnings of subsidiary 402 3 — (405 ) — Total Other Income 498 4 — (405 ) 97 INCOME BEFORE INCOME TAXES 495 402 4 (405 ) 496 INCOME TAX EXPENSE 1 — — — 1 NET INCOME 494 402 4 (405 ) 495 Net income attributable to noncontrolling interests — — (1 ) — (1 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 494 402 3 (405 ) 494 Other comprehensive income — 7 — — 7 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 494 $ 409 $ 3 $ (405 ) $ 501 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2018 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,216 $ 9 $ — $ 2,225 Marketing — 2,519 — — 2,519 Total Revenues — 4,735 9 — 4,744 OPERATING EXPENSES: Oil, natural gas and NGL production — 285 — — 285 Oil, natural gas and NGL gathering, processing and transportation — 693 3 — 696 Production taxes — 57 — — 57 Marketing — 2,560 — — 2,560 General and administrative — 162 1 — 163 Restructuring and other termination costs — 38 — — 38 Provision for legal contingencies, net — 9 — — 9 Oil, natural gas and NGL depreciation, depletion and amortization — 537 2 — 539 Depreciation and amortization of other assets — 37 — — 37 Impairments — 46 — — 46 Other operating income — (1 ) — — (1 ) Net losses on sales of fixed assets — 7 — — 7 Total Operating Expenses — 4,430 6 — 4,436 INCOME FROM OPERATIONS — 305 3 — 308 OTHER INCOME (EXPENSE): Interest expense (240 ) — — — (240 ) Gains on investments — 139 — — 139 Other income — 62 — — 62 Equity in net earnings (losses) of subsidiary 507 1 — (508 ) — Total Other Income (Expense) 267 202 — (508 ) (39 ) INCOME BEFORE INCOME TAXES 267 507 3 (508 ) 269 INCOME TAX BENEFIT (9 ) — — — (9 ) NET INCOME 276 507 3 (508 ) 278 Net income attributable to noncontrolling interests — — (2 ) — (2 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 276 507 1 (508 ) 276 Other comprehensive income — 17 — — 17 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 276 $ 524 $ 1 $ (508 ) $ 293 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS SIX MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated REVENUES: Oil, natural gas and NGL $ — $ 2,736 $ 12 $ — $ 2,748 Marketing — 2,286 — — 2,286 Total Revenues — 5,022 12 — 5,034 OPERATING EXPENSES: Oil, natural gas and NGL production — 275 — — 275 Oil, natural gas and NGL gathering, processing and transportation — 708 4 — 712 Production taxes — 43 — — 43 Marketing — 2,355 — — 2,355 General and administrative 3 131 1 — 135 Provision for legal contingencies, net — 15 — — 15 Oil, natural gas and NGL depreciation, depletion and amortization — 397 2 — 399 Depreciation and amortization of other assets — 42 — — 42 Other operating expense — 417 — — 417 Net losses on sales of fixed assets — 1 — — 1 Total Operating Expenses 3 4,384 7 — 4,394 INCOME (LOSS) FROM OPERATIONS (3 ) 638 5 — 640 OTHER INCOME (EXPENSE): Interest expense (190 ) 2 — — (188 ) Gains on purchases or exchanges of debt 184 — — — 184 Other income — 2 — — 2 Equity in net earnings of subsidiary 645 3 — (648 ) — Total Other Income (Expense) 639 7 — (648 ) (2 ) INCOME BEFORE INCOME TAXES 636 645 5 (648 ) 638 INCOME TAX EXPENSE 2 — — — 2 NET INCOME 634 645 5 (648 ) 636 Net income attributable to noncontrolling interests — — (2 ) — (2 ) NET INCOME ATTRIBUTABLE TO CHESAPEAKE 634 645 3 (648 ) 634 Other comprehensive income — 21 — — 21 COMPREHENSIVE INCOME ATTRIBUTABLE TO CHESAPEAKE $ 634 $ 666 $ 3 $ (648 ) $ 655
Condensed Consolidated Cash Flow Statements	Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By Operating Activities $ 88 $ 1,006 $ 5 $ (8 ) $ 1,091 CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (979 ) — — (979 ) Acquisitions of proved and unproved properties — (191 ) — — (191 ) Proceeds from divestitures of proved and unproved properties — 384 — — 384 Additions to other property and equipment — (5 ) — — (5 ) Other investing activities — 148 — — 148 Net Cash Used In Investing Activities — (643 ) — — (643 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 6,118 — — — 6,118 Payments on revolving credit facility borrowings (6,393 ) — — — (6,393 ) Cash paid for preferred stock dividends (46 ) — — — (46 ) Other financing activities (2 ) (126 ) (7 ) 6 (129 ) Intercompany advances, net 235 (237 ) 2 — — Net Cash Used In Financing Activities (88 ) (363 ) (5 ) 6 (450 ) Net decrease in cash and cash equivalents — — — (2 ) (2 ) Cash and cash equivalents, beginning of period 5 1 2 (3 ) 5 Cash and cash equivalents, end of period $ 5 $ 1 $ 2 $ (5 ) $ 3 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS SIX MONTHS ENDED JUNE 30, 2017 ($ in millions) Parent Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated CASH FLOWS FROM OPERATING ACTIVITIES: Net Cash Provided By (Used In) Operating Activities $ 2 $ (64 ) $ 8 $ (4 ) $ (58 ) CASH FLOWS FROM INVESTING ACTIVITIES: Drilling and completion costs — (1,031 ) — — (1,031 ) Acquisitions of proved and unproved properties — (162 ) — — (162 ) Proceeds from divestitures of proved and unproved properties — 951 — — 951 Additions to other property and equipment — (7 ) — — (7 ) Other investing activities — 26 — — 26 Net Cash Used In Investing Activities — (223 ) — — (223 ) CASH FLOWS FROM FINANCING ACTIVITIES: Proceeds from revolving credit facility borrowings 2,551 — — — 2,551 Payments on revolving credit facility borrowings (1,976 ) — — — (1,976 ) Proceeds from issuance of senior notes, net 742 — — — 742 Cash paid to purchase debt (1,746 ) — — — (1,746 ) Cash paid for preferred stock dividends (137 ) — — — (137 ) Other financing activities (38 ) (2 ) (7 ) 25 (22 ) Intercompany advances, net (287 ) 288 (1 ) — — Net Cash Provided by (Used In) Financing Activities (891 ) 286 (8 ) 25 (588 ) Net increase (decrease) in cash and cash equivalents (889 ) (1 ) — 21 (869 ) Cash and cash equivalents, beginning of period 904 2 1 (25 ) 882 Cash and cash equivalents, end of period $ 15 $ 1 $ 1 $ (4 ) $ 13

