Pressburg (ROAN) 10-Q 3 May 18 2018 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2018	Apr. 30, 2018
Document and Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	Mar. 31, 2018
Amendment Flag	false
Entity Registrant Name	Linn Energy, Inc.
Entity Central Index Key	1,326,428
Current Fiscal Year End	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		79,038,702
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 227,196	$ 464,508
Accounts receivable – trade, net	130,527	140,485
Derivative instruments	7,287	9,629
Restricted cash	77,263	56,445
Other current assets	65,213	79,771
Assets held for sale	92,492	106,963
Total current assets	599,978	857,801
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	778,091	950,083
Less accumulated depletion and amortization	(48,142)	(49,619)
Oil and natural gas properties, successful efforts method, net	729,949	900,464
Other property and equipment	533,078	480,729
Less accumulated depreciation	(36,326)	(28,658)
Other property and equipment, net	496,752	452,071
Derivative instruments	936	469
Deferred income taxes	162,709	198,417
Equity method investments	490,503	464,926
Other noncurrent assets	5,983	6,975
Noncurrent assets, excluding property, total	660,131	670,787
Total noncurrent assets	1,886,832	2,023,322
Total assets	2,486,810	2,881,123
Current liabilities:
Accounts payable and accrued expenses	264,973	253,975
Derivative instruments	16,931	10,103
Other accrued liabilities	38,948	58,617
Liabilities held for sale	42,891	43,302
Total current liabilities	363,743	365,997
Derivative instruments	4,682	2,849
Asset retirement obligations and other noncurrent liabilities	104,730	160,720
Total noncurrent liabilities	109,412	163,569
Commitments and contingencies (Note 11)
Equity:
Preferred stock ($0.001 par value, 30,000,000 shares authorized; no shares issued at March 31, 2018, or December 31, 2017)	0	0
Class A common stock ($0.001 par value, 270,000,000 shares authorized; 76,492,933 shares and 83,582,176 shares issued at March 31, 2018, and December 31, 2017, respectively)	76	84
Additional paid-in capital	1,478,365	1,899,642
Retained earnings	502,684	432,860
Total common stockholders’ equity	1,981,125	2,332,586
Noncontrolling interests	32,530	18,971
Total equity	2,013,655	2,351,557
Total liabilities and equity	$ 2,486,810	$ 2,881,123

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Mar. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Common stock par value	$ 0.001	$ 0.001
Common stock authorized	270,000,000	270,000,000
Common stock issued	76,492,933	83,582,176
Preferred stock par value	$ 0.001	$ 0.001
Preferred stock authorized	30,000,000	30,000,000
Preferred stock issued	0	0

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Other income and (expenses):
Net income (loss)			$ 71,098
Successor
Revenues and other:
Oil, natural gas and natural gas liquids sales	$ 80,325		136,876
Gains (losses) on oil and natural gas derivatives	(11,959)		(15,030)
Marketing revenues	2,914		46,267
Other revenues	2,028		5,894
Total revenues	73,308		174,007
Expenses:
Lease operating expenses	24,630		47,884
Transportation expenses	13,723		19,094
Marketing expenses	2,539		41,755
General and administrative expenses	10,411		44,779
Exploration costs	55		1,202
Depreciation, depletion and amortization	19,914		28,465
Taxes, other than income taxes	7,077		8,452
(Gains) losses on sale of assets and other, net	484		(106,075)
Total expenses	78,833		85,556
Other income and (expenses):
Interest expense, net of amounts capitalized	(4,200)		(404)
Earnings from equity method investments	39		25,345
Other, net	(388)		(169)
Total other income and (expenses)	(4,549)		24,772
Reorganization items, net	(2,565)		(1,951)
Income (loss) from continuing operations before income taxes	(12,639)		111,272
Income tax expense (benefit)	(5,315)		40,174
Income (loss) from continuing operations	(7,324)		71,098
Income (loss) from discontinued operations, net of income taxes	68		0
Net income (loss)	(7,256)		71,098
Net income attributable to noncontrolling interests	0		1,274
Net income (loss) attributable to common stockholders/unitholders	$ (7,256)		$ 69,824
Income (loss) from continuing operations per share/unit – Basic	$ (0.08)		$ 0.88
Income (loss) from continuing operations per share/unit – Diluted	(0.08)		0.86
Income (loss) from discontinued operations per share/unit – Basic	0		0
Income (loss) from discontinued operations per share/unit – Diluted	0		0
Net income (loss) per share/unit – Basic	(0.08)		0.88
Net income (loss) per share/unit – Diluted	$ (0.08)		$ 0.86
Weighted average shares/units outstanding – Basic	89,848		78,975
Weighted average shares/units outstanding – Diluted	89,848		80,332
Predecessor
Revenues and other:
Oil, natural gas and natural gas liquids sales		$ 188,885
Gains (losses) on oil and natural gas derivatives		92,691
Marketing revenues		6,636
Other revenues		9,915
Total revenues		298,127
Expenses:
Lease operating expenses		49,665
Transportation expenses		25,972
Marketing expenses		4,820
General and administrative expenses		71,745
Exploration costs		93
Depreciation, depletion and amortization		47,155
Taxes, other than income taxes		14,877
(Gains) losses on sale of assets and other, net		829
Total expenses		215,156
Other income and (expenses):
Interest expense, net of amounts capitalized		(16,725)
Earnings from equity method investments		157
Other, net		(149)
Total other income and (expenses)		(16,717)
Reorganization items, net		2,331,189
Income (loss) from continuing operations before income taxes		2,397,443
Income tax expense (benefit)		(166)
Income (loss) from continuing operations		2,397,609
Income (loss) from discontinued operations, net of income taxes		(548)
Net income (loss)		2,397,061
Net income attributable to noncontrolling interests		0
Net income (loss) attributable to common stockholders/unitholders		$ 2,397,061
Income (loss) from continuing operations per share/unit – Basic		$ 6.80
Income (loss) from continuing operations per share/unit – Diluted		6.80
Income (loss) from discontinued operations per share/unit – Basic		(0.01)
Income (loss) from discontinued operations per share/unit – Diluted		(0.01)
Net income (loss) per share/unit – Basic		6.79
Net income (loss) per share/unit – Diluted		$ 6.79
Weighted average shares/units outstanding – Basic		352,792
Weighted average shares/units outstanding – Diluted		352,792

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENT OF EQUITY (Unaudited) Statement - 3 months ended Mar. 31, 2018 - USD ($) shares in Thousands, $ in Thousands	Total	Amount	Additional Paid-in Capital	Accumulated Deficit	Total Common Stockholders’ Equity	Noncontrolling Interests
Beginning of period (in shares) at Dec. 31, 2017	83,582
Beginning of period at Dec. 31, 2017	$ 2,332,586	$ 84	$ 1,899,642	$ 432,860	$ 2,332,586
Beginning of period at Dec. 31, 2017	18,971					$ 18,971
Beginning of period at Dec. 31, 2017	2,351,557
Net income		0	0	69,824	69,824
Net income						1,274
Net income	$ 71,098
Issuances of successor Class A common stock	649
Issuances of successor Class A common stock	$ 0	0	0	0	0	0
Repurchases of successor Class A common stock	(7,738)
Repurchases of successor Class A common stock	$ (368,214)	(8)	(368,206)	0	(368,214)	0
Settlement of RSUs	(49,234)	0	(49,234)	0	(49,234)	0
Share-based compensation expenses	17,037	0	17,037	0	17,037	0
Allocation of noncontrolling interest upon vesting of subsidiary units	0	0	(21,233)	0	(21,233)	21,233
Distributions to noncontrolling interests	(8,367)	0	0	0	0	(8,367)
Subsidiary equity transactions	0	0	581	0	581	(581)
Other	$ (222)	0	(222)	0	(222)	0
End of period (in shares) at Mar. 31, 2018	76,493
End of period at Mar. 31, 2018	$ 1,981,125	$ 76	$ 1,478,365	$ 502,684	$ 1,981,125
End of period at Mar. 31, 2018	32,530					$ 32,530
End of period at Mar. 31, 2018	$ 2,013,655

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Cash flow from operating activities:
Net income (loss)			$ 71,098
Cash flow from financing activities:
Cash settlements of RSUs			49,234
Successor
Cash flow from operating activities:
Net income (loss)	$ (7,256)		71,098
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
(Income) loss from discontinued operations	(68)		0
Depreciation, depletion and amortization	19,914		28,465
Deferred income taxes	(5,034)		40,660
Total (gains) losses on derivatives, net	11,959		15,030
Cash settlements on derivatives	5,782		(4,494)
Share-based compensation expenses	4,177		17,037
Amortization and write-off of deferred financing fees	3		404
(Gains) losses on sale of assets and other, net	345		(131,330)
Reorganization items, net	0		0
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	26,614		5,415
(Increase) decrease in other assets	(2,553)		14,176
Increase (decrease) in accounts payable and accrued expenses	(43,476)		15,711
Increase (decrease) in other liabilities	4,187		(24,362)
Net cash provided by operating activities – continuing operations	14,594		47,810
Net cash provided by operating activities – discontinued operations	3,166		0
Net cash provided by operating activities	17,760		47,810
Cash flow from investing activities:
Development of oil and natural gas properties	(19,779)		(26,024)
Purchases of other property and equipment	(2,466)		(46,110)
Proceeds from sale of properties and equipment and other	326		232,394
Net cash provided by (used in) investing activities – continuing operations	(21,919)		160,260
Net cash used in investing activities – discontinued operations	(465)		0
Net cash provided by (used in) investing activities	(22,384)		160,260
Cash flow from financing activities:
Proceeds from rights offerings, net	0		0
Repurchases of shares	0		(367,830)
Proceeds from borrowings	30,000		0
Repayments of debt	(96,250)		0
Payment to holders of claims under the Predecessor’s second lien notes	0		0
Distributions to noncontrolling interests	0		(8,007)
Cash settlements of RSUs	0		48,701
Other	17,658		(26)
Net cash used in financing activities – continuing operations	(48,592)		(424,564)
Net cash used in financing activities – discontinued operations	0		0
Net cash used in financing activities	(48,592)		(424,564)
Net decrease in cash, cash equivalents and restricted cash	(53,216)		(216,494)
Cash, cash equivalents and restricted cash:
Beginning	144,022		520,953
Ending	90,806	$ 144,022	$ 304,459
Predecessor
Cash flow from operating activities:
Net income (loss)		2,397,061
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
(Income) loss from discontinued operations		548
Depreciation, depletion and amortization		47,155
Deferred income taxes		(166)
Total (gains) losses on derivatives, net		(92,691)
Cash settlements on derivatives		(11,572)
Share-based compensation expenses		50,255
Amortization and write-off of deferred financing fees		1,338
(Gains) losses on sale of assets and other, net		1,069
Reorganization items, net		(2,359,364)
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net		(7,216)
(Increase) decrease in other assets		528
Increase (decrease) in accounts payable and accrued expenses		20,949
Increase (decrease) in other liabilities		2,801
Net cash provided by operating activities – continuing operations		50,695
Net cash provided by operating activities – discontinued operations		8,781
Net cash provided by operating activities		59,476
Cash flow from investing activities:
Development of oil and natural gas properties		(50,597)
Purchases of other property and equipment		(7,409)
Proceeds from sale of properties and equipment and other		(166)
Net cash provided by (used in) investing activities – continuing operations		(58,172)
Net cash used in investing activities – discontinued operations		(584)
Net cash provided by (used in) investing activities		(58,756)
Cash flow from financing activities:
Proceeds from rights offerings, net		514,069
Repurchases of shares		0
Proceeds from borrowings		0
Repayments of debt		(1,038,986)
Payment to holders of claims under the Predecessor’s second lien notes		(30,000)
Distributions to noncontrolling interests		0
Cash settlements of RSUs		0
Other		(6,015)
Net cash used in financing activities – continuing operations		(560,932)
Net cash used in financing activities – discontinued operations		0
Net cash used in financing activities		(560,932)
Net decrease in cash, cash equivalents and restricted cash		(560,212)
Cash, cash equivalents and restricted cash:
Beginning	$ 144,022	704,234
Ending		$ 144,022

