Riviera Resources (RVRA) 10-Q 2 Nov 20 2020 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2020	Oct. 31, 2020
Cover [Abstract]
Document Type	10-Q
Document Period End Date	Sep. 30, 2020
Amendment Flag	false
Entity Registrant Name	Riviera Resources, Inc.
Entity Central Index Key	0001737204
Current Fiscal Year End	--12-31
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		57,907,609
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Entity Current Reporting Status	Yes
Entity Shell Company	false
Entity File Number	333-225927
Entity Tax Identification Number	82-5121920
Entity Address, Address Line One	717 Texas Avenue
Entity Address, Address Line Two	Suite 2000
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	281
Local Phone Number	840-4000
Entity Interactive Data Current	Yes
Entity Incorporation, State or Country Code	DE
Document Quarterly Report	true
Document Transition Report	false

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 94,548	$ 116,237
Accounts receivable – trade, net	22,194	51,355
Derivative instruments	375	7,283
Restricted cash	24,887	32,932
Other current assets	11,925	12,853
Assets held for sale	0	104,773
Total current assets	153,929	325,433
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	125,389	180,307
Less accumulated depletion and amortization	(111,480)	(35,603)
Oil and natural gas properties, successful efforts method, net	13,909	144,704
Other property and equipment	396,449	388,851
Less accumulated depreciation	(292,416)	(50,381)
Other property and equipment, net	104,033	338,470
Other noncurrent assets	4,690	7,652
Noncurrent assets, excluding property, total	4,690	7,652
Total noncurrent assets	122,632	490,826
Total assets	276,561	816,259
Current liabilities:
Accounts payable and accrued expenses	34,907	80,579
Derivative instruments	1,795	1,087
Other accrued liabilities	31,776	26,728
Liabilities held for sale	0	35,177
Total current liabilities	68,478	143,571
Noncurrent liabilities:
Credit facilities	80,000	69,800
Asset retirement obligations and other noncurrent liabilities	16,209	29,337
Total noncurrent liabilities	96,209	99,137
Commitments and contingencies (Note 10)	0	0
Equity:
Preferred Stock ($0.01 par value, 30,000,000 shares authorized; no shares issued at September 30, 2020, or December 31, 2019)	0	0
Common Stock ($0.01 par value, 270,000,000 shares authorized; 57,907,609 shares and 58,168,756 shares issued and outstanding at September 30, 2020, and December 31, 2019, respectively)	579	581
Additional paid-in capital	759,186	861,764
Accumulated deficit	(647,891)	(288,794)
Total equity	111,874	573,551
Total liabilities and equity	$ 276,561	$ 816,259

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2020	Dec. 31, 2019
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	30,000,000	30,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	270,000,000	270,000,000
Common stock, shares, issued	57,907,609	58,168,756
Common Stock, shares, outstanding	57,907,609	58,168,756

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenues and other:
Revenues	$ 36,423	$ 102,389	$ 117,981	$ 377,385
Gains (losses) on commodity derivatives	(2,948)	5,665	3,773	12,673
Total revenues	33,475	108,054	121,754	390,058
Expenses:
Lease operating expenses	2,367	18,307	10,212	66,204
Transportation expenses	818	16,275	4,201	53,478
Marketing expenses	20,284	37,688	58,431	132,888
General and administrative expenses	16,871	16,954	37,994	49,434
Exploration costs	413	1,947	413	4,154
Depreciation, depletion and amortization	3,915	20,060	19,027	65,013
Impairment of assets held for sale and long-lived assets	219,606	95,080	341,264	113,470
Taxes, other than income taxes	846	5,111	3,436	14,010
(Gains) losses on sale of assets and other, net	3,515	(7,587)	1,484	(24,967)
Total expenses	268,635	203,835	476,462	473,684
Operating loss	(235,160)	(95,781)	(354,708)	(83,626)
Other income and (expenses):
Interest expense, net of amounts capitalized	(700)	(2,329)	(2,368)	(5,403)
Other, net	(309)	(595)	(1,317)	(708)
Total other income and (expenses)	(1,009)	(2,924)	(3,685)	(6,111)
Reorganization items, net	(210)	(284)	(704)	(756)
Loss before income taxes	(236,379)	(98,989)	(359,097)	(90,493)
Income tax expense	0	126,646	0	129,092
Net loss	$ (236,379)	$ (225,635)	$ (359,097)	$ (219,585)
Loss per share:
Basic and diluted	$ (4.07)	$ (3.76)	$ (6.18)	$ (3.40)
Weighted average shares outstanding ‒ basic and diluted	58,044	60,004	58,080	64,576
Distributions declared per share	$ 0	$ 0	$ 1.75	$ 0
Oil, Natural Gas and NGL Sales
Revenues and other:
Revenues	$ 7,340	$ 51,029	$ 33,072	$ 194,131
Marketing
Revenues and other:
Revenues	29,054	45,828	84,840	166,569
Other Revenues
Revenues and other:
Revenues	$ 29	$ 5,532	$ 69	$ 16,685

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) $ in Thousands	Total	Common Stock	Additional Paid in Capital	Accumulated Earnings (Deficit)
Beginning of period at Dec. 31, 2018	$ 1,262,374	$ 692	$ 1,256,730	$ 4,952
Beginning of period, shares at Dec. 31, 2018		69,197,000
Net income (loss)	12,726	$ 0	0	12,726
Repurchases of common stock	(34,437)	$ (25)	(34,412)	0
Repurchases of common stock, shares		(2,488,000)
Issuance of common stock	1,486	$ 1	1,485	0
Issuance of common stock, shares		82,000
Ending of period, shares at Mar. 31, 2019		66,791,000
Ending of period at Mar. 31, 2019	1,242,149	$ 668	1,223,803	17,678
Beginning of period at Dec. 31, 2018	1,262,374	$ 692	1,256,730	4,952
Beginning of period, shares at Dec. 31, 2018		69,197,000
Net income (loss)	(219,585)
Ending of period, shares at Sep. 30, 2019		58,632,000
Ending of period at Sep. 30, 2019	901,436	$ 586	1,115,483	(214,633)
Beginning of period at Mar. 31, 2019	1,242,149	$ 668	1,223,803	17,678
Beginning of period, shares at Mar. 31, 2019		66,791,000
Net income (loss)	(6,676)	$ 0	0	(6,676)
Repurchases of common stock	(43,307)	$ (32)	(43,275)	0
Repurchases of common stock, shares		(3,170,000)
Ending of period, shares at Jun. 30, 2019		63,621,000
Ending of period at Jun. 30, 2019	1,192,166	$ 636	1,180,528	11,002
Net income (loss)	(225,635)	0	0	(225,635)
Repurchases of common stock	(65,353)	$ (50)	(65,303)	0
Repurchases of common stock, shares		(4,989,000)
Other	258	$ 0	258	0
Ending of period, shares at Sep. 30, 2019		58,632,000
Ending of period at Sep. 30, 2019	901,436	$ 586	1,115,483	(214,633)
Beginning of period at Dec. 31, 2019	$ 573,551	$ 581	861,764	(288,794)
Beginning of period, shares at Dec. 31, 2019	58,168,756	58,169,000
Net income (loss)	$ (101,506)	$ 0	0	(101,506)
Repurchases of common stock	(2,066)	$ (3)	(2,063)	0
Repurchases of common stock, shares		(323,000)
Issuance of common stock	824	$ 1	823	0
Issuance of common stock, shares		62,000
Distributions to shareholders	(57,908)	$ 0	(57,908)	0
Ending of period, shares at Mar. 31, 2020		57,908,000
Ending of period at Mar. 31, 2020	412,895	$ 579	802,616	(390,300)
Beginning of period at Dec. 31, 2019	$ 573,551	$ 581	861,764	(288,794)
Beginning of period, shares at Dec. 31, 2019	58,168,756	58,169,000
Net income (loss)	$ (359,097)
Distributions to shareholders	$ (58,000)
Ending of period, shares at Sep. 30, 2020	57,907,609	57,908,000
Ending of period at Sep. 30, 2020	$ 111,874	$ 579	759,186	(647,891)
Beginning of period at Mar. 31, 2020	412,895	$ 579	802,616	(390,300)
Beginning of period, shares at Mar. 31, 2020		57,908,000
Net income (loss)	(21,212)	$ 0	0	(21,212)
Distributions to shareholders	(43,430)	$ 0	(43,430)	0
Ending of period, shares at Jun. 30, 2020		57,908,000
Ending of period at Jun. 30, 2020	348,253	$ 579	759,186	(411,512)
Net income (loss)	$ (236,379)	$ 0	0	(236,379)
Ending of period, shares at Sep. 30, 2020	57,907,609	57,908,000
Ending of period at Sep. 30, 2020	$ 111,874	$ 579	$ 759,186	$ (647,891)