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities Excluded from Computation of EPS Table (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income (loss) available to common stockholders	$ (40)	$ 470	$ 228	$ 547
Effect of dilutive securities	0	59	0	72
Diluted income (loss) available to common stockholders	$ (40)	$ 529	$ 228	$ 619
Dilutive Securities, Effect on Basic Earnings Per Share [Abstract]
Weighted average common and common equivalent shares outstanding, basic (in shares)	909	908	908	907
Effect of dilutive securities (in shares)	0	206	0	146
Weighted average common and common equivalent shares outstanding, diluted (in shares)	909	1,114	908	1,053
Net income per share attributable to Chesapeake:
Earnings per common share, basic (in dollars per share)	$ (0.04)	$ 0.52	$ 0.25	$ 0.60
Earnings per common share, diluted (in dollars per share)	$ (0.04)	$ 0.47	$ 0.25	$ 0.59
Convertible preferred stock [Member]
Net income per share attributable to Chesapeake:
Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive:	0	0	0	1
Convertible debt securities [Member]
Net income per share attributable to Chesapeake:
Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive:	146	0	146	0
Participating securities [Member]
Net income per share attributable to Chesapeake:
Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive:	1	1	1	1
Preferred stock [Member]
Net income per share attributable to Chesapeake:
Shares of common stock for the following securities were excluded from the calculation of diluted EPS as the effect was antidilutive:	60	0	60	60

Debt - Long-Term Debt Table (De

Debt - Long-Term Debt Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	$ 9,706	$ 9,981
Long-term Debt, Gross	9,670	9,973
Debt issuance costs	(57)	(63)
Debt, current	(433)	(53)
Current maturities of long-term debt, net	(432)	(52)
Long-term debt, fair value	9,273	9,928
Long-term debt, net	9,238	9,921
Interest rate contract [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	0	0
Interest rate derivatives	1	2
Senior notes [Member] | 7.25% Senior Notes Due 2018 [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	44	44
Long-term Debt, Gross	$ 44	44
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	437
Long-term Debt, Gross	$ 437	437
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	227
Long-term Debt, Gross	$ 227	227
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	548
Long-term Debt, Gross	$ 548	548
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	267
Long-term Debt, Gross	$ 267	267
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
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	1,416
Long-term Debt, Gross	$ 1,847	1,895
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
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	1,300
Long-term Debt, Gross	$ 1,290	1,290
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	1,300
Long-term Debt, Gross	$ 1,298	1,298
Interest rate, stated 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
Long-term Debt, Gross	$ 852	837
Interest rate, stated percentage	5.50%
Interest rate, effective percentage	11.50%
Convertible debt [Member] | 2.25% Contingent Convertible Senior Notes Due 2038 [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	$ 9	9
Long-term Debt, Gross	$ 8	8
Interest rate, stated percentage	2.25%
Interest rate, effective percentage	8.00%
Term loan [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	$ 1,233	1,233
Long-term Debt, Gross	1,233	1,233
Line of Credit [Member] | Revolving credit facility [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	506	781
Revolving credit facility	$ 506	$ 781

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Long-Term Debt Instrument [Line Items]
Cash paid to purchase debt					$ 0	$ 1,746
Gains (losses) on restructuring of debt	$ 0	$ 191	$ 184	$ 191	0	$ 184
Debt instrument, face amount	9,706		9,981		9,706
Senior Notes, Sr. Secured Notes, Contingent Convertible Notes [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, repurchased face amount			1,604
Cash paid to purchase debt			1,746
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	183				183
Revolving credit facility [Member] | Line of Credit [Member]
Long-Term Debt Instrument [Line Items]
Debt instrument, face amount	$ 506		$ 781		$ 506

Debt - Fair Value of Debt Table

Debt - Fair Value of Debt Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, fair value	$ 9,273	$ 9,928
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	432	52
Long-term debt, fair value	2,256	2,633
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	432	53
Long-term debt, fair value	2,261	2,629
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	6,982	7,286
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	$ 7,215	$ 7,301

Contingencies and Commitments -

Contingencies and Commitments - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Chaparral Energy, Inc. [Member] | Healthcare of Ontario Pension Plan (HOOPP) [Member] | Pending litigation [Member]
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 215

Contingencies and Commitments43

Contingencies and Commitments - Gathering Processing and Transportation Commitments Table (Details) - Gathering, processing and transportation agreement [Member] $ in Millions	Jun. 30, 2018USD ($)
Other Commitments [Line Items]
Gathering, processing and transportation commitment, 2018	$ 537
Gathering, processing and transportation commitment, 2019	1,047
Gathering, processing and transportation commitment, 2020	992
Gathering, processing and transportation commitment, 2021	900
Gathering, processing and transportation commitment, 2022	792
Gathering, processing and transportation commitment, 2023-2035	4,434
Gathering, processing and transportation commitment, total	$ 8,702

Other Liabilities - Current Tab

Other Liabilities - Current Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Other Liabilities Disclosure [Abstract]
Revenues and royalties due others	$ 488	$ 612
Accrued drilling and production costs	261	216
Joint interest prepayments received	81	74
Accrued compensation and benefits	156	214
Other accrued taxes	104	43
Other	187	296
Current liabilities	$ 1,277	$ 1,455

Other Liabilities - Long-Term T

Other Liabilities - Long-Term Table (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Other Long-Term Liabilities [Line Items]
Conveyance obligation	$ 0		$ 0		$ 156
Unrecognized tax benefits	81		81		101
Other	96		96		97
Total other long-term liabilities	177		177		354
Other income (expense)	62	$ (1)	62	$ 2
Capitalized costs, proved properties	69,976		69,976		$ 68,858
ORRI [Member]
Other Long-Term Liabilities [Line Items]
Conveyance obligation	183		183
Consideration	199
Conveyance obligation, noncurrent	30		30
Conveyance obligation, current	153		153
Other income (expense)	61
Oil and Gas Properties [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Capitalized costs, proved properties	77		$ 77
Liability [Member] | ORRI [Member]
Other Long-Term Liabilities [Line Items]
Extinguishment of liabilities	$ 122

Income Taxes Income Taxes - Nar

Income Taxes Income Taxes - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income Tax Contingency [Line Items]
Tax credit carryforward	$ 3		$ 3
Unrecognized tax benefit, decrease from state income tax expense	1
Unrecognized tax benefits, interest expense	4
Income tax expense (benefit)	(9)	$ 1	$ (9)	$ 2
State and Local Jurisdiction [Member]
Income Tax Contingency [Line Items]
Unrecognized tax benefits, decrease resulting from settlements with taxing authorities	$ 13

Share-Based Compensation - Rest

Share-Based Compensation - Restricted Stock Table (Details) - Restricted stock [Member] shares in Thousands	6 Months Ended
	Jun. 30, 2018$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested restricted stock, beginning balance | shares	13,178
Granted (in shares) | shares	4,765
Vested (in shares) | shares	(5,207)
Forfeited (in shares) | shares	(1,295)
Unvested restricted stock, beginning balance | shares	11,441
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted average grant date fair value, unvested restricted stock, beginning balance (in dollars per share) | $ / shares	$ 6.37
Weighted average grant date fair value, granted (in dollars per share) | $ / shares	3.57
Weighted average grant date fair value, vested (in dollars per share) | $ / shares	7.73
Weighted average grant date fair value, forfeited (in dollars per share) | $ / shares	6.13
Weighted average grant date fair value, unvested restricted stock, ending balance (in dollars per share) | $ / shares	$ 4.61