Basis of Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation When referring to Linn Energy, Inc. (“Successor,” “LINN Energy” or the “Company”), the intent is to refer to LINN Energy, a Delaware corporation formed in February 2017, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. Linn Energy, Inc. is a successor issuer of Linn Energy, LLC pursuant to Rule 15d‑5 of the Securities Exchange Act of 1934, as amended. Linn Energy, Inc. is not a successor of Linn Energy, LLC for purposes of Delaware corporate law. When referring to the “Predecessor” in reference to the period prior to the emergence from bankruptcy, the intent is to refer to Linn Energy, LLC, the predecessor that will be dissolved following the effective date of the Plan (as defined in Note 2) and resolution of all outstanding claims, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. The reference to “Berry” herein refers to Berry Petroleum Company, LLC, which was an indirect 100% wholly owned subsidiary of the Predecessor through February 28, 2017. Berry was deconsolidated effective December 3, 2016. The reference to “LinnCo” herein refers to LinnCo, LLC, which was an affiliate of the Predecessor. Nature of Business LINN Energy is an independent oil and natural gas company that was formed in February 2017, in connection with the reorganization of the Predecessor. The Predecessor was publicly traded from January 2006 to February 2017. As discussed further in Note 2, on May 11, 2016 (the “Petition Date”), Linn Energy, LLC, certain of its direct and indirect subsidiaries, and LinnCo (collectively, the “LINN Debtors”) and Berry (collectively with the LINN Debtors, the “Debtors”), filed voluntary petitions (“Bankruptcy Petitions”) for relief under Chapter 11 of the U.S. Bankruptcy Code (“Bankruptcy Code”) in the U.S. Bankruptcy Court for the Southern District of Texas (“Bankruptcy Court”). The Debtors’ Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16-60040. During the pendency of the Chapter 11 proceedings, the Debtors operated their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code. The Company emerged from bankruptcy effective February 28, 2017. The Company’s properties are currently located in six operating regions in the United States (“U.S.”): the Hugoton Basin, East Texas, North Louisiana, Michigan/Illinois, the Rockies and the Mid-Continent. The Company also owns a 50% equity interest in Roan Resources LLC (“Roan”), which is focused on the accelerated development of the Merge/SCOOP/STACK play in Oklahoma. During 2018, the Company divested all of its properties located in the previous Permian Basin operating region. During 2017, the Company divested all of its properties located in the previous California and South Texas operating regions. Principles of Consolidation and Reporting The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 . The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year. The condensed consolidated financial statements include the accounts of the Company and its subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Noncontrolling interests represent ownership in the net assets of the Company’s consolidated subsidiary, Linn Energy Holdco LLC (“Holdco”), not attributable to LINN Energy, and are presented as a component of equity. Changes in the Company’s ownership interests in Holdco that do not result in deconsolidation are recognized in equity. See Note 13 for additional information about noncontrolling interests. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. See Note 6 for additional information about equity method investments. The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. The Company has also classified the results of operations and cash flows of its California properties as discontinued operations on its condensed consolidated financial statements. Such reclassifications have no impact on previously reported net income (loss) or stockholders equity. See Note 4 for additional information. As a result of the adoption of ASU 2016-18 and the inclusion of restricted cash in the statements of cash flows, previously reported net cash provided by operating activities has been updated to conform to current presentation. See recently adopted accounting standards below for additional information. Bankruptcy Accounting Upon emergence from bankruptcy on February 28, 2017, the Company adopted fresh start accounting which resulted in the Company becoming a new entity for financial reporting purposes. As a result of the adoption of fresh start accounting and the effects of the implementation of the Plan, the Company’s condensed consolidated financial statements subsequent to February 28, 2017, are not comparable to its condensed consolidated financial statements prior to February 28, 2017. References to “Successor” relate to the financial position and results of operations of the reorganized Company subsequent to February 28, 2017. References to “Predecessor” relate to the financial position of the Company prior to, and results of operations through and including, February 28, 2017. The Company’s condensed consolidated financial statements and related footnotes are presented with a black line division, which delineates the lack of comparability between amounts presented after February 28, 2017, and amounts presented on or prior to February 28, 2017. See Note 2 for additional information. Use of Estimates The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, and fair values of commodity derivatives. In addition, as part of fresh start accounting, the Company made estimates and assumptions related to its reorganization value, liabilities subject to compromise, the fair value of assets and liabilities recorded as a result of the adoption of fresh start accounting and income taxes. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods. Recently Adopted Accounting Standards In November 2016, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to address diversity in the classification and presentation of changes in restricted cash on the statement of cash flows. The Company adopted this ASU on January 1, 2018, on a retrospective basis. The adoption of this ASU resulted in the inclusion of restricted cash in the beginning and ending balances of cash on the statements of cash flows and disclosure reconciling cash and cash equivalents presented on the balance sheets to cash, cash equivalents and restricted cash on the statement of cash flows (see Note 17). In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers (“ASC 606”). The Company adopted this ASU on January 1, 2018, using the modified retrospective transition method. Accordingly, the comparative information for the three months ended March 31, 2017 , has not been adjusted and continues to be reported under the previous revenue standard. The adoption of this ASU impacted the Company’s gross revenues and expenses as reported on its condensed consolidated statements of operations (see below), and resulted in increased disclosures regarding the Company’s disaggregation of revenue (see Note 3). Under ASC 606, the Company recognizes revenues based on a determination of when control of its commodities is transferred and whether it is acting as a principal or agent in certain transactions. All facts and circumstances of an arrangement are considered and judgment is often required in making this determination. For its natural gas contracts, the Company generally records its sales at the wellhead or inlet of the plant as revenues net of transportation, gathering and processing expenses if the processor is the customer and there is no redelivery of commodities to the Company. Conversely, the Company generally records its sales at the tailgate of the plant on a gross basis along with the associated transportation, gathering and processing expenses if the processor is a service provider and there is redelivery of commodities to the Company. In addition, the Company recognizes revenues for commodities received as noncash consideration in exchange for services provided by its midstream operations and revenues and associated cost of product for the subsequent sale of those same commodities. This recognition results in an increase to revenues and expenses with no material impact on net income. The items discussed above impacted the Company’s reported “oil, natural gas and natural gas liquids sales,” “marketing revenues,” “transportation expenses” and “marketing expenses.” The impact of adoption on the Company’s current period results is as follows: Three Months Ended March 31, 2018 Under ASC 606 Under Prior Rule Increase/ (Decrease) (in thousands) Revenues: Natural gas sales $ 63,328 $ 64,509 $ (1,181 ) Oil sales 45,696 45,696 — NGL sales 27,852 27,942 (90 ) Total oil, natural gas and NGL sales 136,876 138,147 (1,271 ) Marketing revenues 46,267 28,115 18,152 Other revenues 5,894 5,673 221 189,037 171,935 17,102 Expenses: Transportation expenses 19,094 20,365 (1,271 ) Marketing expenses 41,755 23,603 18,152 Net income $ 71,098 $ 70,877 $ 221 New Accounting Standards Issued But Not Yet Adopted In February 2016, the FASB issued an ASU that is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2018, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its financial statements and related disclosures. The Company expects the adoption of this ASU to impact its balance sheets resulting from an increase in both assets and liabilities related to the Company’s leasing activities.

Emergence From Voluntary Reorga

Emergence From Voluntary Reorganization Under Chapter 11 and Fresh Start Accounting	3 Months Ended
	Mar. 31, 2018
Emergence From Voluntary Reorganization Under Chapter 11 [Abstract]
Emergence From Voluntary Reorganization Under Chapter 11 and Fresh Start Accounting	Emergence From Voluntary Reorganization Under Chapter 11 and Fresh Start Accounting On the Petition Date, the Debtors filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code in the Bankruptcy Court. The Debtors’ Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16‑60040. On December 3, 2016, the LINN Debtors filed the Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and Its Debtor Affiliates Other Than Linn Acquisition Company, LLC (“LAC”) and Berry Petroleum Company, LLC (the “Plan”). The LINN Debtors subsequently filed amended versions of the Plan with the Bankruptcy Court. On December 13, 2016, LAC and Berry filed the Amended Joint Chapter 11 Plan of Reorganization of Linn Acquisition Company, LLC and Berry Petroleum Company, LLC (the “Berry Plan” and together with the Plan, the “Plans”). LAC and Berry subsequently filed amended versions of the Berry Plan with the Bankruptcy Court. On January 27, 2017, the Bankruptcy Court entered an order approving and confirming the Plans (the “Confirmation Order”). On February 28, 2017 (the “Effective Date”), the Debtors satisfied the conditions to effectiveness of the respective Plans, the Plans became effective in accordance with their respective terms and LINN Energy and Berry emerged from bankruptcy as stand-alone, unaffiliated entities. Reorganization Items, Net The Company incurred significant costs and recognized significant gains associated with the reorganization. Reorganization items represent costs and income directly associated with the Chapter 11 proceedings since the Petition Date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments were determined. The following table summarizes the components of reorganization items included on the condensed consolidated statements of operations: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Gain on settlement of liabilities subject to compromise $ — $ — $ 3,724,750 Recognition of an additional claim for the Predecessor’s second lien notes settlement — — (1,000,000 ) Fresh start valuation adjustments — — (591,525 ) Income tax benefit related to implementation of the Plan — — 264,889 Legal and other professional fees (1,952 ) (2,570 ) (46,961 ) Terminated contracts — — (6,915 ) Other 1 5 (13,049 ) Reorganization items, net $ (1,951 ) $ (2,565 ) $ 2,331,189 Fresh Start Accounting Upon the Company’s emergence from Chapter 11 bankruptcy, it adopted fresh start accounting in accordance with the provisions of Accounting Standards Codification 852 “Reorganizations” (“ASC 852”), which resulted in the Company becoming a new entity for financial reporting purposes. In accordance with ASC 852, the Company was required to adopt fresh start accounting upon its emergence from Chapter 11 because (i) the holders of existing voting ownership interests of the Predecessor received less than 50% of the voting shares of the Successor and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the Plan was less than the total of all post-petition liabilities and allowed claims. Upon adoption of fresh start accounting, the reorganization value derived from the enterprise value as disclosed in the Plan was allocated to the Company’s assets and liabilities based on their fair values (except for deferred income taxes) in accordance with ASC 805 “Business Combinations.” The amount of deferred income taxes recorded was determined in accordance with ASC 740 “Income Taxes.” The Effective Date fair values of the Company’s assets and liabilities differed materially from their recorded values as reflected on the historical balance sheet. The effects of the Plan and the application of fresh start accounting were reflected on the condensed consolidated balance sheet as of February 28, 2017, and the related adjustments thereto were recorded on the condensed consolidated statement of operations for the two months ended February 28, 2017.