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Cash flow from operating activities:
Net loss	$ (359,097)	$ (219,585)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	19,027	65,013
Impairment of assets held for sale and long-lived assets	341,264	113,470
Deferred income taxes		129,092
Gains on derivatives, net	(3,773)	(6,386)
Cash settlements on derivatives	11,389	5,740
Share-based compensation expenses	(3,381)	10,624
(Gains) losses on sale of assets and other, net	1,510	(27,366)
Other	2,602	8,897
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	23,416	37,305
Decrease in other assets	2,666	5,367
Decrease in accounts payable and accrued expenses	(34,824)	(29,997)
Decrease in other liabilities	(5,885)	(4,331)
Net cash (used in) provided by operating activities	(5,086)	87,843
Cash flow from investing activities:
Acquisition of property, plant and equipment		(3,380)
Development of oil and natural gas properties	(292)	(67,864)
Purchases of other property and equipment	(31,242)	(82,232)
Proceeds from sale of properties and equipment and other	100,677	177,907
Net cash provided by investing activities	69,143	24,431
Cash flow from financing activities:
Repurchases of shares	(2,653)	(143,097)
Proceeds from borrowings	11,200	142,825
Repayments of debt	(1,000)	(29,615)
Debt issuance costs paid		(3,246)
Distributions to shareholders	(101,338)
Net cash used in financing activities	(93,791)	(33,133)
Net (decrease) increase in cash, cash equivalents and restricted cash	(29,734)	79,141
Cash, cash equivalents and restricted cash:
Beginning	149,169	49,777
Ending	$ 119,435	$ 128,918

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2020
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Basis of Presentation	Note 1 – Basis of Presentation Unless otherwise indicated or the context otherwise requires, references herein to the “Company” refer to Riviera Resources, Inc. (“Riviera”) and its consolidated subsidiaries. Unless otherwise indicated or the context otherwise requires, references herein to “LINN Energy” refer to Linn Energy, Inc. and its consolidated subsidiaries. Nature of Business The Company is incorporated under Delaware law and its headquarters are in Houston, Texas. Prior to the recent sales of interests in oil and natural gas properties and the sale of its wholly owned subsidiary Blue Mountain Midstream LLC (“Blue Mountain Midstream”), discussed below, Riviera was an independent oil and natural gas company. The Company had two reporting segments, upstream and Blue Mountain. The upstream reporting segment was engaged in the exploration, development, production, and sale of oil, natural gas, and natural gas liquids (“NGL”) and its properties were all located in the United States (“U.S.”). The Blue Mountain reporting segment consisted of a cryogenic natural gas processing facility, a network of gathering pipelines and compressors and produced water services and a crude oil gathering system located in the Merge/SCOOP/STACK play. Recent Developments Section 271 Sale In July 2020, the Company signed definitive agreements to sell substantially all of its interests located , North Louisiana and the The Blue Mountain Divestiture, together with the sales of interests in properties located in North Louisiana and the (collectively, the “271 Sale”), constituted a sale of substantially all of the consolidated assets of the Company for purposes of Section 271(a) of the . Therefore, on August 23, 2020, the Company elected to obtain shareholder approval and authorization of the 271 Sale. Holders of a majority of the Company’s issued and outstanding shares of common stock (the “Majority Stockholders”) executed and delivered to the Company a written consent in lieu of a special meeting. The written consent delivered by the Majority Stockholders authorized and approved the 271 Sale. Plan of Liquidation On August 24, 2020, following approval of the 271 Sale, the Company announced that it was evaluating the process of winding-up and of returning the majority of its remaining capital to its shareholders. On October 12, 2020, the Board of Directors of the Company (the “Board”), approved the dissolution, winding up and liquidation of the Company (the “Plan of Liquidation”) and adopted the Plan of Liquidation. Also, on October 12, 2020, the required percentage of the Company’s shareholders approved, through written consent in accordance with the bylaws of the Company, the Plan of Liquidation Other Recent Developments The Company and the oil and gas industry have been adversely impacted by certain events, including the initial dramatic increase in output from the Organization of Petroleum Exporting Countries and other oil producing nations (“ global pandemic While OPEC+ has agreed to cut production, downward pressure on commodity prices has continued. As described further below, the Company recorded impairments on oil and natural gas properties and property, plant and equipment for the nine months ended September 30, 2020. The impairment charges recorded in the three months ended September 30, 2020, were primarily due to the Company’s exit from the midstream business. The impairment charges recorded in the first quarter and second quarter of 2020 were primarily due to declines in commodity prices and declines in expected future volumes. The COVID-19 pandemic continues to evolve and identification of all trends, events and uncertainties, including a possible widespread resurgence in COVID-19 infections in the remainder of 2020 without the availability of generally effective therapeutics or a vaccine for the disease, that may impact the Company’s financial condition and results of operations are unknown at this time. D ue to the adoption of the Plan of Liquidation, the Company’s results of operations for the three months and nine months ended September 30, 2020, are not indicative of its future results. 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 consolidated financial statements and notes in the Company’s Annual Report on Form 10‑K for the year ended December 31, 2019. 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. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. There have been no material changes in critical accounting policies during the nine months ended September 30, 2020, as compared to the critical accounting policies described in Item 8. “Financial Statements and Supplementary Data” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2019. Based on the approval of the Plan of Liquidation in October 2020, discussed above, t he Company plans to adopt the liquidation basis of accounting in the fourth quarter of 2020. 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 impairment evaluations, estimates of the Company’s reserves of oil, natural gas and 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. 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 consolidated financial statements in future periods. Fair Value of Financial Instruments The carrying values of the Company’s receivables, payables and credit facilities are estimated to be substantially the same as their fair values at September 30, 2020, and December 31, 2019. See Note 8 for details about the fair value of the Company’s derivative financial instruments. Recently Adopted Accounting Standard In June 2016, the FASB issued an ASU that is intended to change the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The Company adopted this ASU effective January 1, 2020, using the modified retrospective effective date method. The Company’s trade receivables due in one year or less represent substantially all the items that are within the scope of the new standard. The adoption of this ASU did not have a material impact on the Company’s results of operations or financial position. Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The Company maintains an allowance for doubtful accounts for estimated losses inherent in its accounts receivable portfolio. In establishing the required allowance, management considers historical losses, current receivables aging, and existing industry and national economic data. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential recovery is remote. The balance in the Company’s allowance for doubtful accounts related to trade accounts receivable was approximately $4 million and $1 million at September 30, 2020, and December 31, 2019, respectively. Impairment of Assets Held for Sale and Long-Lived Assets Proved Oil and Natural Gas Properties The Company evaluates the impairment of its proved oil and natural gas properties on a field-by-field basis whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of proved properties are reduced to fair value when the expected undiscounted future cash flows of proved and risk-adjusted probable and possible reserves are less than net book value or there are alternative indications of impairment. The fair values of proved properties are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount, or the Company takes into consideration contract prices from executed definitive agreements. Significant inputs used to determine the fair values of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. These assumptions represent Level 3 inputs. These inputs require assumptions by the Company’s management at the time of the valuation and are the most sensitive and subject to change. The underlying commodity prices embedded in the Company’s estimated cash flows are the product of a process that begins with New York Mercantile Exchange (“NYMEX”) forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Company management believes will impact realizable prices. Based on the analysis described above, during the nine months ended September 30, 2020, the Company recorded noncash impairment charges of approximately $101 million associated with proved oil and natural gas properties. Of this, approximately $85 million related to divested properties located in Oklahoma, approximately $12 million to divested properties located in North Louisiana, and approximately $4 million to divested properties located in East Texas. There was no such charge during the three months ended September 30, 2020. During the three months and nine months ended September 30, 2019, the Company recorded noncash impairment charges of approximately $95 million and $113 million, respectively, associated with divested proved oil and gas properties located in the Hugoton Basin and Michigan. The impairment charges in both periods were primarily due to a decline in commodity prices. The carrying values of the impaired proved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair value measurement. The charges are associated with the upstream reporting segment and are included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statements of operations. See Note 3 for additional information about divestitures. Unproved Oil and Natural Gas Properties The Company evaluates the impairment of its unproved oil and natural gas properties whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of unproved properties are reduced to fair value based on management’s experience in similar situations and other factors such as the lease terms of the properties and the relative proportion of such properties on which proved reserves have been found in the past. Based on the analysis described above, during the nine months ended September 30, 2020, the Company recorded a noncash impairment charge of approximately $3 million associated with unproved oil and natural gas properties located in Oklahoma. There was no such charge during the three months ended September 30, 2020. The impairment was primarily due to a decline in commodity prices. The charge is associated with the upstream reporting segment and is included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statement of operations. Other Property and Equipment and Other Assets The Company evaluates the impairment of its other property and equipment whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of other property and equipment are reduced to fair value when the expected undiscounted future cash flows are less than net book value or there are alternative indications of impairment. The fair values of other property and equipment are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount, or the Company takes into consideration contract prices from executed definitive agreements. Significant inputs used to determine the fair values of other property and equipment and other assets include estimates of future operating costs, future volumes and future commodity prices. These inputs require assumptions by the Company’s management at the time of the valuation and are the most sensitive and subject to change. At September 30, 2020, because of the Blue Mountain Divestiture, the Company performed an impairment evaluation of Blue Mountain Midstream’s other property and equipment and other assets. Based on the analysis described above, during the three months and nine months ended September 30, 2020, the Company recorded impairment charges of approximately $220 million and $237 million, respectively, to reduce the carrying value of Blue Mountain Midstream’s assets to fair value less cost to sell using Level 3 inputs. The impairment charges recorded in the three months ended September 30, 2020, were primarily triggered by the Company’s exit from the midstream business, with the fair value being predominantly driven by the contract price of the Blue Mountain Divestiture. The impairment charges recorded in the first quarter and second quarter of 2020 were primarily due to a decline in expected future volumes in the crude gathering business, related to the economics of customers drilling in the area. The charges are primarily associated with the Blue Mountain reporting segment, with $1 million of the charges associated with the upstream reporting segment and are included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statements of operations.