Share-Based Compensation - Equi

Share-Based Compensation - Equity-Classified Valuation Table (Details) - Stock option [Member]	6 Months Ended
	Jun. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected option life – years	6 years
Volatility	63.55%
Risk-free interest rate	2.72%
Dividend yield	0.00%

Share-Based Compensation - Stoc

Share-Based Compensation - Stock Option Activity Table (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning balance	16,285
Granted (in shares options)	3,611
Exercised (in shares options)	0
Expired (in shares options)	(602)
Forfeited (in shares options)	(995)
Outstanding, ending balance	18,299	16,285
Exercisable (in shares options)	8,250
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Weighted average exercise price, beginning (in dollars per share)	$ 8.25
Weighted average exercise price, granted (in dollars per share)	3.01
Weighted average exercise price, exercised (in dollars per share)	0
Weighted average exercise price, expired (in dollars per share)	13.83
Weighted average exercise price, forfeited (in dollars per share)	5.45
Weighted average exercise price, ending (in dollars per share)	7.18	$ 8.25
Weighted average exercise price, exercisable (in dollars per share)	$ 10.73
Weighted average contract life, outstanding (in years)	7 years 8 months 15 days	7 years 8 months 23 days
Weighted average contract life, exercisable (in years)	6 years 4 months 2 days
Aggregate intrinsic value, outstanding, beginning balance	$ 1
Aggregate intrinsic value, exercised	0
Aggregate intrinsic value, outstanding, ending balance	14	$ 1
Aggregate intrinsic value, exercisable	$ 3

Share-Based Compensation - Eq50

Share-Based Compensation - Equity-Classified Compensation Table (Details) - Restricted stock and stock options [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 11	$ 19	$ 22	$ 34
General and administrative expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	8	12	15	20
Oil and natural gas properties [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	2	3	4	7
Oil, natural gas and NGL production expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 1	$ 4	$ 3	$ 7

Share-Based Compensation - Liab

Share-Based Compensation - Liability Classified Valuation Table (Details) - Performance Share Units [Member]	6 Months Ended
	Jun. 30, 2018
Grant Date Assumptions [Member] | 2017 Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	80.65%
Risk-free interest rate	1.54%
Dividend yield	0.00%
Grant Date Assumptions [Member] | 2016 Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	49.74%
Risk-free interest rate	1.13%
Dividend yield	0.00%
Reporting Period Assumptions [Member] | 2017 Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	51.31%
Risk-free interest rate	2.43%
Dividend yield	0.00%
Reporting Period Assumptions [Member] | 2016 Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Volatility	59.84%
Risk-free interest rate	2.11%
Dividend yield	0.00%

Share-Based Compensation - Perf

Share-Based Compensation - Performance Share Unit Breakout (Details) - USD ($) $ in Millions	Jun. 30, 2018	Jan. 01, 2018
Performance Share Units [Member] | Award Year 2018, Payable 2019, 2020 and 2021 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	3,992,358
Fair Value	$ 21	$ 12
Vested Liability	$ 0
Performance Share Units [Member] | Award Year 2017, Payable 2020 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	1,217,774
Fair Value	$ 8	8
Vested Liability	$ 5
Performance Share Units [Member] | Award Year 2016, Payable 2019 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	2,348,893
Fair Value	$ 16	10
Vested Liability	$ 14
Cash Restricted Stock Units [Member] | Award Year 2018, Payable 2019, 2020 and 2021 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units	16,367,724
Fair Value	$ 86	$ 49
Vested Liability	$ 0

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value of restricted stock, vested	$ 17
Unrecognized compensation expense	$ 40
Share-based compensation expense, weighted average period for recognition	2 years 2 months 12 days
Stock option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense, weighted average period for recognition	1 year 11 months 8 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	$ 20
Stock option [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, percentage	33.30%
Share-based compensation, award vesting period	3 years
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
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 Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Method Used	Monte Carlo simulation
Performance Share Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Share Units Maximum Payout Percentage	0.00%
Performance Share Units [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Share Units Maximum Payout Percentage	200.00%
Performance Share Units [Member] | Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, award vesting period	3 years
Performance Share Units Maximum Payout Percentage	200.00%
Performance Share Grant Maximum Payout Percentage	100.00%
Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award	less than zero
Performance Share Units [Member] | Management [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	0.00%
Operational Component Percentage Performance Share Units	0.00%
Performance Share Units [Member] | Management [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
TSR Component Percentage Performance Share Units	100.00%
Operational Component Percentage Performance Share Units	100.00%

Derivative and Hedging Activi54

Derivative and Hedging Activities - Derivative Instruments Table (Details) gal in Millions, MMBbls in Millions, $ in Millions, MMBTU in Trillions	6 Months Ended	12 Months Ended
	Jun. 30, 2018USD ($)MMBTUgalMMBbls	Dec. 31, 2017USD ($)MMBTUgalMMBbls
Derivative [Line Items]
Derivative assets (liabilities), at fair value, net	$ (318)	$ (35)
Energy related derivative [Member]
Derivative [Line Items]
Derivative assets (liabilities), at fair value, net	$ (318)	$ (35)
Energy related derivative [Member] | Oil [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	40	36
Derivative assets (liabilities), at fair value, net	$ (311)	$ (183)
Energy related derivative [Member] | Oil [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	26	21
Derivative assets (liabilities), at fair value, net	$ (271)	$ (151)
Energy related derivative [Member] | Oil [Member] | Three Way Collar [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	1	2
Derivative assets (liabilities), at fair value, net	$ (14)	$ (10)
Energy related derivative [Member] | Oil [Member] | Call Swaption [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	2	2
Derivative assets (liabilities), at fair value, net	$ (32)	$ (13)
Energy related derivative [Member] | Oil [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | MMBbls	11	11
Derivative assets (liabilities), at fair value, net	$ 6	$ (9)
Energy related derivative [Member] | Natural gas [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	473	754
Derivative assets (liabilities), at fair value, net	$ 4	$ 150
Energy related derivative [Member] | Natural gas [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	240	532
Derivative assets (liabilities), at fair value, net	$ 3	$ 149
Energy related derivative [Member] | Natural gas [Member] | Three Way Collar [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	87	0
Derivative assets (liabilities), at fair value, net	$ 0	$ 0
Energy related derivative [Member] | Natural gas [Member] | Collar [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	24	47
Derivative assets (liabilities), at fair value, net	$ 2	$ 11
Energy related derivative [Member] | Natural gas [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	77	110
Derivative assets (liabilities), at fair value, net	$ 0	$ (3)
Energy related derivative [Member] | Natural gas [Member] | Basis Protection Swap [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, energy measure | MMBTU	45	65
Derivative assets (liabilities), at fair value, net	$ (1)	$ (7)
Energy related derivative [Member] | NGL [Member] | Fixed-Price Swap [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount, volume | gal	114	33
Derivative assets (liabilities), at fair value, net	$ (11)	$ (2)