Revenues

Revenues	3 Months Ended
	Mar. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenues	Revenues Revenue from Contracts with Customers The Company recognizes sales of oil, natural gas and NGL when it satisfies a performance obligation by transferring control of the product to a customer, in an amount that reflects the consideration to which the Company expects to be entitled in exchange for the product. Natural Gas and NGL Sales The Company’s natural gas production is primarily sold under market-sensitive contracts that are typically priced at a differential to the published natural gas index price for the producing area due to the natural gas quality and the proximity to major consuming markets. For its natural gas contracts, the Company generally records its wet gas sales at the wellhead or inlet of the plant as revenues net of transportation, gathering and processing expenses, and its residual natural gas and NGL sales at the tailgate of the plant on a gross basis along with the associated transportation, gathering and processing expenses. All facts and circumstances of an arrangement are considered and judgment is often required in making this determination. Oil Sales The Company’s oil production is primarily sold under market-sensitive contracts that are typically priced at a differential to the New York Mercantile Exchange (“NYMEX”) price or at purchaser posted prices for the producing area. For its oil contracts, the Company generally records its sales based on the net amount received. Production Imbalances The Company uses the sales method to account for natural gas production imbalances. If the Company’s sales volumes for a well exceed the Company’s proportionate share of production from the well, a liability is recognized to the extent that the Company’s share of estimated remaining recoverable reserves from the well is insufficient to satisfy this imbalance. No receivables are recorded for those wells on which the Company has taken less than its proportionate share of production. Marketing Revenues The Company engages in the purchase, gathering and transportation of third-party natural gas and subsequently markets such natural gas to independent purchasers under separate arrangements. As such, the Company separately reports third-party marketing revenues and marketing expenses. Disaggregation of Revenue The following tables present the Company’s disaggregated revenues by source and geographic area: Successor Three Months Ended March 31, 2018 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 22,363 $ 2,732 $ 19,514 $ 44,609 $ 24,080 $ 5,831 $ 74,520 Mid-Continent 7,933 11,867 3,054 22,854 21,892 14 44,760 Permian Basin 2,026 20,108 3,045 25,179 — 16 25,195 East Texas 14,776 1,340 1,306 17,422 36 5 17,463 Rockies 3,380 7,370 1,358 12,108 — (2 ) 12,106 North Louisiana 6,378 1,569 (436 ) 7,511 259 1 7,771 Michigan/Illinois 6,472 710 11 7,193 — 29 7,222 Total $ 63,328 $ 45,696 $ 27,852 $ 136,876 $ 46,267 $ 5,894 $ 189,037 Contract Balances Under the Company’s product sales contracts, its customers are invoiced once the Company’s performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company’s product sales contracts do not give rise to material contract assets or contract liabilities. The Company had trade accounts receivable related to revenue from contracts with customers of approximately $81 million and $117 million as of March 31, 2018 , and December 31, 2017 , respectively. Performance Obligations The majority of the Company’s sales are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in ASC 606-10-50-14 exempting the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s product sales that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606-10-50-14(A) which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

Divestitures and Discontinued O

Divestitures and Discontinued Operations	3 Months Ended
	Mar. 31, 2018
Discontinued Operations [Abstract]
Divestitures and Discontinued Operations	Divestitures and Discontinued Operations Divestitures On March 29, 2018, the Company completed the sale of its interest in conventional properties located in west Texas (the “West Texas Assets Sale”). Cash proceeds received from the sale of these properties were approximately $108 million (including approximately $12 million of restricted cash released in April 2018), net of costs to sell of approximately $1 million , and the Company recognized a net gain of approximately $53 million . On February 28, 2018, the Company completed the sale of its Oklahoma waterflood and Texas Panhandle properties (the “Oklahoma and Texas Assets Sale”). Cash proceeds received from the sale of these properties were approximately $112 million (including a deposit of approximately $12 million received in 2017), net of costs to sell of approximately $1 million , and the Company recognized a net gain of approximately $48 million . The divestitures discussed above are not presented as discontinued operations because they do not represent a strategic shift that will have a major effect on the Company’s operations and financial results. The gains on these divestitures are included in “gains (losses) on sale of assets and other, net” on the condensed consolidated statement of operations. Divestitures – Subsequent Events On April 10, 2018, the Company completed the sale of its conventional properties located in New Mexico (the “New Mexico Assets Sale”) related to a definitive purchase and sale agreement entered into in March 2018 and received cash proceeds of approximately $15 million . On April 4, 2018, the Company completed the sale of its interest in properties located in the Altamont Bluebell Field in Utah (the “Altamont Bluebell Assets Sale”) related to definitive purchase and sale agreement entered into in January 2018 and received cash proceeds of approximately $129 million . The assets and liabilities associated with the Altamont Bluebell Assets Sale and the New Mexico Assets Sale are classified as “held for sale” on the condensed consolidated balance sheet at March 31, 2018 . At March 31, 2018 , the Company’s condensed consolidated balance sheet included current assets of approximately $92 million included in “assets held for sale” and current liabilities of approximately $43 million included in “liabilities held for sale” related to these transactions. In addition, the assets and liabilities associated with the Oklahoma and Texas Assets Sale were classified as “held for sale” on the condensed consolidated balance sheet at December 31, 2017 . At December 31, 2017, the Company’s condensed consolidated balance sheet included current assets of approximately $107 million included in “assets held for sale” and current liabilities of approximately $43 million included in “liabilities held for sale” related to this transaction. The following table presents carrying amounts of the assets and liabilities of the Company’s properties classified as held for sale on the condensed consolidated balance sheets: March 31, 2018 December 31, 2017 (in thousands) Assets: Oil and natural gas properties $ 89,875 $ 92,245 Other property and equipment 1,433 12,983 Other 1,184 1,735 Total assets held for sale $ 92,492 $ 106,963 Liabilities: Asset retirement obligations $ 40,037 $ 42,001 Other 2,854 1,301 Total liabilities held for sale $ 42,891 $ 43,302 Other assets primarily include inventories and other liabilities primarily include accounts payable. Discontinued Operations During 2017, the Company completed the sale of its interest in properties located in the San Joaquin Basin and the Los Angeles Basin in California. As a result of the Company’s strategic exit from California, the Company classified the results of operations and cash flows of its California properties as discontinued operations on its condensed consolidated financial statements. The following tables present summarized financial results of the Company’s California properties classified as discontinued operations on the condensed consolidated statements of operations: Successor Predecessor One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Revenues and other $ 7,125 $ 14,891 Expenses 4,409 13,758 Other income and (expenses) (717 ) (1,681 ) Income (loss) from discontinued operations before income taxes 1,999 (548 ) Income tax expense 1,931 — Income (loss) from discontinued operations, net of income taxes $ 68 $ (548 )

Oil and Natural Gas Properties

Oil and Natural Gas Properties	3 Months Ended
	Mar. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and Natural Gas Properties	Oil and Natural Gas Properties Oil and Natural Gas Capitalized Costs Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below: March 31, 2018 December 31, 2017 (in thousands) Proved properties $ 732,678 $ 904,390 Unproved properties 45,413 45,693 778,091 950,083 Less accumulated depletion and amortization (48,142 ) (49,619 ) $ 729,949 $ 900,464

Equity Method Investments

Equity Method Investments	3 Months Ended
	Mar. 31, 2018
Equity Method Investments [Abstract]
Equity Method Investments	Equity Method Investments On August 31, 2017, the Company, through certain of its subsidiaries, completed the transaction in which LINN Energy and Citizen Energy II, LLC (“Citizen”) each contributed certain upstream assets located in Oklahoma to a newly formed company, Roan Resources LLC (the contribution, the “Roan Contribution”), focused on the accelerated development of the Merge/SCOOP/STACK play. In exchange for their respective contributions, LINN Energy and Citizen each received a 50% equity interest in Roan. The Company uses the equity method of accounting for its investment in Roan. The Company’s equity earnings (losses) consists of its share of Roan’s earnings or losses and the amortization of the difference between the Company’s investment in Roan and Roan’s underlying net assets attributable to certain assets. At both March 31, 2018 , and December 31, 2017 , the Company owned 50% of Roan’s outstanding units. At March 31, 2018 , the carrying amount of the Company’s investment in Roan of approximately $483 million was less than the Company’s ownership interest in Roan’s underlying net assets by approximately $342 million . The difference is attributable to proved and unproved oil and natural gas properties and is amortized over the lives of the related assets. Such amortization is included in the equity earnings (losses) from the Company’s investment in Roan. Impairment testing on the Company’s investment in Roan is performed when events or circumstances warrant such testing and considers whether there is an inability to recover the carrying value of the investment that is other than temporary. No impairments occurred with respect to the Company’s investment in Roan for the three months ended March 31, 2018. Following is summarized statement of operations information for Roan. Summarized Roan Resources LLC Statement of Operations Information Three Months Ended March 31, 2018 (in thousands) Revenues and other $ 101,084 Expenses 57,909 Other income and (expenses) (1,799 ) Net income $ 41,376

Debt

Debt	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Debt	Debt Credit Facility On August 4, 2017, the Company entered into a credit agreement with its subsidiary Linn Energy Holdco II LLC (“Holdco II”), as borrower, Royal Bank of Canada, as administrative agent, and the lenders and agents party thereto, providing for a new senior secured reserve-based revolving loan facility (the “Credit Facility”) with $500 million in borrowing commitments and an initial borrowing base of $500 million . The maximum commitment amount was $390 million at March 31, 2018 . On April 30, 2018, the Company entered into an amendment to the Credit Facility which, among other things, modified the borrowing base and maximum borrowing commitment amount to $425 million . As of March 31, 2018 , there were no borrowings outstanding under the Credit Facility and there was approximately $343 million of available borrowing capacity (which includes a $47 million reduction for outstanding letters of credit). The maturity date is August 4, 2020. Redetermination of the borrowing base under the Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. At the Company’s election, interest on borrowings under the Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin ranging from 2.50% to 3.50% per annum or the alternate base rate (“ABR”) plus an applicable margin ranging from 1.50% to 2.50% per annum, depending on utilization of the borrowing base. Interest is generally payable in arrears quarterly for loans bearing interest based at the ABR and at the end of the applicable interest period for loans bearing interest at the LIBOR, or if such interest period is longer than three months, at the end of the three month intervals during such interest period. The Company is required to pay a commitment fee to the lenders under the Credit Facility, which accrues at a rate per annum of 0.50% on the average daily unused amount of the available revolving loan commitments of the lenders. The obligations under the Credit Facility are secured by mortgages covering approximately 85% of the total value of the proved reserves of the oil and natural gas properties of the Company and certain of its subsidiaries, along with liens on substantially all personal property of the Company and certain of its subsidiaries, and are guaranteed by the Company, Holdco and certain of Holdco II’s subsidiaries, subject to customary exceptions. Under the Credit Facility, the Company is required to maintain (i) a maximum total net debt to last twelve months EBITDA ratio of 4.0 to 1.0 , and (ii) a minimum adjusted current ratio of 1.0 to 1.0 . The Credit Facility also contains affirmative and negative covenants, including as to compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and gas engineering reports and budgets, maintenance and operation of property (including oil and gas properties), restrictions on the incurrence of liens and indebtedness, mergers, consolidations and sales of assets, paying dividends or other distributions in respect of, or repurchasing or redeeming, the Company’s capital stock, making certain investments and transactions with affiliates. The Credit Facility contains events of default and remedies customary for credit facilities of this nature. Failure to comply with the financial and other covenants in the Credit Facility would allow the lenders, subject to customary cure rights, to require immediate payment of all amounts outstanding under the Credit Facility.