Revenues

Revenues	9 Months Ended
	Sep. 30, 2020
Revenue From Contract With Customer [Abstract]
Revenues	Note 2 – Revenues Disaggregation of Revenue Substantially all of the revenues reported on the Company’s unaudited condensed consolidated statements of operations included herein relates to properties that were divested either prior or subsequent to September 30, 2020. See Note 1, Note 3 and Note 18 for information about divestitures. The following tables present the Company’s disaggregated revenues by source and geographic area: Three Months Ended September 30, 2020 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Mid-Continent $ 2,140 $ 2,657 $ 645 $ 5,442 $ — $ 30 $ 5,472 East Texas (11 ) — — (11 ) — — (11 ) North Louisiana 1,675 187 53 1,915 113 — 2,028 Uinta Basin (13 ) — — (13 ) — — (13 ) Other divested properties 5 — 2 7 — (1 ) 6 Blue Mountain — — — — 28,941 — 28,941 Total $ 3,796 $ 2,844 $ 700 $ 7,340 $ 29,054 $ 29 $ 36,423 Three Months Ended September 30, 2019 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 12,057 $ 405 $ 5,561 $ 18,023 $ 9,810 $ 5,413 $ 33,246 Mid-Continent 3,870 8,387 1,171 13,428 — 78 13,506 East Texas 7,379 812 492 8,683 843 2 9,528 North Louisiana 6,849 467 141 7,457 442 2 7,901 Uinta Basin 2,845 — — 2,845 — 1 2,846 Michigan/Illinois 82 504 7 593 — 36 629 Blue Mountain — — — — 34,733 — 34,733 Total $ 33,082 $ 10,575 $ 7,372 $ 51,029 $ 45,828 $ 5,532 $ 102,389 Nine Months Ended September 30, 2020 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Mid-Continent $ 8,269 $ 10,369 $ 2,302 $ 20,940 $ — $ 87 $ 21,027 East Texas 2,510 328 444 3,282 2,282 2 5,566 North Louisiana 7,003 700 234 7,937 525 1 8,463 Uinta Basin 906 — (8 ) 898 — — 898 Other divested properties 7 27 (19 ) 15 4 (21 ) (2 ) Blue Mountain — — — — 82,029 — 82,029 Total $ 18,695 $ 11,424 $ 2,953 $ 33,072 $ 84,840 $ 69 $ 117,981 Nine Months Ended September 30, 2019 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 49,993 $ 1,198 $ 22,843 $ 74,034 $ 42,962 $ 16,485 $ 133,481 Mid-Continent 12,639 18,507 5,493 36,639 — 102 36,741 East Texas 28,228 2,609 1,500 32,337 2,740 6 35,083 North Louisiana 20,352 2,225 901 23,478 1,162 5 24,645 Uinta Basin 12,388 86 5 12,479 — 1 12,480 Michigan/Illinois 13,223 1,900 41 15,164 — 86 15,250 Blue Mountain — — — — 119,705 — 119,705 Total $ 136,823 $ 26,525 $ 30,783 $ 194,131 $ 166,569 $ 16,685 $ 377,385 Contract Balances Under the Company’s product sales contracts, 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 $16 million and $43 million as of September 30, 2020, and December 31, 2019, respectively. Performance Obligations A 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 that exempts 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 contracts, future revenue from the sale of products and services is dependent on future production or variable customer volume and variable commodity prices for that volume; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.