Derivative and Hedging Activi55

Derivative and Hedging Activities - Derivative Instruments in Balance Sheet Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Derivative, fair value, net	$ (318)	$ (35)
Not designated as hedging instrument [Member] | Commodity contract [Member]
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross liability	(318)	(35)
Derivative liability, fair value, gross asset	0	0
Derivative, fair value, net	(318)	(35)
Other current assets [Member] | Not designated as hedging instrument [Member] | Commodity contract [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	20	157
Derivative asset, fair value, gross liability	(20)	(130)
Derivative, fair value, net	0	27
Other noncurrent assets [Member] | Not designated as hedging instrument [Member] | Commodity contract [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, fair value, gross asset	7
Derivative asset, fair value, gross liability	(7)
Derivative, fair value, net	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	(317)	(188)
Derivative liability, fair value, gross asset	20	130
Derivative, fair value, net	(297)	(58)
Other noncurrent liabilities [Member] | Not designated as hedging instrument [Member] | Commodity contract [Member]
Derivatives, Fair Value [Line Items]
Derivative liability, fair value, gross liability	(28)	(4)
Derivative liability, fair value, gross asset	7	0
Derivative, fair value, net	$ (21)	$ (4)

Derivative and Hedging Activi56

Derivative and Hedging Activities Derivative and Hedging Activities - Oil, Natural Gas and NGL Revenues Table (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended		12 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Derivative [Line Items]
Revenues	$ 2,255		$ 2,281		$ 4,744	$ 5,034
Gains (losses) on undesignated oil, natural gas and NGL derivatives	(251)				(368)
Oil, Natural Gas and NGL Sales [Member]
Derivative [Line Items]
Losses on terminated cash flow hedges	(7)		(7)		(17)	(17)
Oil, Natural Gas and NGL Sales [Member] | Commodity contract [Member] | Not designated as hedging instrument [Member]
Derivative [Line Items]
Gains (losses) on undesignated oil, natural gas and NGL derivatives	(244)		207		(351)	539
Oil, natrual gas and NGL [Member]
Derivative [Line Items]
Revenues	$ 982	$ 1,233	$ 1,279	$ 1,079	$ 2,225	$ 2,748	$ 2,593	$ 2,226

Derivative and Hedging Activi57

Derivative and Hedging Activities - Cash Flow Hedges Components of AOCI Table (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
AOCI Attributable to Parent, Net of Tax [Roll Forward]
AOCI, after tax, beginning of period				$ (57)
Net change in fair value, after tax	[1]	$ 0	$ 0	0	$ 4
Losses reclassified to income, after tax	[1]	7	7	17	17
AOCI, after tax, end of period		(40)		(40)
Cash flow hedging [Member]
AOCI Attributable to Parent, Net of Tax [Roll Forward]
AOCI, before tax, beginning of period		(104)	(139)	(114)	(153)
AOCI, after tax, beginning of period		(47)	(82)	(57)	(96)
Net change in fair value, before tax				0	4
Net change in fair value, after tax				0	4
Losses reclassified to income, before tax		7	7	17	17
Losses reclassified to income, after tax		7	7	17	17
AOCI, before tax, end of period		(97)	(132)	(97)	(132)
AOCI, after tax, end of period		$ (40)	$ (75)	$ (40)	$ (75)
[1]	Deferred tax activity incurred in other comprehensive income was offset by a valuation allowance.

Derivative and Hedging Activi58

Derivative and Hedging Activities - Fair Value of Recurring Assets and Liabilities Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	$ (318)	$ (35)
Commodity contract [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	27	8
Derivative Liability	(345)	(43)
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 2 [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative assets (liabilities), at fair value, net	(273)	(20)
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	20	0
Derivative Liability	(293)	(20)
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	(45)	(15)
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	7	8
Derivative Liability	(52)	(23)
Derivative assets (liabilities), at fair value, net	$ (45)	$ (15)	$ 10	$ (10)

Derivative and Hedging Activi59

Derivative and Hedging Activities - Fair Value Level 3 Measurements Table (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Derivative assets (liabilities), at fair value, net, beginning of period	$ (35)
Derivative assets (liabilities), at fair value, net, end of period	(318)
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	(15)
Derivative assets (liabilities), at fair value, net, end of period	(45)
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]
Gains (loses) included in earnings	(32)	$ 19
Change in unrealized gains (losses) related to assets still held at reporting date	(30)	12
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	(15)	(10)
Gains (loses) included in earnings	(32)	19
Settlements	2	1
Derivative assets (liabilities), at fair value, net, end of period	$ (45)	$ 10

Derivative and Hedging Activi60

Derivative and Hedging Activities - Quantitative Disclosures Level 3 Table (Details) - Energy related derivative [Member] $ in Millions	Jun. 30, 2018USD ($)
Oil [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Fair value, measurement with unobservable inputs reconciliations, recurring basis, liability value	$ (47)
Natural gas [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Fair value, measurement with unobservable inputs reconciliations, recurring basis, asset value	$ 2
Measurement Input, Price Volatility [Member] | Oil [Member] | Weighted average [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.2501
Measurement Input, Price Volatility [Member] | Oil [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.1716
Measurement Input, Price Volatility [Member] | Oil [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.3026
Measurement Input, Price Volatility [Member] | Natural gas [Member] | Weighted average [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.1830
Measurement Input, Price Volatility [Member] | Natural gas [Member] | Minimum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.1423
Measurement Input, Price Volatility [Member] | Natural gas [Member] | Maximum [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items] (Deprecated 2018-01-31)
Measurement input	0.4686

Derivative and Hedging Activi61

Derivative and Hedging Activities - Narrative (Details)	Jun. 30, 2018USD ($)counterpartyDerivatives	Dec. 31, 2017USD ($)Derivatives
Derivative [Line Items]
Number of interest rate derivatives held | Derivatives	0	0
Cash collateral balances for derivatives | $	$ 0	$ 0
Expected amount to be transferred of during the next 12 months | $	$ 33,000,000
Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative, number of instruments held | Derivatives	0	0
Credit Risk [Member]
Derivative [Line Items]
Number of counterparties in hedge facility | counterparty	11

Oil and Natural Gas Property 62

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	6 Months Ended
	Jun. 30, 2018USD ($)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 63

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	6 Months Ended
	Jun. 30, 2018BcfeMMBblsBcf
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)	32 months
Proved Developed Reserves (Energy) | Bcfe	34.8
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)	0.3
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	28.5
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)	0.8

Oil and Natural Gas Property 64

Oil and Natural Gas Property Transactions - Narrative (Details) MMcf in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018USD ($)well	Jun. 30, 2017USD ($)wellMMcf	Jun. 30, 2018USD ($)awell	Jun. 30, 2017USD ($)awellMMcf
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties			$ 384	$ 951
Mid-Continent [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties			$ 491
Number of net acres | a			238,500
Productive gas wells, number of wells, net | well	3,200		3,200
Other properties [Member]
Business Acquisition [Line Items]
Proceeds from divestitures of proved and unproved properties	$ 5	$ 63	$ 23	83
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		576
Haynesville Shale [Member] | Natural gas [Member]
Business Acquisition [Line Items]
Proved developed reserves (volume) | MMcf		80		80