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Commodity Derivatives Historically, the Company has hedged a portion of its forecasted production to reduce exposure to fluctuations in oil and natural gas prices and provide long-term cash flow predictability to manage its business. The current direct NGL hedging market is constrained in terms of price, volume, duration and number of counterparties, which limits the Company’s ability to effectively hedge its NGL production. The Company has also hedged its exposure to differentials in certain operating areas but does not currently hedge exposure to oil or natural gas differentials. The Company has historically entered into commodity hedging transactions primarily in the form of swap contracts that are designed to provide a fixed price, collars and, from time to time, put options that are designed to provide a fixed price floor with the opportunity for upside. The Company enters into these transactions with respect to a portion of its projected production or consumption to provide an economic hedge of the risk related to the future commodity prices received or paid. The Company does not enter into derivative contracts for trading purposes. The Company did not designate any of its contracts as cash flow hedges; therefore, the changes in fair value of these instruments are recorded in current earnings. See Note 9 for fair value disclosures about oil and natural gas commodity derivatives. The following table presents derivative positions for the periods indicated as of March 31, 2018 : 2018 2019 Natural gas positions: Fixed price swaps (NYMEX Henry Hub): Hedged volume (MMMBtu) 52,525 18,615 Average price ($/MMBtu) $ 3.02 $ 2.91 Oil positions: Fixed price swaps (NYMEX WTI): Hedged volume (MBbls) 413 — Average price ($/Bbl) $ 54.07 $ — Collars (NYMEX WTI): Hedged volume (MBbls) 1,375 1,825 Average floor price ($/Bbl) $ 50.00 $ 50.00 Average ceiling price ($/Bbl) $ 55.50 $ 55.50 Natural gas basis differential positions: (1) NGPL TXOK basis swaps: Hedged volume (MMMBtu) 2,750 — Hedge differential $ (0.19 ) — (1) Settle on the indicated pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price. During the three months ended March 31, 2018 , the Company entered into commodity derivative contracts consisting of natural gas basis swaps for March 2018 through December 2018 and natural gas fixed price swaps for January 2019 through December 2019. During the one month ended March 31, 2017 , the Company entered into commodity derivative contracts consisting of natural gas fixed price swaps for January 2018 through December 2019. The Company did not enter into any commodity derivative contracts during the two months ended February 28, 2017. In April 2018, in connection with the closing of the Altamont Bluebell Assets Sale, the Company canceled its oil collars for 2018 and 2019. The Company paid net cash settlements of approximately $20 million for the cancellations. The natural gas derivatives are settled based on the closing price of NYMEX Henry Hub natural gas on the last trading day for the delivery month, which occurs on the third business day preceding the delivery month, or the relevant index prices of natural gas published in Inside FERC’s Gas Market Report on the first business day of the delivery month. The oil derivatives are settled based on the average closing price of NYMEX WTI crude oil for each day of the delivery month. Balance Sheet Presentation The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed consolidated balance sheets. The following table summarizes the fair value of derivatives outstanding on a gross basis: March 31, 2018 December 31, 2017 (in thousands) Assets: Commodity derivatives $ 18,672 $ 22,589 Liabilities: Commodity derivatives $ 32,062 $ 25,443 By using derivative instruments to economically hedge exposures to changes in commodity prices, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Company, which creates credit risk. The Company’s counterparties are participants in the Credit Facility. The Credit Facility is secured by certain of the Company’s and its subsidiaries’ oil, natural gas and NGL reserves and personal property; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties. The maximum amount of loss due to credit risk that the Company would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of financial instruments, was approximately $19 million at March 31, 2018 . The Company minimizes the credit risk in derivative instruments by: (i) limiting its exposure to any single counterparty; (ii) entering into derivative instruments only with counterparties that meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity derivatives are subject to counterparty netting under agreements governing such derivatives and therefore the risk of loss due to counterparty nonperformance is somewhat mitigated. Gains and Losses on Derivatives Gains and losses on derivatives were net losses of approximately $15 million and $12 million for the three months ended March 31, 2018 , and the one month ended March 31, 2017 , respectively, and net gains of approximately $93 million for the two months ended February 28, 2017. Gains and losses on derivatives are reported on the condensed consolidated statements of operations in “gains (losses) on oil and natural gas derivatives.” The Company paid net cash settlements of approximately $4 million for the three months March 31, 2018 , received net cash payments of approximately $6 million for the one month ended March 31, 2017 , and paid net cash settlements of approximately $12 million for the two months ended February 28, 2017.

Fair Value Measurements on a Re

Fair Value Measurements on a Recurring Basis	3 Months Ended
	Mar. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements on a Recurring Basis	Fair Value Measurements on a Recurring Basis The Company accounts for its commodity derivatives at fair value (see Note 8) on a recurring basis. The Company determines the fair value of its oil and natural gas derivatives utilizing pricing models that use a variety of techniques, including market quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those instruments trade in active markets. Assumed credit risk adjustments, based on published credit ratings and public bond yield spreads, are applied to the Company’s commodity derivatives. Fair Value Hierarchy In accordance with applicable accounting standards, the Company has categorized its financial instruments into a three-level fair value hierarchy based on the priority of inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis: March 31, 2018 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 18,672 $ (10,449 ) $ 8,223 Liabilities: Commodity derivatives $ 32,062 $ (10,449 ) $ 21,613 December 31, 2017 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 22,589 $ (12,491 ) $ 10,098 Liabilities: Commodity derivatives $ 25,443 $ (12,491 ) $ 12,952 (1) Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company has the obligation to plug and abandon oil and natural gas wells and related equipment at the end of production operations. Estimated asset retirement costs are recognized as liabilities with an increase to the carrying amounts of the related long-lived assets when the obligation is incurred. The liabilities are included in “other accrued liabilities” and “asset retirement obligations and other noncurrent liabilities” on the condensed consolidated balance sheets. Accretion expense is included in “depreciation, depletion and amortization” on the condensed consolidated statements of operations. The fair value of additions to the asset retirement obligations is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plug and abandon costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors; and (iv) a credit-adjusted risk-free interest rate. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change. The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2017 $ 164,553 Liabilities added from drilling 38 Liabilities associated with assets divested (19,211 ) Liabilities associated with assets held for sale (40,042 ) Current year accretion expense 2,474 Settlements (1,473 ) Asset retirement obligations at March 31, 2018 $ 106,339

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies On May 11, 2016, the Debtors filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code in the Bankruptcy Court. The Debtors’ Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16‑60040. On January 27, 2017, the Bankruptcy Court entered the Confirmation Order. Consummation of the Plan was subject to certain conditions set forth in the Plan. On the Effective Date, all of the conditions were satisfied or waived and the Plan became effective and was implemented in accordance with its terms. The LINN Debtors Chapter 11 cases will remain pending until the final resolution of all outstanding claims. The commencement of the Chapter 11 proceedings automatically stayed certain actions against the Company, including actions to collect prepetition liabilities or to exercise control over the property of the Company’s bankruptcy estates. However, the Company is, and will continue to be until the final resolution of all claims, subject to certain contested matters and adversary proceedings stemming from the Chapter 11 proceedings. In March 2017, Wells Fargo Bank, National Association (“Wells Fargo”), the administrative agent under the Predecessor’s credit facility, filed a motion in the Bankruptcy Court seeking payment of post-petition default interest of approximately $31 million . The Company has vigorously disputed that Wells Fargo is entitled to any default interest based on the plain language of the Plan and Confirmation Order. On November 13, 2017, the Bankruptcy Court ruled that the secured lenders are not entitled to payment of post-petition default interest. That ruling was appealed by Wells Fargo and on March 29, 2018, the U.S. District Court for the Southern District of Texas affirmed the Bankruptcy Court’s ruling. The Company is not currently a party to any litigation or pending claims that it believes would have a material adverse effect on its overall business, financial position, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved. Except for in connection with its Chapter 11 proceedings, the Company made no significant payments to settle any legal, environmental or tax proceedings during the three months ended March 31, 2018 , or March 31, 2017 . The Company regularly analyzes current information and accrues for probable liabilities on the disposition of certain matters as necessary. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.

Equity

Equity	3 Months Ended
	Mar. 31, 2018
Equity [Abstract]
Equity	Equity Shares Issued and Outstanding As of March 31, 2018 , there were 76,492,933 shares of Class A common stock issued and outstanding. An additional 1,629,543 unvested restricted stock units were outstanding under the Company’s Omnibus Incentive Plan. As of March 31, 2018 , the Company’s consolidated subsidiary, Holdco, had 1,392,841 vested Class A-2 units and 1,392,840 unvested Class A-2 units, which may be converted into shares of Class A common stock pursuant to the terms of the Limited Liability Company Operating Agreement of Holdco (the “Holdco LLC Agreement”). See Note 14 for additional information related to the restricted stock units and Class A-2 units. Effective April 10, 2018, all outstanding Holdco Class A-2 units were converted into Class A common stock in accordance with the terms of the Holdco LLC Agreement. An aggregate of 2,785,681 shares of Class A common stock were issued to the respective holders and remain subject to the vesting provisions applicable to the underlying Class A-2 units. Share Repurchase Program The Company’s Board of Directors has authorized the repurchase of up to $400 million of the Company’s outstanding shares of Class A common stock. Any share repurchases are subject to restrictions in the Credit Facility. During the three months ended March 31, 2018 , the Company repurchased an aggregate of 897,674 shares of Class A common stock at an average price of $38.73 per share for a total cost of approximately $35 million . In April 2018, the Company purchased 194,083 shares of Class A common stock at an average price of $38.80 for a total cost of approximately $8 million . At April 30, 2018, approximately $159 million was available for share repurchases under the program. Tender Offer On December 14, 2017, the Company’s Board of Directors announced the intention to commence a tender offer to purchase at least $250 million of the Company’s Class A common stock. In January 2018, upon the terms and subject to the conditions described in the Offer to Purchase dated December 20, 2017, as amended, the Company repurchased an aggregate of 6,770,833 shares of Class A common stock at a fixed price of $48.00 per share for a total cost of approximately $325 million (excluding expenses of approximately $4 million related to the tender offer). Dividends The Company is not currently paying a cash dividend; however, the Board of Directors periodically reviews the Company’s liquidity position to evaluate whether or not to pay a cash dividend. Any future payment of cash dividends would be subject to the restrictions in the Credit Facility.

Noncontrolling Interests

Noncontrolling Interests	3 Months Ended
	Mar. 31, 2018
Noncontrolling Interests [Abstract]
Noncontrolling Interest Disclosure	Noncontrolling Interests Noncontrolling interests represent ownership in the net assets of the Company’s consolidated subsidiary, Holdco, not attributable to LINN Energy. On the Effective Date, Holdco granted incentive interest awards to certain members of its management in the form of Class B units (see Note 14). In accordance with the terms of the Holdco LLC Agreement, on July 31, 2017, all of the Class B units were converted to Class A-2 units of Holdco. At March 31, 2018 , and December 31, 2017 , the noncontrolling Class A-2 units represented approximately 1.76% and 0.88% , respectively, of Holdco’s total outstanding units. Effective April 10, 2018, all outstanding Holdco Class A-2 units were converted into Class A common stock in accordance with the terms of the Holdco LLC Agreement.