Divestitures

Divestitures	9 Months Ended
	Sep. 30, 2020
Discontinued Operations [Abstract]
Divestitures	Note 3 – Divestitures Divestitures – 2020 On January 15, 2020, the Company completed the sale of its interest in non-operated properties located in the Drunkards Wash field in the Uinta Basin. Cash proceeds from the sale of these properties were approximately $4 million (including a deposit of approximately $450,000 received in 2019), and the Company recorded a net gain of approximately $1 million. On January 31, 2020, the Company completed the sale of its interest in properties located in the Overton field in East Texas. Cash proceeds from the sale of these properties were approximately $17 million (including a deposit of approximately $2 million received in 2019). On February 14, 2020, the Company completed the sale of its interest in properties located in the Personville field in East Texas. Cash proceeds from the sale of these properties were approximately $28 million (including a deposit of approximately $3 million received in 2019). On February 28, 2020, the Company completed the sale of its office building located in Oklahoma City, Oklahoma. Cash proceeds from the sale were approximately $21 million. On April 2, 2020, the Company completed the sale of its remaining interest in properties located in East Texas. Cash proceeds from the sale of these properties were approximately $392,000. On September 1, 2020, the Company completed the sale of its interest in substantially all of its properties located in North Louisiana (the “North Louisiana Assets”). Cash proceeds from the sale of these properties were approximately $23 million and the Company recorded a net loss of approximately $1 million. The Company recorded a noncash impairment charge of approximately $12 million to reduce the carrying value of these assets to fair value in the second quarter of 2020. Divestitures – Subsequent Events On October 1, 2020, the Company completed the sale of its interest in substantially all of its Mid-Continent properties located in Oklahoma (the “Mid-Continent Assets”). Cash proceeds from the sale of these properties were approximately $13 million (including a deposit of approximately $2 million received in the third quarter of 2020) and the Company expects to record a net gain of approximately $16 million in the fourth quarter of 2020. See Note 18 for pro forma financial information related to divestiture of the Mid-Continent Assets. The following are summarized results of operations and balance sheet information for the Mid-Continent Assets: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ 6,558 $ 9,763 $ 18,231 $ 33,373 Expenses 3,977 8,195 104,337 25,865 Income (loss) before income taxes 2,581 1,568 (86,106 ) 7,508 Income tax expense — 24,560 — 33,275 Net income (loss) $ 2,581 $ (22,992 ) $ (86,106 ) $ (25,767 ) September 30, 2020 (in thousands) Assets: Current assets $ 7,859 Oil and natural gas properties, net 11,325 Other property and equipment, net 1,825 $ 21,009 Liabilities: Current liabilities $ 5,003 Asset retirement obligations 14,487 $ 19,490 On October 8, 2020, the Company completed the Blue Mountain Divestiture. Cash proceeds from the sale were approximately $114 million (including a deposit of approximately $11 million received in the third quarter of 2020). The Company repaid approximately $80 million, representing total borrowings under the Blue Mountain Credit Facility, as defined in Note 6, with a portion of th e The following are summarized results of operations and balance sheet information for the Blue Mountain Divestiture: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ 28,941 $ 34,407 $ 82,495 $ 119,548 Expenses 20,703 30,383 59,655 99,346 Other income (expenses) (226,737 ) (7,243 ) (254,284 ) (25,858 ) Loss before income taxes (218,499 ) (3,219 ) (231,444 ) (5,656 ) Income tax benefit — (28,204 ) — (27,775 ) Net (loss) income $ (218,499 ) $ 24,985 $ (231,444 ) $ 22,119 September 30, 2020 (in thousands) Assets: Current assets $ 21,777 Other property and equipment, net 101,683 Other noncurrent assets 3,628 $ 127,088 Liabilities: Current liabilities $ 10,227 Credit facility 80,000 Asset retirement obligations 716 Other noncurrent liabilities 936 $ 91,879 Divestitures – 2019 On November 22, 2019, the Company completed the sale of its interest in properties located in the Hugoton Basin (the “Hugoton Basin Assets Sale”). Cash proceeds from the sale of these properties were approximately $286 million. In connection with the Hugoton Basin Assets Sale, the buyer also acquired the Company’s interest in Mayzure, LLC, a wholly owned subsidiary of the Company, which was the counterparty to the volumetric production payment agreements based on On September 5, 2019, the Company completed the sale of its interest in properties located in Illinois. Cash proceeds from the sale of these properties were approximately $4 million and the Company recorded a net gain of approximately $4 million. On August 30, 2019, the Company completed the sale of its interest in non-core assets located in North Louisiana. Cash proceeds from the sale were approximately $2 million and the Company recorded a net gain of approximately $376,000. On July 3, 2019, the Company completed the sale of its interest in properties located in Michigan. Cash proceeds from the sale of these properties were approximately $39 million. The Company recorded a noncash impairment charge of approximately $18 million to reduce the carrying value of these assets to fair value. On May 31, 2019, the Company completed the sale of its interest in non-operated properties located in the Hugoton Basin in Kansas. Cash proceeds from the sale of these properties were approximately $29 million and the Company recorded a net loss of approximately $10 million. On January 17, 2019, the Company completed the sale of its interest in properties located in the Arkoma Basin in Oklahoma. Cash proceeds from the sale of these properties were approximately $64 million (including a deposit of approximately $5 million received in 2018), and the Company recorded a net gain of approximately $28 million. The Blue Mountain Divestiture and the Mid-Continent Assets are not presented as discontinued operations as of and for the period ended September 30, 2020, as the associated activity represents substantially all of the Company’s results of operations and remaining net assets. Therefore, they do not meet the definition of a component of an entity because they are not clearly distinguishable from the rest of the entity. Other divestitures of oil and natural gas properties during 2019 and 2020 are not presented as discontinued operations because they did not represent a strategic shift. The gains and losses on divestitures are included in “(gains) losses on sale of assets and other, net” on the condensed consolidated statements of operations, in the upstream reporting segment for oil and natural gas properties, and in the Blue Mountain reporting segment for the Blue Mountain Divestiture. 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 sheet: December 31, 2019 (in thousands) Assets: Oil and natural gas properties, net $ 17,732 Other property and equipment, net 85,798 Other 1,243 Total assets held for sale $ 104,773 Liabilities: Asset retirement obligations $ 33,542 Other 1,635 Total liabilities held for sale $ 35,177 Other assets primarily include inventories and other liabilities primarily include accounts payable.

Equity (Deficit)

Equity (Deficit)	9 Months Ended
	Sep. 30, 2020
Equity [Abstract]
Equity (Deficit)	Note 4 – Equity (Deficit) Share Repurchase Program On July 18, 2019, the Board authorized the repurchase of up to $150 million of the Company’s outstanding shares of common stock. During the nine months ended September 30, 2020, the Company repurchased an aggregate of 282,742 shares of common stock at an average price of $7.31 per share for a total cost of approximately $2 million. Future share repurchases are not provided for under the Company’s Plan of Liquidation. Cash Distributions On March 9, 2020, the Board declared a cash distribution of $1.00 per share. A cash distribution totaling approximately $58 million was paid on April 22, 2020, to shareholders of record as of the close of business on April 8, 2020. On April 23, 2020, the Board declared a cash distribution of $0.75 per share. The distribution totaling approximately $43 million was paid on May 11, 2020, to shareholders of record as of the close of business on May 7, 2020. In addition, approximately $1 million and $11 million for potential future distributions related to nonvested share-based compensation awards was voluntarily recorded in restricted cash at September 30, 2020, and December 31, 2019, respectively. Cash Distributions – Subsequent Event On October 12, 2020, the Board declared a cash distribution of $1.35 per share. A cash distribution totaling approximately $78 million was paid on October 28, 2020, to shareholders of record as of the close of business on October 23, 2020.

Oil and Natural Gas Properties

Oil and Natural Gas Properties	9 Months Ended
	Sep. 30, 2020
Oil And Gas Exploration And Production Industries Disclosures [Abstract]
Oil and Natural Gas Properties	Note 5 – Oil and Natural Gas Properties Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below: September 30, 2020 December 31, 2019 (in thousands) Proved properties $ 122,307 $ 174,845 Unproved properties 3,082 5,462 125,389 180,307 Less accumulated depletion and amortization (111,480 ) (35,603 ) $ 13,909 $ 144,704 As discussed in Note 1 and Note 3, substantially all of the Company’s remaining oil and natural gas properties were sold subsequent to September 30, 2020.