Revenue Recognition - Additiona

Revenue Recognition - Additional Information (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
ASU 2014-09 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Cumulative effect of accounting change	$ 8

Revenue Recognition - Impact of

Revenue Recognition - Impact of Adoption on Balance Sheet and Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018	Dec. 31, 2017
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Other current liabilities	$ 1,277	$ 1,277	$ 1,455
Other long-term liabilities	177	177	354
Accumulated deficit	(16,257)	(16,257)	$ (16,525)
Revenue from contracts with customers	1,233	2,593
Marketing [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contracts with customers	1,273	2,519
Marketing	1,292	2,560
Calculated under revenue guidance in effect before Topic 606 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Other current liabilities	1,275	1,275
Other long-term liabilities	172	172
Accumulated deficit	(16,249)	(16,249)
Calculated under revenue guidance in effect before Topic 606 [Member] | Marketing [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contracts with customers	1,449	2,810
Marketing	1,469	2,852
Difference between revenue guidance in effect before and after Topic 606 [Member] | ASU 2014-09 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Other current liabilities	2	2
Other long-term liabilities	5	5
Accumulated deficit	(8)	(8)
Difference between revenue guidance in effect before and after Topic 606 [Member] | Marketing [Member] | ASU 2014-09 [Member]
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from contracts with customers	(176)	(291)
Marketing	$ (177)	$ (292)

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregated Revenue (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended		12 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 1,233				$ 2,593
Losses on oil, natural gas and NGL derivatives	(251)				(368)
Revenues	2,255		$ 2,281		4,744	$ 5,034
Marcellus [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	169				463
Haynesville [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	200				411
Eagle Ford [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	477				918
Utica [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	226				451
Mid-Continent [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	89				215
Powder River Basin [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	72				135
Oil [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	566				1,103
Losses on oil, natural gas and NGL derivatives	(202)				(288)
Oil [Member] | Marcellus [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0				0
Oil [Member] | Haynesville [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1				2
Oil [Member] | Eagle Ford [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	389				749
Oil [Member] | Utica [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	62				119
Oil [Member] | Mid-Continent [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	62				138
Oil [Member] | Powder River Basin [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	52				95
Natural gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	539				1,245
Losses on oil, natural gas and NGL derivatives	(35)				(67)
Natural gas [Member] | Marcellus [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	169				463
Natural gas [Member] | Haynesville [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	199				409
Natural gas [Member] | Eagle Ford [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	42				84
Natural gas [Member] | Utica [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	103				219
Natural gas [Member] | Mid-Continent [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	15				47
Natural gas [Member] | Powder River Basin [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11				23
NGL [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	128				245
Losses on oil, natural gas and NGL derivatives	(14)				(13)
NGL [Member] | Marcellus [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0				0
NGL [Member] | Haynesville [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0				0
NGL [Member] | Eagle Ford [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	46				85
NGL [Member] | Utica [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	61				113
NGL [Member] | Mid-Continent [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	12				30
NGL [Member] | Powder River Basin [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	9				17
Oil, natrual gas and NGL [Member]
Disaggregation of Revenue [Line Items]
Revenues	982	$ 1,233	1,279	$ 1,079	2,225	2,748	$ 2,593	$ 2,226
Oil, natrual gas and NGL [Member] | Oil [Member]
Disaggregation of Revenue [Line Items]
Revenues	364				815
Oil, natrual gas and NGL [Member] | Natural gas [Member]
Disaggregation of Revenue [Line Items]
Revenues	504				1,178
Oil, natrual gas and NGL [Member] | NGL [Member]
Disaggregation of Revenue [Line Items]
Revenues	114				232
Marketing [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,069				2,158
Revenues	1,273		$ 1,002		2,519	$ 2,286
Marketing [Member] | Oil [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	732				1,418
Revenues	877				1,680
Marketing [Member] | Natural gas [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	235				528
Revenues	294				627
Marketing [Member] | NGL [Member]
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	102				212
Revenues	102				212
Other marketing revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues	204				361
Other marketing revenue [Member] | Oil [Member]
Disaggregation of Revenue [Line Items]
Revenues	145				262
Other marketing revenue [Member] | Natural gas [Member]
Disaggregation of Revenue [Line Items]
Revenues	59				99
Other marketing revenue [Member] | NGL [Member]
Disaggregation of Revenue [Line Items]
Revenues	$ 0				$ 0

Revenue Recognition - Accounts

Revenue Recognition - Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Allowance for doubtful accounts	$ (15)	$ (30)
Accounts receivable, net	1,060	1,322
Oil, Natural Gas and NGL Sales [Member]
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	801	959
Joint Interest [Member]
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	206	209
Other [Member]
Disaggregation of Revenue [Line Items]
Accounts receivable, gross	$ 68	$ 184

Investments Narrative (Details)

Investments Narrative (Details) - FTS International, Inc. [Member] - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage	20.00%	29.00%
Investment, realized gain (loss)	$ 61
Number of shares sold	4.3
Proceeds from sale of equity method investments	$ 74
Shares held (in shares)	22
IPO [Member]
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage	24.00%
Investment, realized gain (loss)	$ 78

Impairments (Details)

Impairments (Details) $ in Millions	3 Months Ended
	Jun. 30, 2018USD ($)
Property, Plant and Equipment [Abstract]
Impairment loss	$ 42

Other Operating Expenses - Narr

Other Operating Expenses - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2018	Jun. 30, 2017
Natural gas [Member]
Property, Plant and Equipment [Line Items]
Loss on contract termination	$ 23	$ 126
Oil [Member]
Property, Plant and Equipment [Line Items]
Loss on contract termination		$ 290

Restructuring and Other Termi72

Restructuring and Other Termination Costs Narrative (Details) - USD ($) $ in Millions	Jan. 30, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Restructuring Cost and Reserve [Line Items]
Restructuring and other termination costs, number of positions eliminated, period percent	13.00%
Restructuring Reserve [Roll Forward]
Restructuring reserve, beginning balance				$ 0
Initial restructuring recognition on January 30, 2018		$ 0	$ 0	38	$ 0
Termination benefits paid				(38)
Restructuring reserve, ending balance		0		$ 0
One-time termination benefits [Member]
Restructuring Reserve [Roll Forward]
Initial restructuring recognition on January 30, 2018	$ 38	$ 38

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	$ 1	$ (3)
Other current assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	53	57
Other current liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	(52)	(60)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	1	(3)
Fair Value, Inputs, Level 1 [Member] | Other current assets [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current assets	53	57
Fair Value, Inputs, Level 1 [Member] | Other current liabilities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other current liabilities	(52)	(60)
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	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	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	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, net asset (liability), total	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	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	$ 0	$ 0