Share-Based Compensation

Share-Based Compensation	3 Months Ended
	Mar. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation A summary of share-based compensation expenses included on the condensed consolidated statements of operations is presented below: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) General and administrative expenses $ 17,037 $ 4,177 $ 50,255 Income tax benefit $ 2,417 $ 427 $ 5,170 During the three months ended March 31, 2018 , the Company granted to certain employees 12,500 restricted stock units with an aggregate grant date fair value of approximately $519,000 . The restricted stock units vest over three years. As of April 30, 2018, 1,527,943 shares were issuable under the Omnibus Incentive Plan pursuant to outstanding restricted stock units and approximately 4.2 million additional shares were reserved for future issuance under the Plan. The Compensation Committee of the Board of Directors of the Company (the “Compensation Committee”) generally has discretion regarding the timing, size and terms of future awards; however, the Omnibus Incentive Plan requires that 1) the portion of the Share Reserve that does not constitute the Emergence Awards, plus any subsequent awards forfeited before vesting (the “Remaining Share Reserve”), will be fully granted within the 36-month period immediately following the Effective Date (with such 36-month anniversary, the “Final Allocation Date”) and 2) if a Change in Control (as defined in the Omnibus Incentive Plan) occurs before the Final Allocation Date, the entire Remaining Share Reserve will be allocated on a fully-vested basis to actively employed employees (pro-rata based upon each such employee’s relative awards) upon the consummation of the Change in Control. As of April 30, 2018, all current participants in the Omnibus Incentive Plan have agreed to waive any rights they may have to future awards under this provision in consideration for the ability to participate in the Liquidity Program described below or a similar future program. The Compensation Committee has indicated that it does not intend to grant any future awards under the Omnibus Incentive Plan. Upon a participant’s termination of employment and/or service (as applicable), the Company has the right (but not the obligation) to repurchase all or any portion of the shares of Class A common stock acquired pursuant to an award at a price equal to the fair market value (as determined under the Omnibus Incentive Plan) of the shares of Class A common stock to be repurchased, measured as of the date of the Company’s repurchase notice. In addition, in January 2018, the Compensation Committee approved a one-time liquidity program under which the Company agreed to 1) settle all or a portion of an eligible participant’s restricted stock units vesting on or before March 1, 2018 in cash and/or 2) repurchase all or a portion of any shares of Class A common stock held by an eligible participant as a result of a prior vesting of restricted stock units, in each case at an agreed upon price (the “Liquidity Program”). For the three months ended March 31, 2018 , the Company settled 909,990 restricted stock units in cash and repurchased 120,829 shares of Class A common stock for approximately $40 million pursuant to the Liquidity Program.

Earnings Per Share_Unit

Earnings Per Share/Unit	3 Months Ended
	Mar. 31, 2018
Earnings Per Share [Abstract]
Earnings Per Share/Unit	Earnings Per Share/Unit Basic earnings per share/unit is computed by dividing net earnings attributable to common stockholders/unitholders by the weighted average number of shares/units outstanding during the period. Diluted earnings per share/unit is computed by adjusting the average number of shares/units outstanding for the dilutive effect, if any, of potential common shares/units. The following tables provide a reconciliation of the numerators and denominators of the basic and diluted per share/unit computations for net income (loss): Successor Three Months Ended March 31, 2018 Income Shares Per Share (in thousands, except per share data) Basic: Net income attributable to common stockholders $ 69,824 78,975 $ 0.88 Effect of Dilutive Securities: Dilutive effect of restricted stock units $ — 1,357 Dilutive effect of unvested Class A-2 units of Holdco $ (653 ) — Diluted: Net income attributable to common stockholders $ 69,171 80,332 $ 0.86 Successor One Month Ended March 31, 2017 Income (Loss) Shares Per Share (in thousands, except per share data) Basic and Diluted: Loss from continuing operations $ (7,324 ) 89,848 $ (0.08 ) Income from discontinued operations, net of income taxes 68 89,848 — Net loss attributable to common stockholders $ (7,256 ) 89,848 $ (0.08 ) Predecessor Two Months Ended February 28, 2017 Income (Loss) Units Per Unit (in thousands, except per unit data) Basic and Diluted: Income from continuing operations $ 2,397,609 352,792 $ 6.80 Loss from discontinued operations, net of income taxes (548 ) 352,792 (0.01 ) Net income attributable to common unitholders $ 2,397,061 352,792 $ 6.79 The diluted earnings per share calculation excludes approximately 9,000 restricted stock units that were anti-dilutive for the three months ended March 31, 2018 . The diluted earnings per share calculation excludes approximately 2 million restricted stock units and approximately 3 million Class B units that were anti-dilutive for the one month ended March 31, 2017 . There were no potential common units outstanding during the two months ended February 28, 2017.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Amounts recognized as income taxes are included in “income tax expense (benefit),” as well as discontinued operations, on the consolidated statements of operations. The effective income tax rates were approximately 36% , 42% and zero for the three months ended March 31, 2018 , the one month ended March 31, 2017 , and the two months ended February 28, 2017, respectively. For the three months ended March 31, 2018 , the Company’s federal and state statutory rate net of the federal tax benefit was approximately 24% compared to an effective tax rate of approximately 36% . The increase in the effective tax rate is primarily due to non-deductible executive compensation. The Successor was formed as a C corporation. For federal and state income tax purposes (with the exception of the state of Texas), the Predecessor was a limited liability company treated as a partnership, in which income tax liabilities and/or benefits were passed through to the Predecessor’s unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Predecessor’s subsidiaries were C corporations subject to federal and state income taxes. As such, with the exception of the state of Texas and certain subsidiaries, the Predecessor did not directly pay federal and state income taxes and recognition was not given to federal and state income taxes for the operations of the Predecessor. The deferred tax effects of the Company’s change to a C corporation are included in income from continuing operations for the two months ended February 28, 2017.

Supplemental Disclosures to the

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	3 Months Ended
	Mar. 31, 2018
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows [Abstract]
Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows “Other current assets” reported on the condensed consolidated balance sheets include the following: March 31, 2018 December 31, 2017 (in thousands) Prepaids $ 39,101 $ 46,238 Receivable from related party 17,355 23,163 Inventories 6,078 7,667 Other 2,679 2,703 Other current assets $ 65,213 $ 79,771 “Other accrued liabilities” reported on the condensed consolidated balance sheets include the following: March 31, 2018 December 31, 2017 (in thousands) Accrued compensation $ 13,346 $ 29,089 Asset retirement obligations (current portion) 1,609 3,926 Deposits 20,868 15,349 Income taxes payable 221 7,496 Other 2,904 2,757 Other accrued liabilities $ 38,948 $ 58,617 The following table provides a reconciliation of cash and cash equivalents on the condensed consolidated balance sheets to cash, cash equivalents and restricted cash on the condensed consolidated statements of cash flows: March 31, 2018 December 31, 2017 (in thousands) Cash and cash equivalents $ 227,196 $ 464,508 Restricted cash 77,263 56,445 Cash, cash equivalents and restricted cash $ 304,459 $ 520,953 Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Cash payments for interest, net of amounts capitalized $ — $ 1,458 $ 17,651 Cash payments for income taxes $ 7,748 $ — $ — Cash payments for reorganization items, net $ 1,184 $ 1,286 $ 21,571 Noncash investing activities: Accrued capital expenditures $ 34,377 $ 18,670 $ 22,191 For purposes of the condensed consolidated statements of cash flows, the Company considers all highly liquid short-term investments with original maturities of three months or less to be cash equivalents. At March 31, 2018 , “restricted cash” on the condensed consolidated balance sheet consisted of approximately $35 million that will be used to settle certain claims in accordance with the Plan (which is the remainder of approximately $80 million transferred to restricted cash in February 2017 to fund such items), approximately $31 million related to deposits and approximately $11 million for other items. At December 31, 2017 , “restricted cash” on the condensed consolidated balance sheet consisted of approximately $36 million that will be used to settle certain claims in accordance with the Plan, approximately $15 million related to deposits and approximately $5 million for other items.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related Party Transactions Roan Resources LLC On August 31, 2017, the Company completed the Roan Contribution. In exchange for their respective contributions, LINN Energy and Citizen each received a 50% equity interest in Roan. See Note 6 for additional information. Also on such date, Roan entered into a Master Services Agreement (the “MSA”) with Linn Operating, LLC (“Linn Operating”), a subsidiary of LINN Energy, pursuant to which Linn Operating agreed to provide certain operating, administrative and other services in respect of the assets contributed to Roan during a transitional period. Under the MSA, Roan agreed to reimburse Linn Operating for certain costs and expenses incurred by Linn Operating in connection with providing the services, and to pay to Linn Operating a service fee of $1.25 million per month, prorated for partial months. The MSA terminated according to its terms on April 30, 2018. In addition, the Company’s subsidiary, Blue Mountain Midstream LLC, has an agreement in place with Roan for the processing of natural gas from certain of Roan’s properties. For the three months ended March 31, 2018 , the Company recognized service fees of approximately $4 million as a reduction to general and administrative expenses. At March 31, 2018 , the Company had approximately $17 million due from Roan, primarily associated with capital spending, included in “other current assets” and approximately $11 million due to Roan, primarily associated with joint interest billings and natural gas purchases, included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet. At December 31, 2017 , the Company had approximately $23 million due from Roan, primarily associated with capital spending, included in “other current assets” and approximately $18 million due to Roan, primarily associated with joint interest billings and natural gas purchases, included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet. Berry Petroleum Company, LLC Berry, a former subsidiary of the Predecessor, was deconsolidated effective December 31, 2016 . The employees of Linn Operating, Inc. (“LOI”), a subsidiary of the Predecessor, provided services and support to Berry in accordance with an agency agreement and power of attorney between Berry and LOI. Upon deconsolidation, transactions between the Predecessor and Berry were no longer eliminated in consolidation and were treated as related party transactions. These transactions include, but are not limited to, management fees paid to the Company by Berry. On the Effective Date, Berry emerged from bankruptcy as a stand-alone, unaffiliated entity. For the two months ended February 28, 2017, Berry incurred management fees of approximately $6 million for services provided by LOI. LinnCo, LLC LinnCo, which was an affiliate of the Predecessor, was formed on April 30, 2012. The Predecessor had agreed to provide to LinnCo, or to pay on LinnCo’s behalf, any financial, legal, accounting, tax advisory, financial advisory and engineering fees, and other administrative and out-of-pocket expenses incurred by LinnCo, along with any other expenses incurred in connection with any public offering of shares in LinnCo or incurred as a result of being a publicly traded entity. These expenses include costs associated with annual, quarterly and other reports to holders of LinnCo shares, tax return and Form 1099 preparation and distribution, NASDAQ listing fees, printing costs, independent auditor fees and expenses, legal counsel fees and expenses, limited liability company governance and compliance expenses and registrar and transfer agent fees. In addition, the Predecessor had agreed to indemnify LinnCo and its officers and directors for damages suffered or costs incurred (other than income taxes payable by LinnCo) in connection with carrying out LinnCo’s activities. All expenses and costs paid by the Predecessor on LinnCo’s behalf were expensed by the Predecessor. For the two months ended February 28, 2017, LinnCo incurred total general and administrative expenses of approximately $287,000 , including approximately $240,000 related to services provided by the Predecessor. All of the expenses incurred during the two months ended February 28, 2017, had been paid by the Predecessor on LinnCo’s behalf as of February 28, 2017.