Debt

Debt	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Debt	Note 6 – Debt Fair Value The Company’s debt is recorded at the carrying amount on the condensed consolidated balance sheets. The carrying amounts of the credit facilities approximate fair value because the interest rates are variable and reflective of market rates. Riviera Credit Facility As of September 30, 2020, Riviera’s credit agreement provided for a senior secured reserve-based revolving loan facility (the “Riviera Credit Facility”) with a borrowing base and borrowing commitments of $7 million. As of September 30, 2020, there were no borrowings outstanding under the Riviera Credit Facility and there was approximately $6 million of available borrowing capacity (which includes a reduction of approximately $1 million for outstanding letters of credit). The maturity date is August 4, 2021. Redetermination of the borrowing base under the Riviera Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. On June 1, 2020, the Company entered into a Fifth Amendment (the “Fifth Amendment”) to the Riviera Credit Facility. Pursuant to the Fifth Amendment, the borrowing base was reduced from $90 million to $30 million and the applicable margin for interest on borrowings was increased by 0.25%. On September 2, 2020, the Company elected to reduce the aggregate maximum credit amount under the Riviera Credit Facility from $30 million to $7 million. On October 27, 2020, the Company entered into a Sixth Amendment (the “Sixth Amendment”) to the Riviera Credit Facility. Pursuant to the Sixth Amendment, the borrowing base was reduced to $540,000, the lenders obligations to make any loans were eliminated, and the Company’s ability to make any borrowing requests was removed. In addition, the Company is required to maintain a cash deposit of at least $540,000 with a lender bank related to letter of credit commitments. The Company anticipates the Riviera Credit Facility will be terminated in the fourth quarter of 2020 as a result of the Company’s Plan of Liquidation. See Note 18. During the nine months ended September 30, 2020, the Company recorded a finance fee expense of approximately $468,000 related to the write-off of a portion of unamortized deferred financing fees due to a reduction of the Riviera Credit Facility borrowing base. During the three months and nine months ended September 30, 2019, the Company recorded a finance fee expense of approximately $700,000 related to the write-off of a portion of unamortized deferred financing fees due to a reduction of the Riviera Credit Facility borrowing base. At the Company’s election, interest on borrowings under the Riviera Credit Facility is determined by reference to either the LIBOR plus an applicable margin ranging from 2.25% to 3.25% per annum or the alternate base rate (“ABR”) plus an applicable margin ranging from 1.25 % to 2.25 % 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 six 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 Riviera 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 Riviera 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 excluding Blue Mountain Midstream, and are guaranteed by the Company and certain of its subsidiaries, subject to customary exceptions. Under the Riviera Credit Facility, the Company is required to maintain (i) a maximum total net debt to last twelve months EBITDA ratio of 3.5 to 1.0, and (ii) a minimum adjusted current ratio of 1.0 to 1.0. The Riviera Credit Facility also contains affirmative and negative covenants, including 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 Riviera 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 Riviera Credit Facility would allow the lenders, subject to customary cure rights, to require immediate payment of all amounts outstanding under the Riviera Credit Facility. As of September 30, 2020, the Company was in compliance with all financial and other covenants of the Riviera Credit Facility. Blue Mountain Midstream Credit Facility On October 8, 2020, the Company repaid approximately $80 million, representing total borrowings under the Blue Mountain Credit Facility, as defined below, with a portion of th e for information about the Blue Mountain Divestiture As of September 30, 2020, Blue Mountain Midstream’s credit agreement provided for a senior secured revolving loan facility (the “Blue Mountain Credit Facility”), with a borrowing base and borrowing commitments of $200 million at September 30, 2020. The Blue Mountain Credit Facility together with the Riviera Credit Facility, are referred to as the “Credit Facilities”). As of September 30, 2020, total borrowings outstanding under the Blue Mountain Credit Facility were approximately $80 million and there was approximately $110 million of available borrowing capacity (which included a reduction of approximately $10 million for outstanding letters of credit), subject to covenant restrictions in the Blue Mountain Credit Facility.

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2020
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivatives	Note 7 – Derivatives Commodity Derivatives As of September 30, 2020, the Company had no derivative positions. During the three months ended September 30, 2020, the Company unwound all of its natural gas fixed price swaps, oil fixed price swaps, and Panhandle Eastern Pipeline basis swaps for 2020 and 2021, for a cost of approximately $356,000. During the nine months ended September 30, 2020, the Company recognized an immaterial net gain for the unwinding of swaps. During the nine months ended September 30, 2019, the Company entered into commodity derivative contracts consisting of natural gas fixed price swaps and NGL fixed price swaps for 2019 and oil fixed price swaps and natural gas basis swaps for 2020. In addition, in July 2019, in connection with the sale of interest in properties located in Michigan, the Company canceled its MichCon natural gas basis swaps for 2019 and 2020. 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 Federal Energy Regulatory Commission’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. The NGL derivatives are settled based on the average effective price of natural gas liquids for each day of the delivery month, published in the issue of Oil Price Information Service. Balance Sheet Presentation The Company’s commodity derivatives are presented on a net basis in “derivative instruments” and “a sset retirement obligations and other noncurrent liabilities September 30, 2020 December 31, 2019 (in thousands) Assets: Commodity derivatives $ 375 $ 7,439 Liabilities: Commodity derivatives $ 1,795 $ 1,243 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. A majority of the Company’s counterparties are participants in its Credit Facilities. The Credit Facilities are secured by certain of the Company’s and its subsidiaries’ oil, natural gas and NGL reserves and personal property. 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 $375,000 at September 30, 2020. 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 A summary of gains and losses on derivatives included on the condensed consolidated statements of operations is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Gains (losses) on commodity derivatives $ (2,948 ) $ 5,665 $ 3,773 $ 12,673 Marketing expenses — (1,326 ) — (6,287 ) Gains (losses) on commodity derivatives $ (2,948 ) $ 4,339 $ 3,773 $ 6,386 The Company received net cash settlements of approximately $5 million and $11 million for the three months and nine months ended September 30, 2020, respectively. The Company received net cash settlements of approximately $8 million and $6 million for the three months and nine months ended September 30, 2019, respectively.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements on a Recurring Basis	Note 8 – Fair Value Measurements Fair Value Measurements on a Recurring Basis The Company accounts for its commodity derivatives at fair value (see Note 7) on a recurring basis. The Company determines the fair value of its commodity 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. 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: September 30, 2020 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 375 $ — $ 375 Liabilities: Commodity derivatives $ 1,795 $ — $ 1,795 (1) December 31, 2019 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 7,439 $ (156 ) $ 7,283 Liabilities: Commodity derivatives $ 1,243 $ (156 ) $ 1,087 (1) Fair Value Measurements on a Nonrecurring Basis Non-financial assets and liabilities that are initially measured at fair value include asset retirement obligations (see Note 9) and impairments (see Note 1).

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 9 – 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 assumptions represent Level 3 inputs. 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. In addition, there is insufficient information to reasonably determine the timing and/or method of settlement for purposes of estimating the fair value of the asset retirement obligation of the majority of Blue Mountain Midstream’s assets. In such cases, asset retirement obligation cost is considered indeterminate because there is no data or information that can be derived from past practice, industry practice, management’s experience, or the asset’s estimated economic life. Indeterminate asset retirement obligation costs associated with Blue Mountain Midstream will be recognized in the period in which sufficient information exists to reasonably estimate potential settlement dates and methods. The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2019 $ 21,497 Liabilities added from drilling 209 Liabilities associated with assets divested (5,628 ) Current year accretion expense 854 Settlements (1,008 ) Revision of estimates 299 Asset retirement obligations at September 30, 2020 $ 16,223 Substantially all of the Company’s asset retirement obligations at September 30, 2020, relate to properties divested subsequent to September 30, 2020. See Note 1 and Note 3.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2020
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 10 – Commitments and Contingencies The close of the Blue Mountain Divestiture on October 8, 2020, in combination with the divestitures of upstream assets, constituted a Change of Control under the Riviera Resources, Inc. 2018 Omnibus Incentive Plan (the “Riviera Omnibus Incentive Plan”) and the Blue Mountain Midstream LLC 2018 Omnibus Incentive Plan, as amended (the “BMM Incentive Plan”). Effective with the Change of Control, outstanding vested and unvested share-based compensation awards, excluding those issued to certain executive officers and directors, were cancelled and converted into the right to receive an amount in cash, without interest, equal to fair value. In addition, the Company has an employment contract with one executive officer and an ongoing severance plan for employees that provide for payments as a multiple of base salary and various other benefits in the event of termination without cause following a Change of Control. The Company expects to incur expenses of approximately $2 million in the fourth quarter of 2020 for share-based compensation and severance termination benefits. See Note 3 for information about divestitures, Note 12 for information about share-based compensation and Note 18 for information about the Company’s Plan of Liquidation. In 2016, Linn Energy, LLC, certain of its direct and indirect subsidiaries, and LinnCo, LLC (collectively, the “LINN Debtors”) filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code. The LINN Debtors emerged from bankruptcy in 2017. In 2018, LINN Energy completed the spin-off of Riviera from LINN Energy. 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, which are not affected by the closure of the LINN Debtors’ Chapter 11 cases. 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.