Condensed Consolidating Finan74

Condensed Consolidating Financial Information Narrative (Details)	Jun. 30, 2018
Senior notes [Member]
Condensed Financial Statements, Captions [Line Items]
Noncontrolling interest, ownership percentage by parent	100.00%

Condensed Consolidating Finan75

Condensed Consolidating Financial Information Balance Sheets Table (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017
CURRENT ASSETS:
Cash and cash equivalents	$ 3	$ 5
Other current assets	1,237	1,520
Intercompany receivable, net	0	0
Total Current Assets	1,240	1,525
PROPERTY AND EQUIPMENT:
Oil and natural gas properties at cost, based on full cost accounting, net	9,675	9,350
Other property and equipment, net	1,164	1,314
Property and equipment held for sale, net	11	16
Total Property and Equipment, Net	10,850	10,680
LONG-TERM ASSETS:
Other long-term assets	251	220
Investments in subsidiaries and intercompany advances	0	0
TOTAL ASSETS	12,341	12,425
CURRENT LIABILITIES:
Current liabilities	2,873	2,356
Intercompany payable, net	0	0
Total Current Liabilities	2,873	2,356
LONG-TERM LIABILITIES:
Long-term debt, net	9,238	9,921
Other long-term liabilities	347	520
Total Long-Term Liabilities	9,585	10,441
EQUITY:
Chesapeake stockholders’ equity (deficit)	(240)	(496)
Noncontrolling interests	123	124
Total Equity (Deficit)	(117)	(372)	$ (684)
TOTAL LIABILITIES AND EQUITY	12,341	12,425
Eliminations [Member]
CURRENT ASSETS:
Cash and cash equivalents	(5)	(3)
Other current assets	0	(1)
Intercompany receivable, net	(8,338)	(9,133)
Total Current Assets	(8,343)	(9,137)
PROPERTY AND EQUIPMENT:
Oil and natural gas properties at cost, based on full cost accounting, net	0	0
Other property and equipment, net	0	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	0	0
LONG-TERM ASSETS:
Other long-term assets	0	0
Investments in subsidiaries and intercompany advances	(985)	(660)
TOTAL ASSETS	(9,328)	(9,797)
CURRENT LIABILITIES:
Current liabilities	(5)	(4)
Intercompany payable, net	(8,338)	(9,133)
Total Current Liabilities	(8,343)	(9,137)
LONG-TERM LIABILITIES:
Long-term debt, net	0	0
Other long-term liabilities	0	0
Total Long-Term Liabilities	0	0
EQUITY:
Chesapeake stockholders’ equity (deficit)	(985)	(660)
Noncontrolling interests	0	0
Total Equity (Deficit)	(985)	(660)
TOTAL LIABILITIES AND EQUITY	(9,328)	(9,797)
Parent Company [Member] | Reportable legal entities [Member]
CURRENT ASSETS:
Cash and cash equivalents	5	5
Other current assets	63	154
Intercompany receivable, net	8,132	8,697
Total Current Assets	8,200	8,856
PROPERTY AND EQUIPMENT:
Oil and natural gas properties at cost, based on full cost accounting, net	521	435
Other property and equipment, net	0	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	521	435
LONG-TERM ASSETS:
Other long-term assets	44	52
Investments in subsidiaries and intercompany advances	907	806
TOTAL ASSETS	9,672	10,149
CURRENT LIABILITIES:
Current liabilities	561	190
Intercompany payable, net	32	433
Total Current Liabilities	593	623
LONG-TERM LIABILITIES:
Long-term debt, net	9,238	9,921
Other long-term liabilities	81	101
Total Long-Term Liabilities	9,319	10,022
EQUITY:
Chesapeake stockholders’ equity (deficit)	(240)	(496)
Noncontrolling interests	0	0
Total Equity (Deficit)	(240)	(496)
TOTAL LIABILITIES AND EQUITY	9,672	10,149
Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
CURRENT ASSETS:
Cash and cash equivalents	1	1
Other current assets	1,173	1,364
Intercompany receivable, net	31	436
Total Current Assets	1,205	1,801
PROPERTY AND EQUIPMENT:
Oil and natural gas properties at cost, based on full cost accounting, net	9,129	8,888
Other property and equipment, net	1,164	1,314
Property and equipment held for sale, net	11	16
Total Property and Equipment, Net	10,304	10,218
LONG-TERM ASSETS:
Other long-term assets	207	168
Investments in subsidiaries and intercompany advances	78
Investments in subsidiaries and intercompany advances		(146)
TOTAL ASSETS	11,794	12,041
CURRENT LIABILITIES:
Current liabilities	2,315	2,168
Intercompany payable, net	8,306	8,648
Total Current Liabilities	10,621	10,816
LONG-TERM LIABILITIES:
Long-term debt, net	0	0
Other long-term liabilities	266	419
Total Long-Term Liabilities	266	419
EQUITY:
Chesapeake stockholders’ equity (deficit)	907	806
Noncontrolling interests	0	0
Total Equity (Deficit)	907	806
TOTAL LIABILITIES AND EQUITY	11,794	12,041
Non-Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
CURRENT ASSETS:
Cash and cash equivalents	2	2
Other current assets	1	3
Intercompany receivable, net	175	0
Total Current Assets	178	5
PROPERTY AND EQUIPMENT:
Oil and natural gas properties at cost, based on full cost accounting, net	25	27
Other property and equipment, net	0	0
Property and equipment held for sale, net	0	0
Total Property and Equipment, Net	25	27
LONG-TERM ASSETS:
Other long-term assets	0	0
Investments in subsidiaries and intercompany advances	0	0
TOTAL ASSETS	203	32
CURRENT LIABILITIES:
Current liabilities	2	2
Intercompany payable, net	0	52
Total Current Liabilities	2	54
LONG-TERM LIABILITIES:
Long-term debt, net	0	0
Other long-term liabilities	0	0
Total Long-Term Liabilities	0	0
EQUITY:
Chesapeake stockholders’ equity (deficit)	78	(146)
Noncontrolling interests	123	124
Total Equity (Deficit)	201	(22)
TOTAL LIABILITIES AND EQUITY	$ 203	$ 32