Basis of Presentation (Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business LINN Energy is an independent oil and natural gas company that was formed in February 2017, in connection with the reorganization of the Predecessor. The Predecessor was publicly traded from January 2006 to February 2017. As discussed further in Note 2, on May 11, 2016 (the “Petition Date”), Linn Energy, LLC, certain of its direct and indirect subsidiaries, and LinnCo (collectively, the “LINN Debtors”) and Berry (collectively with the LINN Debtors, the “Debtors”), filed voluntary petitions (“Bankruptcy Petitions”) for relief under Chapter 11 of the U.S. Bankruptcy Code (“Bankruptcy Code”) in the U.S. Bankruptcy Court for the Southern District of Texas (“Bankruptcy Court”). The Debtors’ Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16-60040. During the pendency of the Chapter 11 proceedings, the Debtors operated their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code. The Company emerged from bankruptcy effective February 28, 2017. The Company’s properties are currently located in six operating regions in the United States (“U.S.”): the Hugoton Basin, East Texas, North Louisiana, Michigan/Illinois, the Rockies and the Mid-Continent
Principles of Consolidation and Reporting	Principles of Consolidation and Reporting The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 . The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year. The condensed consolidated financial statements include the accounts of the Company and its subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Noncontrolling interests represent ownership in the net assets of the Company’s consolidated subsidiary, Linn Energy Holdco LLC (“Holdco”), not attributable to LINN Energy, and are presented as a component of equity. Changes in the Company’s ownership interests in Holdco that do not result in deconsolidation are recognized in equity. See Note 13 for additional information about noncontrolling interests. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. See Note 6 for additional information about equity method investments. The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. The Company has also classified the results of operations and cash flows of its California properties as discontinued operations on its condensed consolidated financial statements. Such reclassifications have no impact on previously reported net income (loss) or stockholders equity. See Note 4 for additional information. As a result of the adoption of ASU 2016-18 and the inclusion of restricted cash in the statements of cash flows, previously reported net cash provided by operating activities has been updated to conform to current presentation. See recently adopted accounting standards below for additional information.
Use of Estimates	Use of Estimates The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, and fair values of commodity derivatives. In addition, as part of fresh start accounting, the Company made estimates and assumptions related to its reorganization value, liabilities subject to compromise, the fair value of assets and liabilities recorded as a result of the adoption of fresh start accounting and income taxes. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
Recently Issued Accounting Standards	Recently Adopted Accounting Standards In November 2016, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to address diversity in the classification and presentation of changes in restricted cash on the statement of cash flows. The Company adopted this ASU on January 1, 2018, on a retrospective basis. The adoption of this ASU resulted in the inclusion of restricted cash in the beginning and ending balances of cash on the statements of cash flows and disclosure reconciling cash and cash equivalents presented on the balance sheets to cash, cash equivalents and restricted cash on the statement of cash flows (see Note 17). In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers (“ASC 606”). The Company adopted this ASU on January 1, 2018, using the modified retrospective transition method. Accordingly, the comparative information for the three months ended March 31, 2017 , has not been adjusted and continues to be reported under the previous revenue standard. The adoption of this ASU impacted the Company’s gross revenues and expenses as reported on its condensed consolidated statements of operations (see below), and resulted in increased disclosures regarding the Company’s disaggregation of revenue (see Note 3). Under ASC 606, the Company recognizes revenues based on a determination of when control of its commodities is transferred and whether it is acting as a principal or agent in certain transactions. All facts and circumstances of an arrangement are considered and judgment is often required in making this determination. For its natural gas contracts, the Company generally records its sales at the wellhead or inlet of the plant as revenues net of transportation, gathering and processing expenses if the processor is the customer and there is no redelivery of commodities to the Company. Conversely, the Company generally records its sales at the tailgate of the plant on a gross basis along with the associated transportation, gathering and processing expenses if the processor is a service provider and there is redelivery of commodities to the Company. In addition, the Company recognizes revenues for commodities received as noncash consideration in exchange for services provided by its midstream operations and revenues and associated cost of product for the subsequent sale of those same commodities. This recognition results in an increase to revenues and expenses with no material impact on net income. The items discussed above impacted the Company’s reported “oil, natural gas and natural gas liquids sales,” “marketing revenues,” “transportation expenses” and “marketing expenses.” The impact of adoption on the Company’s current period results is as follows: Three Months Ended March 31, 2018 Under ASC 606 Under Prior Rule Increase/ (Decrease) (in thousands) Revenues: Natural gas sales $ 63,328 $ 64,509 $ (1,181 ) Oil sales 45,696 45,696 — NGL sales 27,852 27,942 (90 ) Total oil, natural gas and NGL sales 136,876 138,147 (1,271 ) Marketing revenues 46,267 28,115 18,152 Other revenues 5,894 5,673 221 189,037 171,935 17,102 Expenses: Transportation expenses 19,094 20,365 (1,271 ) Marketing expenses 41,755 23,603 18,152 Net income $ 71,098 $ 70,877 $ 221 New Accounting Standards Issued But Not Yet Adopted In February 2016, the FASB issued an ASU that is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2018, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its financial statements and related disclosures. The Company expects the adoption of this ASU to impact its balance sheets resulting from an increase in both assets and liabilities related to the Company’s leasing activities.

Basis of Presentation (Tables)

Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The impact of adoption on the Company’s current period results is as follows: Three Months Ended March 31, 2018 Under ASC 606 Under Prior Rule Increase/ (Decrease) (in thousands) Revenues: Natural gas sales $ 63,328 $ 64,509 $ (1,181 ) Oil sales 45,696 45,696 — NGL sales 27,852 27,942 (90 ) Total oil, natural gas and NGL sales 136,876 138,147 (1,271 ) Marketing revenues 46,267 28,115 18,152 Other revenues 5,894 5,673 221 189,037 171,935 17,102 Expenses: Transportation expenses 19,094 20,365 (1,271 ) Marketing expenses 41,755 23,603 18,152 Net income $ 71,098 $ 70,877 $ 221

Emergence From Voluntary Reor27

Emergence From Voluntary Reorganization Under Chapter 11 and Fresh Start Accounting (Tables)	3 Months Ended
	Mar. 31, 2018
Emergence From Voluntary Reorganization Under Chapter 11 [Abstract]
Schedule of Reorganization Items	The following table summarizes the components of reorganization items included on the condensed consolidated statements of operations: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Gain on settlement of liabilities subject to compromise $ — $ — $ 3,724,750 Recognition of an additional claim for the Predecessor’s second lien notes settlement — — (1,000,000 ) Fresh start valuation adjustments — — (591,525 ) Income tax benefit related to implementation of the Plan — — 264,889 Legal and other professional fees (1,952 ) (2,570 ) (46,961 ) Terminated contracts — — (6,915 ) Other 1 5 (13,049 ) Reorganization items, net $ (1,951 ) $ (2,565 ) $ 2,331,189

Revenues (Tables)

Revenues (Tables)	3 Months Ended
	Mar. 31, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	The following tables present the Company’s disaggregated revenues by source and geographic area: Successor Three Months Ended March 31, 2018 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 22,363 $ 2,732 $ 19,514 $ 44,609 $ 24,080 $ 5,831 $ 74,520 Mid-Continent 7,933 11,867 3,054 22,854 21,892 14 44,760 Permian Basin 2,026 20,108 3,045 25,179 — 16 25,195 East Texas 14,776 1,340 1,306 17,422 36 5 17,463 Rockies 3,380 7,370 1,358 12,108 — (2 ) 12,106 North Louisiana 6,378 1,569 (436 ) 7,511 259 1 7,771 Michigan/Illinois 6,472 710 11 7,193 — 29 7,222 Total $ 63,328 $ 45,696 $ 27,852 $ 136,876 $ 46,267 $ 5,894 $ 189,037

Divestitures and Discontinued29

Divestitures and Discontinued Operations (Tables)	3 Months Ended
	Mar. 31, 2018
Discontinued Operations [Abstract]
Disclosure of Long Lived Assets Held-for-sale	The following table presents carrying amounts of the assets and liabilities of the Company’s properties classified as held for sale on the condensed consolidated balance sheets: March 31, 2018 December 31, 2017 (in thousands) Assets: Oil and natural gas properties $ 89,875 $ 92,245 Other property and equipment 1,433 12,983 Other 1,184 1,735 Total assets held for sale $ 92,492 $ 106,963 Liabilities: Asset retirement obligations $ 40,037 $ 42,001 Other 2,854 1,301 Total liabilities held for sale $ 42,891 $ 43,302 Other assets primarily include inventories and other liabilities primarily include accounts payable.
Summarized statements of operations	The following tables present summarized financial results of the Company’s California properties classified as discontinued operations on the condensed consolidated statements of operations: Successor Predecessor One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Revenues and other $ 7,125 $ 14,891 Expenses 4,409 13,758 Other income and (expenses) (717 ) (1,681 ) Income (loss) from discontinued operations before income taxes 1,999 (548 ) Income tax expense 1,931 — Income (loss) from discontinued operations, net of income taxes $ 68 $ (548 )

Oil and Natural Gas Properties

Oil and Natural Gas Properties (Tables)	3 Months Ended
	Mar. 31, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below: March 31, 2018 December 31, 2017 (in thousands) Proved properties $ 732,678 $ 904,390 Unproved properties 45,413 45,693 778,091 950,083 Less accumulated depletion and amortization (48,142 ) (49,619 ) $ 729,949 $ 900,464

Equity Method Investments (Tabl

Equity Method Investments (Tables)	3 Months Ended
	Mar. 31, 2018
Equity Method Investments [Abstract]
Summarized Roan Resources LLC statement of operations information	Following is summarized statement of operations information for Roan. Summarized Roan Resources LLC Statement of Operations Information Three Months Ended March 31, 2018 (in thousands) Revenues and other $ 101,084 Expenses 57,909 Other income and (expenses) (1,799 ) Net income $ 41,376

Derivatives (Tables)

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following table presents derivative positions for the periods indicated as of March 31, 2018 : 2018 2019 Natural gas positions: Fixed price swaps (NYMEX Henry Hub): Hedged volume (MMMBtu) 52,525 18,615 Average price ($/MMBtu) $ 3.02 $ 2.91 Oil positions: Fixed price swaps (NYMEX WTI): Hedged volume (MBbls) 413 — Average price ($/Bbl) $ 54.07 $ — Collars (NYMEX WTI): Hedged volume (MBbls) 1,375 1,825 Average floor price ($/Bbl) $ 50.00 $ 50.00 Average ceiling price ($/Bbl) $ 55.50 $ 55.50 Natural gas basis differential positions: (1) NGPL TXOK basis swaps: Hedged volume (MMMBtu) 2,750 — Hedge differential $ (0.19 ) — (1) Settle on the indicated pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
Fair Value of Derivatives Outstanding on a Gross Basis by Location on the Balance Sheets	The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed consolidated balance sheets. The following table summarizes the fair value of derivatives outstanding on a gross basis: March 31, 2018 December 31, 2017 (in thousands) Assets: Commodity derivatives $ 18,672 $ 22,589 Liabilities: Commodity derivatives $ 32,062 $ 25,443

Fair Value Measurements on a 33

Fair Value Measurements on a Recurring Basis (Tables)	3 Months Ended
	Mar. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements, Recurring Basis	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis: March 31, 2018 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 18,672 $ (10,449 ) $ 8,223 Liabilities: Commodity derivatives $ 32,062 $ (10,449 ) $ 21,613 December 31, 2017 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 22,589 $ (12,491 ) $ 10,098 Liabilities: Commodity derivatives $ 25,443 $ (12,491 ) $ 12,952 (1) Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations Reconciliation	The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2017 $ 164,553 Liabilities added from drilling 38 Liabilities associated with assets divested (19,211 ) Liabilities associated with assets held for sale (40,042 ) Current year accretion expense 2,474 Settlements (1,473 ) Asset retirement obligations at March 31, 2018 $ 106,339