Operating Leases

Operating Leases	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Operating Leases	Note 11 – Operating Leases Lessee The Company leases office space and other property and equipment under lease agreements expiring on various dates through 2022. During the three months and nine months ended September 30, 2020, the Company recorded lease expenses of approximately $1 million and $3 million, respectively. During the three months and nine months ended September 30, 2019, the Company recorded lease expenses of approximately $1 million and $3 million, respectively. As of September 30, 2020, undiscounted future minimum lease payments were as follows (in thousands): 2020 $ 626 2021 2,333 2022 1,296 $ 4,255 The weighted-average remaining lease term is two years. The future minimum lease payments above include an office building under a two-year Lessor The Company previously leased a building located in Oklahoma to third parties under lease agreements. The Company sold the building in the first quarter of 2020, and the leases were terminated effective with the close of the sale. Lease income for the three months and nine months ended September 30, 2019, was approximately $1 million and $2 million, respectively. The Company has no other lease agreements for which it is the lessor. It determines if an arrangement is a lease at inception.

Share-Based Compensation

Share-Based Compensation	9 Months Ended
	Sep. 30, 2020
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Share-Based Compensation	Note 12 – Share-Based Compensation Riviera Omnibus Incentive Plan Effective with the close of the Blue Mountain Divestiture on October 8, 2020, which, in combination with the divestitures of upstream assets, constituted a Change of Control under the Riviera Omnibus Incentive Plan, outstanding vested and unvested awards, excluding those issued to certain executive officers and directors, under the Riviera Omnibus Incentive Plan were cancelled and converted into the right to receive an amount in cash, without interest, equal to fair value. The Company expects to incur expenses of approximately $1 million in the fourth quarter of 2020 for awards outstanding under the Riviera Omnibus Incentive Plan. See Note 3 for information about the Blue Mountain Divestiture and Note 18 for information about the Company’s Plan of Liquidation. As of September 30, 2020, 1,995,853 shares were issuable under the Riviera Omnibus Incentive Plan pursuant to outstanding Riviera RSUs, including (i) the Riviera Legacy RSUs, (ii) 146,260 restricted stock units of the Company granted to certain employees of the Company (the “Restricted Shares” and together with Riviera Legacy RSUs, the “Riviera RSUs”), (iii) 1,847,950 restricted stock units of the Company granted as performance units to certain employees of the Company (the “Riviera Performance Shares”) that, in the case of the Riviera Performance Shares, vest, if at all, based on the achievement of certain performance conditions specified in the award agreements. The Committee (as defined in the Riviera Omnibus Incentive Plan) has broad authority under the Riviera Omnibus Incentive Plan to, among other things: (i) select participants; (ii) determine the types of awards that participants receive and the number of shares that are subject to such awards; and (iii) establish the terms and conditions of awards, including the price (if any) to be paid for the shares or the award. As of September 30, 2020, up to 451,757 shares of common stock were available for issuance under the Riviera Omnibus Incentive Plan within the share reserve established under the Riviera Omnibus Incentive Plan, 361,799 of which the Committee has designated for issuance as Restricted Shares and 89,958 of which the Committee has designated for issuance as Riviera Performance Shares. As noted above, effective October 8, 2020, all outstanding vested and unvested awards issued under the Riviera Omnibus Incentive Plan were cancelled. Blue Mountain Midstream Omnibus Incentive Plan Effective with the close of the Blue Mountain Divestiture, on October 8, 2020, which constituted a Change of Control under the BMM Incentive Plan, all outstanding vested and unvested awards issued under the BMM Incentive Plan were cancelled and converted into the right to receive an amount in cash, without interest, equal to the Class B Unit value. The Company expects to incur expenses of an immaterial amount in the fourth quarter of 2020 for awards outstanding under the BMM Incentive Plan. See Note 3 for information about the Blue Mountain Divestiture and Note 18 for information about the Company’s Plan of Liquidation. The Blue Mountain Midstream Second Amended and Restated Limited Liability Operating Agreement (as amended, the “BMM LLC Agreement”), provides for two classes of membership units under the BMM Incentive Plan: Class A Units, of which 100% are held by Linn Holdco II (a wholly owned subsidiary of Riviera) and Class B Units. Pursuant to the BMM LLC Agreement, Blue Mountain Midstream has the authority to issue an unlimited number of Class A Units and up to 58,750 Class B Units. As of September 30, 2020, Blue Mountain Midstream had issued 738,213 Class A Units and no Class B Units. As of September 30, 2020, under the BMM Incentive Plan, Blue Mountain Midstream had granted awards that could result in the issuance of 45,272 Class B Units or an equivalent value in cash, at the Board’s discretion. The issued awards included 9,010 restricted security units and 18,131 performance stock units (“BMM PSUs”) ( 36,262 at 200% of target). As noted above, effective October 8, 2020, all outstanding vested and unvested awards issued under the BMM Incentive Plan were cancelled. Accounting for Share-Based Compensation The condensed consolidated financial statements include 100% of employee-related expenses. Compensation cost related to the grant of share-based awards has been recorded at the subsidiary level with a corresponding credit to liability or equity. As a result of the Company’s history of cash settling awards, all unvested share-based compensation awards are liability classified. The Company recorded a liability of approximately $1 million and $10 million at September 30, 2020, and December 31, 2019, respectively, related to unvested share-based compensation awards included in “other accrued liabilities” and “asset retirement obligations and other noncurrent liabilities” on the condensed consolidated balance sheets. All cash settlements of liability classified awards are classified as operating activities on the condensed consolidated statements of cash flows. A summary of share-based compensation expenses included on the condensed consolidated statements of operations is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Marketing expenses $ — $ 54 $ (127 ) $ 216 General and administrative expenses 392 2,778 (2,831 ) 12,603 Total share-based compensation expenses $ 392 $ 2,832 $ (2,958 ) $ 12,819 Income tax benefit $ — $ — $ — $ — Riviera Restricted Stock Units During the nine months ended September 30, 2020, upon vesting of Riviera RSUs and at the election of participants, the Company repurchased 100,956 Riviera RSUs for a total cost of approximately $706,000. In addition, 61,645 shares of common stock were issued to participants (net of statutory tax withholdings) upon vesting of Riviera RSUs. During the nine months ended September 30, 2020, the Company granted 15,357 RSUs with a fair value of approximately $125,000. As noted above, effective October 8, 2020, all outstanding vested and unvested awards issued under the Riviera Omnibus Incentive Plan were cancelled. During the nine months ended September 30, 2019, upon vesting of Riviera RSUs and at the election of participants, the Company repurchased 132,632 Riviera RSUs for a total cost of approximately $2 million. In addition, 81,923 shares of common stock were issued to participants (net of statutory tax withholdings) upon vesting of Riviera RSUs. Performance Shares As of September 30, 2020, there were 1,847,950 Riviera Performance Shares outstanding at 200% of target and 36,262 BMM PSUs outstanding at 200% of target. The Riviera Performance Shares and the BMM PSUs had no fair value as of September 30, 2020. As noted above, effective October 8, 2020, all outstanding vested and unvested awards issued under the Riviera Omnibus Incentive Plan and the BMM Incentive Plan were cancelled.