Condensed Consolidating Finan76

Condensed Consolidating Financial Information Income Statements Table (Details) - USD ($) $ in Millions	3 Months Ended					6 Months Ended		12 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
REVENUES:
Revenues	$ 2,255			$ 2,281		$ 4,744	$ 5,034
OPERATING EXPENSES:
Oil, natural gas and NGL production	138			140		285	275
Oil, natural gas and NGL gathering, processing and transportation	340			357		696	712
Production taxes	26			21		57	43
General and administrative	91			70		163	135
Restructuring and other termination costs	0			0		38	0
Provision for legal contingencies, net	4			17		9	15
Oil, natural gas and NGL depreciation, depletion and amortization	271			202		539	399
Depreciation and amortization of other assets	19			21		37	42
Impairments	46			0		46	0
Net (gains) losses on sales of fixed assets	(1)			1		7	1
Other operating (income) expense	(1)			26		(1)	417
Total Operating Expenses	2,225			1,882		4,436	4,394
INCOME FROM OPERATIONS	30			399		308	640
OTHER INCOME (EXPENSE):
Interest income (expense)	(117)			(93)		(240)	(188)
Gains on investments	0			0		139	0
Gains on purchases or exchanges of debt	0	$ 191	$ 184	191		0	184
Other income (expense)	62			(1)		62	2
Equity in net earnings (losses) of subsidiary	0			0		0	0
Total Other Income (Expense)	(55)			97		(39)	(2)
INCOME (LOSS) BEFORE INCOME TAXES	(25)			496		269	638
Income tax expense (benefit)	(9)			1		(9)	2
NET INCOME (LOSS)	(16)			495		278	636
Net income attributable to noncontrolling interests	(1)			(1)		(2)	(2)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(17)			494		276	634
Other comprehensive income	7			7		17	21
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(10)			501		293	655
Eliminations [Member]
REVENUES:
Revenues	0			0		0	0
OPERATING EXPENSES:
Oil, natural gas and NGL production	0			0		0	0
Oil, natural gas and NGL gathering, processing and transportation	0			0		0	0
Production taxes	0			0		0	0
General and administrative	0			0		0	0
Restructuring and other termination costs						0
Provision for legal contingencies, net	0			0		0	0
Oil, natural gas and NGL depreciation, depletion and amortization	0			0		0	0
Depreciation and amortization of other assets	0			0		0	0
Impairments	0					0
Net (gains) losses on sales of fixed assets	0			0		0	0
Other operating (income) expense	0			0		0	0
Total Operating Expenses	0			0		0	0
INCOME FROM OPERATIONS	0			0		0	0
OTHER INCOME (EXPENSE):
Interest income (expense)	0			0		0	0
Gains on investments						0
Gains on purchases or exchanges of debt				0			0
Other income (expense)	0			0		0	0
Equity in net earnings (losses) of subsidiary	(90)			(405)		(508)	(648)
Total Other Income (Expense)	(90)			(405)		(508)	(648)
INCOME (LOSS) BEFORE INCOME TAXES	(90)			(405)		(508)	(648)
Income tax expense (benefit)	0			0		0	0
NET INCOME (LOSS)	(90)			(405)		(508)	(648)
Net income attributable to noncontrolling interests	0			0		0	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(90)			(405)		(508)	(648)
Other comprehensive income	0			0		0	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(90)			(405)		(508)	(648)
Parent Company [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	0			0		0	0
OPERATING EXPENSES:
Oil, natural gas and NGL production	0			0		0	0
Oil, natural gas and NGL gathering, processing and transportation	0			0		0	0
Production taxes	0			0		0	0
General and administrative	0			3		0	3
Restructuring and other termination costs						0
Provision for legal contingencies, net	0			0		0	0
Oil, natural gas and NGL depreciation, depletion and amortization	0			0		0	0
Depreciation and amortization of other assets	0			0		0	0
Impairments	0					0
Net (gains) losses on sales of fixed assets	0			0		0	0
Other operating (income) expense	0			0		0	0
Total Operating Expenses	0			3		0	3
INCOME FROM OPERATIONS	0			(3)		0	(3)
OTHER INCOME (EXPENSE):
Interest income (expense)	(117)			(95)		(240)	(190)
Gains on investments						0
Gains on purchases or exchanges of debt				191			184
Other income (expense)	0			0		0	0
Equity in net earnings (losses) of subsidiary	91			402		507	645
Total Other Income (Expense)	(26)			498		267	639
INCOME (LOSS) BEFORE INCOME TAXES	(26)			495		267	636
Income tax expense (benefit)	(9)			1		(9)	2
NET INCOME (LOSS)	(17)			494		276	634
Net income attributable to noncontrolling interests	0			0		0	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(17)			494		276	634
Other comprehensive income	0			0		0	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(17)			494		276	634
Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	2,251			2,275		4,735	5,022
OPERATING EXPENSES:
Oil, natural gas and NGL production	138			140		285	275
Oil, natural gas and NGL gathering, processing and transportation	338			355		693	708
Production taxes	26			21		57	43
General and administrative	90			67		162	131
Restructuring and other termination costs						38
Provision for legal contingencies, net	4			17		9	15
Oil, natural gas and NGL depreciation, depletion and amortization	270			202		537	397
Depreciation and amortization of other assets	19			21		37	42
Impairments	46					46
Net (gains) losses on sales of fixed assets	(1)			1		7	1
Other operating (income) expense	(1)			26		(1)	417
Total Operating Expenses	2,221			1,877		4,430	4,384
INCOME FROM OPERATIONS	30			398		305	638
OTHER INCOME (EXPENSE):
Interest income (expense)	0			2		0	2
Gains on investments						139
Gains on purchases or exchanges of debt				0			0
Other income (expense)	62			(1)		62	2
Equity in net earnings (losses) of subsidiary				3		1	3
Equity in net earnings (losses) of subsidiary	(1)
Total Other Income (Expense)	61			4		202	7
INCOME (LOSS) BEFORE INCOME TAXES	91			402		507	645
Income tax expense (benefit)	0			0		0	0
NET INCOME (LOSS)	91			402		507	645
Net income attributable to noncontrolling interests	0			0		0	0
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	91			402		507	645
Other comprehensive income	7			7		17	21
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	98			409		524	666
Non-Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	4			6		9	12
OPERATING EXPENSES:
Oil, natural gas and NGL production	0			0		0	0
Oil, natural gas and NGL gathering, processing and transportation	2			2		3	4
Production taxes	0			0		0	0
General and administrative	1			0		1	1
Restructuring and other termination costs						0
Provision for legal contingencies, net	0			0		0	0
Oil, natural gas and NGL depreciation, depletion and amortization	1			0		2	2
Depreciation and amortization of other assets	0			0		0	0
Impairments	0					0
Net (gains) losses on sales of fixed assets	0			0		0	0
Other operating (income) expense	0			0		0	0
Total Operating Expenses	4			2		6	7
INCOME FROM OPERATIONS	0			4		3	5
OTHER INCOME (EXPENSE):
Interest income (expense)	0			0		0	0
Gains on investments						0
Gains on purchases or exchanges of debt				0			0
Other income (expense)	0			0		0	0
Equity in net earnings (losses) of subsidiary	0			0		0	0
Total Other Income (Expense)	0			0		0	0
INCOME (LOSS) BEFORE INCOME TAXES	0			4		3	5
Income tax expense (benefit)	0			0		0	0
NET INCOME (LOSS)	0			4		3	5
Net income attributable to noncontrolling interests	(1)			(1)		(2)	(2)
NET INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(1)			3		1	3
Other comprehensive income	0			0		0	0
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO CHESAPEAKE	(1)			3		1	3
Oil, natrual gas and NGL [Member]
REVENUES:
Revenues	982	$ 1,233		1,279	$ 1,079	2,225	2,748	$ 2,593	$ 2,226
Oil, natrual gas and NGL [Member] | Eliminations [Member]
REVENUES:
Revenues	0			0		0	0
Oil, natrual gas and NGL [Member] | Parent Company [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	0			0		0	0
Oil, natrual gas and NGL [Member] | Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	978			1,273		2,216	2,736
Oil, natrual gas and NGL [Member] | Non-Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	4			6		9	12
Marketing [Member]
REVENUES:
Revenues	1,273			1,002		2,519	2,286
OPERATING EXPENSES:
Marketing	1,292			1,027		2,560	2,355
Marketing [Member] | Eliminations [Member]
REVENUES:
Revenues	0			0		0	0
OPERATING EXPENSES:
Marketing	0			0		0	0
Marketing [Member] | Parent Company [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	0			0		0	0
OPERATING EXPENSES:
Marketing	0			0		0	0
Marketing [Member] | Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	1,273			1,002		2,519	2,286
OPERATING EXPENSES:
Marketing	1,292			1,027		2,560	2,355
Marketing [Member] | Non-Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
REVENUES:
Revenues	0			0		0	0
OPERATING EXPENSES:
Marketing	$ 0			$ 0		$ 0	$ 0