Share-Based Compensation (Table

Share-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share/Unit-Based Compensation	A summary of share-based compensation expenses included on the condensed consolidated statements of operations is presented below: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) General and administrative expenses $ 17,037 $ 4,177 $ 50,255 Income tax benefit $ 2,417 $ 427 $ 5,170

Earnings Per Share_Unit (Tables

Earnings Per Share/Unit (Tables)	3 Months Ended
	Mar. 31, 2018
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following tables provide a reconciliation of the numerators and denominators of the basic and diluted per share/unit computations for net income (loss): Successor Three Months Ended March 31, 2018 Income Shares Per Share (in thousands, except per share data) Basic: Net income attributable to common stockholders $ 69,824 78,975 $ 0.88 Effect of Dilutive Securities: Dilutive effect of restricted stock units $ — 1,357 Dilutive effect of unvested Class A-2 units of Holdco $ (653 ) — Diluted: Net income attributable to common stockholders $ 69,171 80,332 $ 0.86 Successor One Month Ended March 31, 2017 Income (Loss) Shares Per Share (in thousands, except per share data) Basic and Diluted: Loss from continuing operations $ (7,324 ) 89,848 $ (0.08 ) Income from discontinued operations, net of income taxes 68 89,848 — Net loss attributable to common stockholders $ (7,256 ) 89,848 $ (0.08 ) Predecessor Two Months Ended February 28, 2017 Income (Loss) Units Per Unit (in thousands, except per unit data) Basic and Diluted: Income from continuing operations $ 2,397,609 352,792 $ 6.80 Loss from discontinued operations, net of income taxes (548 ) 352,792 (0.01 ) Net income attributable to common unitholders $ 2,397,061 352,792 $ 6.79

Supplemental Disclosures to t37

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Tables)	3 Months Ended
	Mar. 31, 2018
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows [Abstract]
Other Current Assets	“Other current assets” reported on the condensed consolidated balance sheets include the following: March 31, 2018 December 31, 2017 (in thousands) Prepaids $ 39,101 $ 46,238 Receivable from related party 17,355 23,163 Inventories 6,078 7,667 Other 2,679 2,703 Other current assets $ 65,213 $ 79,771
Other Current Liabilities	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following: March 31, 2018 December 31, 2017 (in thousands) Accrued compensation $ 13,346 $ 29,089 Asset retirement obligations (current portion) 1,609 3,926 Deposits 20,868 15,349 Income taxes payable 221 7,496 Other 2,904 2,757 Other accrued liabilities $ 38,948 $ 58,617
Reconciliation of cash, cash equivalents and restricted cash	The following table provides a reconciliation of cash and cash equivalents on the condensed consolidated balance sheets to cash, cash equivalents and restricted cash on the condensed consolidated statements of cash flows: March 31, 2018 December 31, 2017 (in thousands) Cash and cash equivalents $ 227,196 $ 464,508 Restricted cash 77,263 56,445 Cash, cash equivalents and restricted cash $ 304,459 $ 520,953
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Successor Predecessor Three Months Ended March 31, 2018 One Month Ended March 31, 2017 Two Months Ended February 28, 2017 (in thousands) Cash payments for interest, net of amounts capitalized $ — $ 1,458 $ 17,651 Cash payments for income taxes $ 7,748 $ — $ — Cash payments for reorganization items, net $ 1,184 $ 1,286 $ 21,571 Noncash investing activities: Accrued capital expenditures $ 34,377 $ 18,670 $ 22,191

Basis of Presentation Details (

Basis of Presentation Details (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2018
Item Effected [Line Items]
Net income		$ 71,098
Successor
Item Effected [Line Items]
Natural Gas		63,328
Oil		45,696
NGL		27,852
Oil, natural gas and natural gas liquids sales	$ 80,325	136,876
Gains (losses) on oil and natural gas derivatives	(11,959)	(15,030)
Marketing revenues	2,914	46,267
Other revenues	2,028	5,894
Revenues		189,037
Transportation expenses	13,723	19,094
Marketing expenses	2,539	41,755
Net income	$ (7,256)	71,098
Accounting Standards Update 2014-09 [Member] | Successor
Item Effected [Line Items]
Natural Gas		(1,181)
Oil		0
NGL		(90)
Oil, natural gas and natural gas liquids sales		(1,271)
Marketing revenues		18,152
Other revenues		221
Revenues		17,102
Transportation expenses		(1,271)
Marketing expenses		18,152
Net income		221
ASC 606 [Member] | Successor
Item Effected [Line Items]
Natural Gas		63,328
Oil		45,696
NGL		27,852
Oil, natural gas and natural gas liquids sales		136,876
Marketing revenues		46,267
Other revenues		5,894
Revenues		189,037
Transportation expenses		19,094
Marketing expenses		41,755
Net income		71,098
ASC 605 [Member] | Successor
Item Effected [Line Items]
Natural Gas		64,509
Oil		45,696
NGL		27,942
Oil, natural gas and natural gas liquids sales		138,147
Marketing revenues		28,115
Other revenues		5,673
Revenues		171,935
Transportation expenses		20,365
Marketing expenses		23,603
Net income		$ 70,877

Emergence From Voluntary Reor39

Emergence From Voluntary Reorganization Under Chapter 11 and Fresh Start Accounting Reorganization (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Predecessor
Reorganization Items
Gain on settlement of liabilities subject to compromise		$ 3,724,750
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement		(1,000,000)
Fresh start valuation adjustments		(591,525)
Income tax benefit related to implementation of the Plan		264,889
Legal and other professional advisory fees		(46,961)
Terminated contracts		(6,915)
Other		(13,049)
Total reorganization items, net		$ 2,331,189
Successor
Reorganization Items
Gain on settlement of liabilities subject to compromise	$ 0		$ 0
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement	0		0
Fresh start valuation adjustments	0		0
Income tax benefit related to implementation of the Plan	0		0
Legal and other professional advisory fees	(2,570)		(1,952)
Terminated contracts	0		0
Other	5		1
Total reorganization items, net	$ (2,565)		$ (1,951)

Revenues (Details)

Revenues (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Revenue from Contract with Customer [Abstract]
Contract with Customer, Accounts Receivable	$ 81	$ 117

Revenues Disaggregated revenues

Revenues Disaggregated revenues (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Successor
Disaggregation of Revenue [Line Items]
Natural Gas			$ 63,328
Oil			45,696
NGL			27,852
Oil, natural gas and natural gas liquids sales	$ 80,325		136,876
Marketing revenues	2,914		46,267
Other revenues	$ 2,028		5,894
Total			189,037
Successor | Hugoton Basin
Disaggregation of Revenue [Line Items]
Natural Gas			22,363
Oil			2,732
NGL			19,514
Oil, natural gas and natural gas liquids sales			44,609
Marketing revenues			24,080
Other revenues			5,831
Total			74,520
Successor | Mid-Continent
Disaggregation of Revenue [Line Items]
Natural Gas			7,933
Oil			11,867
NGL			3,054
Oil, natural gas and natural gas liquids sales			22,854
Marketing revenues			21,892
Other revenues			14
Total			44,760
Successor | Permian Basin
Disaggregation of Revenue [Line Items]
Natural Gas			2,026
Oil			20,108
NGL			3,045
Oil, natural gas and natural gas liquids sales			25,179
Marketing revenues			0
Other revenues			16
Total			25,195
Successor | East Texas
Disaggregation of Revenue [Line Items]
Natural Gas			14,776
Oil			1,340
NGL			1,306
Oil, natural gas and natural gas liquids sales			17,422
Marketing revenues			36
Other revenues			5
Total			17,463
Successor | Rockies
Disaggregation of Revenue [Line Items]
Natural Gas			3,380
Oil			7,370
NGL			1,358
Oil, natural gas and natural gas liquids sales			12,108
Marketing revenues			0
Other revenues			(2)
Total			12,106
Successor | North Louisiana
Disaggregation of Revenue [Line Items]
Natural Gas			6,378
Oil			1,569
NGL			(436)
Oil, natural gas and natural gas liquids sales			7,511
Marketing revenues			259
Other revenues			1
Total			7,771
Successor | Michigan/Illinois
Disaggregation of Revenue [Line Items]
Natural Gas			6,472
Oil			710
NGL			11
Oil, natural gas and natural gas liquids sales			7,193
Marketing revenues			0
Other revenues			29
Total			$ 7,222
Predecessor
Disaggregation of Revenue [Line Items]
Oil, natural gas and natural gas liquids sales		$ 188,885
Marketing revenues		6,636
Other revenues		$ 9,915

Divestitures and Discontinued42

Divestitures and Discontinued Operations (Details) - USD ($) $ in Thousands	Jul. 31, 2017	Apr. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Jun. 30, 2017
ASSETS
Assets held for sale, oil and natural gas properties			$ 89,875	$ 92,245
Assets held for sale, property and other equipment			1,433	12,983
Assets held for sale, other assets			1,184	1,735
Assets held for sale			92,492	106,963
Liabilities [Abstract]
Liabilities held for sale, asset retirement obligations			40,037	42,001
Liabilities held for sale, other liabilities			2,854	1,301
Liabilities held for sale			42,891	43,302	$ 43,000
Deposits			20,868	15,349
West Texas Assets Sale [Member]
Liabilities [Abstract]
Proceeds from Divestiture of Businesses			108,000
Gain (Loss) on Disposition of Oil and Gas Property			53,000
West Texas Assets Sale [Member] | Subsequent Event [Member]
Liabilities [Abstract]
Deposits		$ 12,000
OK Waterfloods & TXPHS [Member]
Liabilities [Abstract]
Proceeds from Divestiture of Businesses			112,000
Deposits				$ 12,000
Costs Associated With Sale of Oil and Gas Property and Equipment	$ 1,000
Gain (Loss) on Disposition of Oil and Gas Property			$ 48,000
New Mexico Assets Sale [Member] | Subsequent Event [Member]
Liabilities [Abstract]
Proceeds from Divestiture of Businesses		15,000
Altamont Bluebell Assets Sale [Member] | Subsequent Event [Member]
Liabilities [Abstract]
Proceeds from Divestiture of Businesses		$ 129,000

Divestitures and Discontinued43

Divestitures and Discontinued Operations Discontinued summary financial information (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Successor
Discontinued operations - Income statement disclosures
Revenues and other	$ 7,125
Expenses	4,409
Other income and (expenses)	(717)
Income (loss) from discontinued operations before income taxes	1,999
Income tax expense	1,931
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	$ 68		$ 0
Predecessor
Discontinued operations - Income statement disclosures
Revenues and other		$ 14,891
Expenses		13,758
Other income and (expenses)		(1,681)
Income (loss) from discontinued operations before income taxes		(548)
Income tax expense		0
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		$ (548)

Oil and Natural Gas Propertie44

Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Proved properties	$ 732,678	$ 904,390
Unproved properties	45,413	45,693
Oil and natural gas properties (successful efforts method)	778,091	950,083
Less accumulated depletion and amortization	(48,142)	(49,619)
Oil and natural gas properties, successful efforts method, net	$ 729,949	$ 900,464

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 490,503	$ 464,926
Roan Resources LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Equity method investments	$ 483,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	$ 342,000

Equity Method Investments Summa

Equity Method Investments Summarized Roan Resources LLC Statement of Operations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Equity Method Investments [Abstract]
Revenues and other	$ 101,084
Expenses	57,909
Other income and (expenses)	(1,799)
Net income	$ 41,376