Loss Per Share

Loss Per Share	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Loss Per Share	Note 13 – Loss Per Share Basic loss per share is computed by dividing net loss by the weighted average number of shares outstanding during the period. Diluted loss per share is computed by adjusting the average number of shares outstanding for the dilutive effect, if any, of potential common shares. There was no dilutive effect for three months and nine months ended September 30, 2020, or September 30, 2019, therefore, basic and diluted loss per share is the same for these periods. The diluted loss per share calculation excludes the Riviera Performance Shares for the three months and nine months ended September 30, 2020, and September 30, 2019, because no performance targets have been met. The diluted loss per share calculation excludes approximately 489,000 and 318,000 restricted stock units that were anti-dilutive for the three months ended September 30, 2020, and September 30, 2019, respectively, and excludes approximately 152,000 and 199,000 restricted stock units that were anti-dilutive for the nine months ended September 30, 2020, and September 30, 2019, respectively.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 14 – Income Taxes Amounts recognized as income taxes are included in “income tax expense” on the condensed consolidated statements of operations. The Company recognized no income tax expense during the three months and nine months ended September 30, 2020, because of the full valuation allowance recorded in 2019. The Company’s effective income tax rate was approximately 0% for both the three months and nine months ended September 30, 2020. The Company’s federal and state statutory rate net of the federal tax benefit was approximately 25% for both the three months and nine months ended September 30, 2020. The Company’s effective income tax rate was approximately (128)% and (143)% for the three months and nine months ended September 30, 2019, respectively. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. During the third quarter of 2019, and for the first time since Riviera’s inception, the Company’s earnings were a cumulative loss, primarily due to losses generated during 2019. Based on the cumulative loss and projections of future taxable loss for the periods in which the deferred tax assets are deductible, the Company recorded a valuation allowance of approximately $259 million and $171 million against all of its deferred tax assets as of September 30, 2020, and December 31, 2019, respectively. The Company intends to continue maintaining a full valuation allowance on its deferred tax assets until there is sufficient evidence to support the reversal of all or some portion of these allowances. As of December 31, 2019, the Company had approximately $246 million of indefinite lived net operating loss (“NOL”) carryforwards for U.S. federal income tax purposes. Based on activity through September 30, 2020, the Company estimates that a significant amount of additional NOLs will be generated through December 31, 2020. As discussed above, the Company maintains a full valuation allowance against all of its deferred tax assets which includes deferred tax assets associated with NOLs. The Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) that was enacted March 27, 2020, includes income tax provisions that allow NOLs to be carried back, allows interest expense to be deducted up to a higher percentage of adjusted taxable income, and modifies tax depreciation of qualified improvement property, among other provisions. These provisions have no material impact on the Company.

Supplemental Disclosures to the

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	9 Months Ended
	Sep. 30, 2020
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	Note 15 – 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: September 30, 2020 December 31, 2019 (in thousands) Prepaids $ 4,570 $ 9,152 Inventories 6,777 1,116 Receivables and other 578 2,585 Other current assets $ 11,925 $ 12,853 “Accounts payable and accrued expenses” reported on the condensed consolidated balance sheets include the following: September 30, 2020 December 31, 2019 (in thousands) Accounts payable $ 27,040 $ 50,601 Accrued operating expenses 4,191 16,828 Accrued capital expenditures 711 10,087 Accrued general and administrative expenses 2,214 2,448 Other accrued expenses 751 615 Accounts payable and accrued expenses $ 34,907 $ 80,579 “Other accrued liabilities” reported on the condensed consolidated balance sheets include the following: September 30, 2020 December 31, 2019 (in thousands) Accrued compensation $ 16,743 $ 11,314 Asset retirement obligations (current portion) 1,184 1,184 Deposits 13,765 6,111 Other 84 8,119 Other accrued liabilities $ 31,776 $ 26,728 The following table provides a reconciliation of “cash and cash equivalents” reported on the condensed consolidated balance sheets to “cash, cash equivalents and restricted cash” reported on the condensed consolidated statement of cash flows: September 30, 2020 December 31, 2019 (in thousands) Cash and cash equivalents $ 94,548 $ 116,237 Restricted cash 24,887 32,932 Cash, cash equivalents and restricted cash $ 119,435 $ 149,169 Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Nine Months Ended September 30, 2020 2019 (in thousands) Cash payments for interest, net of amounts capitalized $ 1,670 $ 2,941 Cash payments for income taxes $ — $ — Cash payments for reorganization items, net $ 721 $ 756 Noncash investing activities: Accrued capital expenditures $ 711 $ 6,593 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 September 30, 2020, “restricted cash” on the condensed consolidated balance sheet consisted of approximately $10 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 $14 million related to deposits and approximately $1 million related to potential future distributions for nonvested share-based compensation awards. At December 31, 2019, “restricted cash” on the condensed consolidated balance sheet consisted of approximately $16 million that will be used to settle certain claims in accordance with the Plan, approximately $6 million related to deposits and approximately $11 million related to potential future distributions for nonvested share-based compensation awards.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2020
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Note 16 – Related Party Transactions Roan Resources LLC During 2019, through December 6, 2019, certain members of the Board were also members of the board of directors of Roan Resources, Inc. Additionally, certain of the Company’s principal stockholders were also significant stockholders of Roan Resources, Inc. For the three months and nine months ended September 30, 2019, the Company recorded revenue from Roan Resources LLC of approximately $9 million and $17 million, respectively, included in “marketing revenues” on the condensed consolidated statements of operations. For the three months and nine months ended September 30, 2019, the Company made natural gas purchases from Roan Resources LLC of approximately $19 million and $78 million, respectively, included in “marketing expenses” on the condensed consolidated statements of operations.

Segments

Segments	9 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Segments	Note 17 – Segments As of September 30, 2020, the Company had two reporting segments: upstream and Blue Mountain. The upstream reporting segment oil and natural gas properties were all located in the U.S. The Blue Mountain reporting segment consisted of a cryogenic natural gas processing facility, a network of gathering pipelines and compressors and produced water services and a crude oil gathering system located in the Merge/SCOOP/STACK play. To assess the performance of the reporting segments, the Company’s Chief Operating Decision Maker (“CODM”) analyzes field level cash flow, a non-GAAP financial metric. The Company defines field level cash flow as revenues less direct operating expenses. Other indirect income (expenses) include “general and administrative expenses,” “exploration costs,” “depreciation, depletion and amortization,” “(gains) on sale of assets and other, net,” “impairment of long-lived assets,” “other income and (expenses)” and “reorganization items, net.” Information regarding total assets by reporting segment is not presented because it is not reviewed by the CODM. During the first quarter of 2020, the definition of field level cash flow analyzed by the Company’s CODM was revised to report within segment results, expenses previously reported as unallocated to segment result s. Information presented for the prior period has been recast to conform to current presentation. The following tables present the Company’s financial information by reporting segment: Three Months Ended September 30, 2020 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 7,340 $ — $ 7,340 Marketing revenues 113 28,941 29,054 Other revenues 29 — 29 7,482 28,941 36,423 Lease operating expenses 2,367 — 2,367 Transportation expenses 818 — 818 Marketing expenses 6 20,278 20,284 Taxes other than income taxes 421 425 846 Total direct operating expenses 3,612 20,703 24,315 Field level cash flow 3,870 8,238 12,108 Losses on commodity derivatives (2,948 ) — (2,948 ) Other indirect income (expenses), net (19,602 ) (225,937 ) (245,539 ) Loss before income taxes $ (18,680 ) $ (217,699 ) $ (236,379 ) Three Months Ended September 30, 2019 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 51,029 $ — $ 51,029 Marketing revenues 11,095 34,733 45,828 Other revenues 5,532 — 5,532 67,656 34,733 102,389 Lease operating expenses 18,307 — 18,307 Transportation expenses 16,275 — 16,275 Marketing expenses 7,948 29,740 37,688 Taxes other than income taxes 4,468 643 5,111 Total direct operating expenses 46,998 30,383 77,381 Field level cash flow 20,658 4,350 25,008 Gains (losses) on commodity derivatives 5,991 (326 ) 5,665 Other indirect income (expenses), net (122,419 ) (7,243 ) (129,662 ) Loss before income taxes $ (95,770 ) $ (3,219 ) $ (98,989 ) Nine Months Ended September 30, 2020 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 33,072 $ — $ 33,072 Marketing revenues 2,811 82,029 84,840 Other revenues 69 — 69 35,952 82,029 117,981 Lease operating expenses 10,212 — 10,212 Transportation expenses 4,201 — 4,201 Marketing expenses 70 58,361 58,431 Taxes other than income taxes 2,142 1,294 3,436 Total direct operating expenses 16,625 59,655 76,280 Field level cash flow 19,327 22,374 41,701 Gains on commodity derivatives 3,307 466 3,773 Other indirect income (expenses), net (151,087 ) (253,484 ) (404,571 ) Loss before income taxes $ (128,453 ) $ (230,644 ) $ (359,097 ) Nine Months Ended September 30, 2019 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 194,131 $ — $ 194,131 Marketing revenues 46,864 119,705 166,569 Other revenues 16,685 — 16,685 257,680 119,705 377,385 Lease operating expenses 66,204 — 66,204 Transportation expenses 53,478 — 53,478 Marketing expenses 35,568 97,320 132,888 Taxes other than income taxes 11,984 2,026 14,010 Total direct operating expenses 167,234 99,346 266,580 Field level cash flow 90,446 20,359 110,805 Gains (losses) on commodity derivatives 12,830 (157 ) 12,673 Other indirect income (expenses), net (188,113 ) (25,858 ) (213,971 ) Loss before income taxes $ (84,837 ) $ (5,656 ) $ (90,493 )