Condensed Consolidating Finan77

Condensed Consolidating Financial Information Statements of Cash Flows Tables (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	$ 1,091	$ (58)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(979)	(1,031)
Acquisitions of proved and unproved properties	(191)	(162)
Proceeds from divestitures of proved and unproved properties	384	951
Additions to other property and equipment	(5)	(7)
Other investing activities	148	26
Net Cash Used In Investing Activities	(643)	(223)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	6,118	2,551
Payments on revolving credit facility borrowings	(6,393)	(1,976)
Proceeds from issuance of senior notes, net	0	742
Cash paid to purchase debt	0	(1,746)
Cash paid for preferred stock dividends	(46)	(137)
Other financing activities	(129)	(22)
Intercompany advances, net	0	0
Net Cash Used In Financing Activities	(450)	(588)
Net decrease in cash and cash equivalents	(2)	(869)
Cash and cash equivalents, beginning of period	5	882
Cash and cash equivalents, end of period	3	13
Eliminations [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	(8)	(4)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	0	0
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	0	0
Other investing activities	0	0
Net Cash Used In Investing Activities	0	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	0	0
Payments on revolving credit facility borrowings	0	0
Proceeds from issuance of senior notes, net		0
Cash paid to purchase debt		0
Cash paid for preferred stock dividends	0	0
Other financing activities	6	25
Intercompany advances, net	0	0
Net Cash Used In Financing Activities	6	25
Net decrease in cash and cash equivalents	(2)	21
Cash and cash equivalents, beginning of period	(3)	(25)
Cash and cash equivalents, end of period	(5)	(4)
Parent Company [Member] | Reportable legal entities [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	88	2
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	0	0
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	0	0
Other investing activities	0	0
Net Cash Used In Investing Activities	0	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	6,118	2,551
Payments on revolving credit facility borrowings	(6,393)	(1,976)
Proceeds from issuance of senior notes, net		742
Cash paid to purchase debt		(1,746)
Cash paid for preferred stock dividends	(46)	(137)
Other financing activities	(2)	(38)
Intercompany advances, net		(287)
Intercompany advances, net	235
Net Cash Used In Financing Activities	(88)	(891)
Net decrease in cash and cash equivalents	0	(889)
Cash and cash equivalents, beginning of period	5	904
Cash and cash equivalents, end of period	5	15
Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	1,006	(64)
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	(979)	(1,031)
Acquisitions of proved and unproved properties	(191)	(162)
Proceeds from divestitures of proved and unproved properties	384	951
Additions to other property and equipment	(5)	(7)
Other investing activities	148	26
Net Cash Used In Investing Activities	(643)	(223)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	0	0
Payments on revolving credit facility borrowings	0	0
Proceeds from issuance of senior notes, net		0
Cash paid to purchase debt		0
Cash paid for preferred stock dividends	0	0
Other financing activities	(126)	(2)
Intercompany advances, net	(237)
Intercompany advances, net		288
Net Cash Used In Financing Activities	(363)	286
Net decrease in cash and cash equivalents	0	(1)
Cash and cash equivalents, beginning of period	1	2
Cash and cash equivalents, end of period	1	1
Non-Guarantor Subsidiaries [Member] | Reportable legal entities [Member]
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Cash Provided By Operating Activities	5	8
CASH FLOWS FROM INVESTING ACTIVITIES:
Drilling and completion costs	0	0
Acquisitions of proved and unproved properties	0	0
Proceeds from divestitures of proved and unproved properties	0	0
Additions to other property and equipment	0	0
Other investing activities	0	0
Net Cash Used In Investing Activities	0	0
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from revolving credit facility borrowings	0	0
Payments on revolving credit facility borrowings	0	0
Proceeds from issuance of senior notes, net		0
Cash paid to purchase debt		0
Cash paid for preferred stock dividends	0	0
Other financing activities	(7)	(7)
Intercompany advances, net		(1)
Intercompany advances, net	2
Net Cash Used In Financing Activities	(5)	(8)
Net decrease in cash and cash equivalents	0	0
Cash and cash equivalents, beginning of period	2	1
Cash and cash equivalents, end of period	$ 2	$ 1

Subsequent Events Subsequent Ev

Subsequent Events Subsequent Events - Narrative (Details) - Utica Shale [Member] - Disposal group, disposed of by sale, not discontinued operations [Member] a in Thousands, Mcfe in Thousands, Boe in Thousands	Jul. 26, 2018USD ($)aday$ / BTU	Dec. 31, 2017BoeMcfewell
Subsequent Event [Line Items]
Productive gas wells, number of wells, net | well		920
Produced BOEs per day | Boe		107
Reserves | Boe		480,000
Subsequent event [Member]
Subsequent Event [Line Items]
Area of land, gross (in acres) | a	1,500
Area of land, net (in acres) | a	900
Consideration | $	$ 2,000,000,000
Future natural gas prices [Member] | Subsequent event [Member]
Subsequent Event [Line Items]
Consideration | $	$ 100,000,000
Period of trading days | day	20
Consecutive trading days | day	30
Commercial Shale [Member] | Subsequent event [Member]
Subsequent Event [Line Items]
Area of land, net (in acres) | a	320
NGL [Member]
Subsequent Event [Line Items]
Produced BOEs per day | Mcfe		427
Reserves, percent		23.00%
Natural gas [Member]
Subsequent Event [Line Items]
Produced BOEs per day | Boe		26
Reserves, percent		72.00%
Oil [Member]
Subsequent Event [Line Items]
Produced BOEs per day | Boe		10
Reserves, percent		5.00%
2022 NYMEX Natural Gas [Member] | Future natural gas prices [Member] | Subsequent event [Member]
Subsequent Event [Line Items]
Consideration | $	$ 50,000,000
Average Sales Prices | $ / BTU	3
2023 NYMEX Natural Gas [Member] | Future natural gas prices [Member] | Subsequent event [Member]
Subsequent Event [Line Items]
Consideration | $	$ 50,000,000
Average Sales Prices | $ / BTU	3.25