Debt (Details)

Debt (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)	Apr. 30, 2018USD ($)
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 390
Line of Credit Facility, Maximum Borrowing Capacity	500
Long-term Line of Credit	0
Line of Credit Facility, Remaining Borrowing Capacity	343
Letters of Credit Outstanding, Amount	$ 47
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.50%
Line Of Credit Facility Portion Of Properties Required To Maintain Mortgages	85.00%
Debt to EBITDAX Ratio	4
Current Ratio	1
London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.50%
ABR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.50%
ABR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.50%
Subsequent Event [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity		$ 425

Derivatives (Commodity Derivati

Derivatives (Commodity Derivatives) (Details)		1 Months Ended
		Apr. 30, 2018USD ($)	Mar. 31, 2018USD ($)MBblsMMMBTU$ / MMBTU$ / bbl
Year 2018 [Member] | Natural Gas Commodity Contract [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MMMBTU			52,525
Average price (in usd per energy unit) | $ / MMBTU			3.02
Year 2018 [Member] | Oil Commodity Contract [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls			413
Average price (in usd per energy unit)			54.07
Year 2018 [Member] | Oil Commodity Contract [Member] | Curde Oil Sales - Collars [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls			1,375
Derivative, Floor Price			50
Derivative, Cap Price			55.50
Year 2018 [Member] | Basis Swap [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MMMBTU	[1]		2,750
Hedged Differential | $	[1]		$ (0.19)
Year 2019 [Member] | Natural Gas Commodity Contract [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MMMBTU			18,615
Average price (in usd per energy unit) | $ / MMBTU			2.91
Year 2019 [Member] | Oil Commodity Contract [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls			0
Average price (in usd per energy unit)			0
Year 2019 [Member] | Oil Commodity Contract [Member] | Curde Oil Sales - Collars [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls			1,825
Derivative, Floor Price			50
Derivative, Cap Price			55.50
Year 2019 [Member] | Basis Swap [Member] | Swap [Member]
Derivative [Line Items]
Hedged Volume (in energy unit) | MMMBTU	[1]		0
Hedged Differential | $	[1]		$ 0
Subsequent Event [Member]
Derivative [Line Items]
Settlements on Canceled Derivatives | $		$ 20,000,000
[1]	Settle on the indicated pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.

Derivatives (Balance Sheet Pres

Derivatives (Balance Sheet Presentation) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Assets:
Commodity derivatives	$ 18,672	$ 22,589
Liabilities:
Commodity derivatives	32,062	$ 25,443
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 19,000

Derivatives (Gains (Losses) On

Derivatives (Gains (Losses) On Derivatives) (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure			$ 19,000
Successor
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on oil and natural gas derivatives	$ 11,959		15,030
Cash settlements on derivatives	$ 5,782		$ (4,494)
Predecessor
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on oil and natural gas derivatives		$ (92,691)
Cash settlements on derivatives		$ (11,572)

Fair Value Measurements on a 51

Fair Value Measurements on a Recurring Basis (Details) - USD ($) $ in Thousands		Mar. 31, 2018	Dec. 31, 2017
Assets:
Commodity derivatives		$ 18,672	$ 22,589
Commodity derivatives	[1]	(10,449)	(12,491)
Commodity derivatives		8,223	10,098
Liabilities:
Commodity derivatives		32,062	25,443
Commodity derivatives	[1]	(10,449)	(12,491)
Commodity derivatives		$ 21,613	$ 12,952
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at December 31, 2017	$ 164,553
Liabilities added from drilling	38
Liabilities associated with assets divested	19,211
Liabilities associated with assets held for sale	40,042
Current year accretion expense	2,474
Settlements	1,473
Asset retirement obligations at March 31, 2018	$ 106,339

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Loss Contingency, Damages Sought, Value	$ 31,000
Payments for Legal Settlements	$ 0	$ 0

Equity Equity Offering (Details

Equity Equity Offering (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		3 Months Ended
	Apr. 30, 2018	Jan. 31, 2018	Mar. 31, 2018	Dec. 31, 2017	Dec. 14, 2017	Oct. 04, 2017
Schedule of Equity Offerings [Line Items]
Common stock issued			76,492,933	83,582,176
Issuances of successor Class A common stock			649,000
Stock Repurchase Program, Authorized Amount						$ 400
Stock Repurchased During Period, Shares			897,674
Accelerated Share Repurchases, Final Price Paid Per Share			$ 38.73
Accelerated Share Repurchases, Settlement (Payment) or Receipt			$ 35
Subsequent Event [Member]
Schedule of Equity Offerings [Line Items]
Issuances of successor Class A common stock	2,785,681
Stock Repurchased During Period, Shares	194,083
Accelerated Share Repurchases, Final Price Paid Per Share	$ 38.80
Accelerated Share Repurchases, Settlement (Payment) or Receipt	$ 8
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 159
Restricted Stock Units (RSUs) [Member]
Schedule of Equity Offerings [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number			1,629,543
Restricted Stock Units (RSUs) [Member] | Subsequent Event [Member]
Schedule of Equity Offerings [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,527,943
Class A-2 Unit [Member]
Schedule of Equity Offerings [Line Items]
Vested equity awards outstanding			1,392,841
Unvested equity awards			1,392,840
Tender offer [Member]
Schedule of Equity Offerings [Line Items]
Stock Repurchase Program, Authorized Amount					$ 250
Stock Repurchased During Period, Shares		6,770,833
Accelerated Share Repurchases, Final Price Paid Per Share		$ 48
Accelerated Share Repurchases, Settlement (Payment) or Receipt		$ 325
Share tender, fees		$ 4

Noncontrolling Interests (Detai

Noncontrolling Interests (Details)	Mar. 31, 2018	Dec. 31, 2017
Noncontrolling Interests [Abstract]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	1.76%	0.88%

Share-Based Compensation (Detai

Share-Based Compensation (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Apr. 30, 2018	Mar. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Repurchased During Period, Shares		897,674
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		12,500
Stock Issued During Period, Value, Restricted Stock Award, Gross		$ 519
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number		1,629,543
Liquidity program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Repurchased During the Period, Restricted Stock Units		909,990
Employee Service Share-based Compensation, Cash Flow Effect, Cash Used to Settle Awards		$ 40,000
Stock Repurchased During Period, Shares		120,829
Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Repurchased During Period, Shares	194,083
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	4,200,000
Subsequent Event [Member] | Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,527,943

Share-Based Compensation (Compe

Share-Based Compensation (Compensation Expenses) (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Successor
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Share/unit-based compensation expenses	$ 4,177		$ 17,037
Income tax benefit	$ 427		$ 2,417
Predecessor
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Share/unit-based compensation expenses		$ 50,255
Income tax benefit		$ 5,170

Earnings Per Share_Unit (Detail

Earnings Per Share/Unit (Details) - shares shares in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Earnings Per Share, Potentially Dilutive Securities		0
Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average anti-dilutive unit equivalents excluded from computation of earnings per unit (in units)	2,000		9
Class B Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average anti-dilutive unit equivalents excluded from computation of earnings per unit (in units)	3,000

Earnings Per Share_Unit EPS Cal

Earnings Per Share/Unit EPS Calculation (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Predecessor
Basic:
Weighted average shares outstanding - basic		352,792
Net income attributable to common stockholders		$ 6.79
Diluted:
Weighted average shares outstanding - diluted		352,792
Net income attributable to common stockholders		$ 6.79
Basic and Diluted:
Loss from continuing operations		$ 2,397,609
Loss from discontinued operations, net of income taxes		(548)
Net income		$ 2,397,061
Basic and diluted weighted average units outstanding		352,792
Loss from continuing operations		$ 6.80
Loss from discontinued operations, net of income taxes		(0.01)
Net loss attributable to common unitholders		$ 6.79
Successor
Basic:
Net income attributable to common stockholders			$ 69,824
Weighted average shares outstanding - basic	89,848		78,975
Net income attributable to common stockholders	$ (0.08)		$ 0.88
Effect of Dilutive Securities:
Dilutive effect of unvested Class A-2 units of Holdco			$ (653)
Dilutive effect of restricted stock units			1,357
Diluted:
Net income attributable to common stockholders			$ 69,171
Weighted average shares outstanding - diluted	89,848		80,332
Net income attributable to common stockholders	$ (0.08)		$ 0.86
Basic and Diluted:
Loss from continuing operations	$ (7,324)
Loss from discontinued operations, net of income taxes	68		$ 0
Net income	$ (7,256)		$ 69,824
Basic and diluted weighted average units outstanding	89,848
Loss from continuing operations	$ (0.08)
Loss from discontinued operations, net of income taxes	0
Net loss attributable to common unitholders	$ (0.08)

Income Taxes Details (Details)

Income Taxes Details (Details)	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Effective Income Tax Rate Reconciliation, Percent	42.00%	0.00%	36.00%
Blended Tax Rate			24.00%

Supplemental Disclosures to t61

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Cash Flows) (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended
	Mar. 31, 2017	Feb. 28, 2017	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Schedule of supplemental cash flow disclosures [Line Items]
Cash and cash equivalents			$ 227,196	$ 464,508
Restricted cash			77,263	56,445
Cash payments for interest, net of amounts capitalized	$ 1,458	$ 17,651	0
Cash payments for income taxes	0	0	7,748
Cash payments for reorganization items, net	1,286	21,571	1,184
Noncash investing activities:
Accrued capital expenditures	18,670	22,191	34,377
Successor
Schedule of supplemental cash flow disclosures [Line Items]
Cash, cash equivalents and restricted cash	$ 90,806	144,022	304,459	520,953
Predecessor
Schedule of supplemental cash flow disclosures [Line Items]
Increase (Decrease) in Restricted Cash for Operating Activities		80,000
Cash, cash equivalents and restricted cash		$ 144,022			$ 704,234
Professional fees [Member] | Successor
Schedule of supplemental cash flow disclosures [Line Items]
Restricted cash			35,000	36,000
Deposits for divestitures [Member] | Successor
Schedule of supplemental cash flow disclosures [Line Items]
Restricted cash			31,000	15,000
Other [Member] | Successor
Schedule of supplemental cash flow disclosures [Line Items]
Restricted cash			$ 11,000	$ 5,000

Supplemental Disclosures to t62

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows Balance Sheet (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Other current assets
Prepaids	$ 39,101	$ 46,238
Receivable from related party	17,355	23,163
Inventories	6,078	7,667
Other	2,679	2,703
Other current assets	65,213	79,771
Other accrued liabilities
Accrued compensation	13,346	29,089
Asset retirement obligations (current portion)	1,609	3,926
Deposits	20,868	15,349
Income taxes payable	221	7,496
Other	2,904	2,757
Other accrued liabilities	$ 38,948	$ 58,617

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	2 Months Ended	3 Months Ended	4 Months Ended
	Feb. 28, 2017	Mar. 31, 2018	Dec. 31, 2017	Aug. 31, 2017	Dec. 31, 2016
Roan Resources LLC [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage				50.00%
Related party monthly fee		$ 1,250
Related Party Transaction, Other Revenues from Transactions with Related Party		4,000
Revenue from Related Parties		17,000	$ 23,000
Due to Related Parties, Current		$ 11,000			$ 18,000
Berry [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	$ 6,000
LinnCo [Member]
Related Party Transaction [Line Items]
General and administrative expenses	287
Related Party Transaction, Amounts of Transaction	$ 240