Plan of Liquidation, Winding Up

Plan of Liquidation, Winding Up and Dissolution	9 Months Ended
	Sep. 30, 2020
Plan Of Dissolution Winding Up And Liquidation [Abstract]
Plan of Liquidation, Winding Up and Dissolution	Note 18 – Plan of Liquidation, Winding Up and Dissolution Plan of Liquidation The Company’s Plan of Liquidation, approved by shareholders on October 12, 2020, contemplates the orderly sale of the Company’s remaining assets and the discharge of all outstanding liabilities to third parties and, after the establishment of appropriate reserves, the distribution of any remaining cash to shareholders. Pursuant to the Plan of Liquidation, the Company will (i) pay or provide for all claims and obligations known to it, (ii) provide for any claim which is the subject of a pending action, suit or proceeding to which it is a party, (iii) provide for claims that have not been known to it but are likely to arise within ten years after the date of dissolution, (iv) after providing for (i) through (iii), distribute the remaining assets, to the extent owed, to the Company’s existing creditors, and (v) after providing for (iv), distribute any remaining assets, which the Company currently expects to be between $ 0 and $ 40 million, to the Company stockholders in accordance with the Company’s Certificate of Incorporation, as amended. This estimate is preliminary and subject to adjustment. The Plan of Liquidation also provides that the Company will make applicable filings and take such other actions as are found to be appropriate to carry out the Plan of Liquidation. The Company intends to file a certificate of dissolution with the State of Delaware, at which time the Company’s transfer books and records will be closed and the Company’s common stock will cease trading on the OTCQX Market, no later than the close of business on December 31, 2020. After such time, the Company intends to file with the U.S. Securities and Exchange Commission a Certification on Form 15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), requesting the suspension of the Company’s reporting obligations under Sections 13 and 15(d) of the Exchange Act. Based on the approval of the Plan of Liquidation in October 2020, discussed above, the Company plans to adopt the liquidation basis of accounting in the fourth quarter of 2020. Under the liquidation basis of accounting, all the Company’s assets will be stated at estimated net realizable value, or liquidation value, which represents the estimated amount of cash that the Company will collect on the disposal of assets as it carries out the Plan of Liquidation. The asset liquidation values will be based on current contracts, estimates and other indications of sales value, predicated on current values. All liabilities of the Company, including estimated costs associated with implementing the Plan of Liquidation, will be stated at estimated settlement amounts. Uncertainties as to the precise net value of non-cash assets and the ultimate amount of liabilities make it impracticable to predict with certainty the aggregate net value that may ultimately be distributable to shareholders. Claims, liabilities and future expenses for operations will continue to be incurred with execution of the Plan of Liquidation Pro Forma Financial Information Substantially all of the revenues reported on the Company’s unaudited condensed consolidated statements of operations included herein relates to properties that were divested either prior or subsequent to September 30, 2020. The following unaudited pro forma condensed consolidated financial statements are derived from historical consolidated financial statements of the Company. The unaudited pro forma condensed consolidated financial statements are for informational and illustrative purposes only and are not necessarily indicative of the financial results that would have occurred if the transactions reflected therein had occurred on the dates indicated, nor are such financial statements indicative of the results of operations in future periods. As noted above, the Company plans to adopt the liquidation basis of accounting in the fourth quarter of 2020. Under the liquidation basis of accounting, all the Company’s net assets will be stated at estimated net realizable value, or liquidation value. The The preparation of the unaudited pro forma condensed consolidated financial information is based on financial statements prepared in accordance with GAAP. These principles require the use of estimates that effect the reported amounts of revenues and expenses. The following unaudited pro forma financial information presents a summary of the Company’s condensed consolidated balance sheet as of September 30, 2020, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of September 30, 2020, and condensed consolidated results of operations for the three months and nine months ended September 30, 2020, and 2019, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of January 1, 2019: Pro Forma Condensed Consolidated Balance Sheet (Unaudited) September 30, 2020 (in thousands) Assets: Current assets $ 161,343 Oil and natural gas properties, net 2,584 Other property and equipment, net 525 Other noncurrent assets 1,062 $ 165,514 Liabilities: Current liabilities $ 52,117 Asset retirement obligations and other noncurrent liabilities 1,201 $ 53,318 Pro Forma Condensed Consolidated Statements of Operations (Unaudited) Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ (2,024 ) $ 158,806 $ 21,028 $ 237,137 Expenses 18,077 232,370 60,736 324,490 Other income (expenses) (360 ) (3,487 ) (1,839 ) (4,992 ) Loss from continuing operations before income taxes (20,461 ) (77,051 ) (41,547 ) (92,345 ) Income tax expense — 125,639 — 123,592 Loss from continuing operations $ (20,461 ) $ (202,690 ) $ (41,547 ) $ (215,937 )

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2020
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Nature of Business	Nature of Business The Company is incorporated under Delaware law and its headquarters are in Houston, Texas. Prior to the recent sales of interests in oil and natural gas properties and the sale of its wholly owned subsidiary Blue Mountain Midstream LLC (“Blue Mountain Midstream”), discussed below, Riviera was an independent oil and natural gas company. The Company had two reporting segments, upstream and Blue Mountain. The upstream reporting segment was engaged in the exploration, development, production, and sale of oil, natural gas, and natural gas liquids (“NGL”) and its properties were all located in the United States (“U.S.”). The Blue Mountain reporting segment consisted of a cryogenic natural gas processing facility, a network of gathering pipelines and compressors and produced water services and a crude oil gathering system located in the Merge/SCOOP/STACK play. Recent Developments Section 271 Sale In July 2020, the Company signed definitive agreements to sell substantially all of its interests located , North Louisiana and the The Blue Mountain Divestiture, together with the sales of interests in properties located in North Louisiana and the (collectively, the “271 Sale”), constituted a sale of substantially all of the consolidated assets of the Company for purposes of Section 271(a) of the . Therefore, on August 23, 2020, the Company elected to obtain shareholder approval and authorization of the 271 Sale. Holders of a majority of the Company’s issued and outstanding shares of common stock (the “Majority Stockholders”) executed and delivered to the Company a written consent in lieu of a special meeting. The written consent delivered by the Majority Stockholders authorized and approved the 271 Sale. Plan of Liquidation On August 24, 2020, following approval of the 271 Sale, the Company announced that it was evaluating the process of winding-up and of returning the majority of its remaining capital to its shareholders. On October 12, 2020, the Board of Directors of the Company (the “Board”), approved the dissolution, winding up and liquidation of the Company (the “Plan of Liquidation”) and adopted the Plan of Liquidation. Also, on October 12, 2020, the required percentage of the Company’s shareholders approved, through written consent in accordance with the bylaws of the Company, the Plan of Liquidation
Other Recent Developments	Other Recent Developments The Company and the oil and gas industry have been adversely impacted by certain events, including the initial dramatic increase in output from the Organization of Petroleum Exporting Countries and other oil producing nations (“ global pandemic While OPEC+ has agreed to cut production, downward pressure on commodity prices has continued. As described further below, the Company recorded impairments on oil and natural gas properties and property, plant and equipment for the nine months ended September 30, 2020. The impairment charges recorded in the three months ended September 30, 2020, were primarily due to the Company’s exit from the midstream business. The impairment charges recorded in the first quarter and second quarter of 2020 were primarily due to declines in commodity prices and declines in expected future volumes. The COVID-19 pandemic continues to evolve and identification of all trends, events and uncertainties, including a possible widespread resurgence in COVID-19 infections in the remainder of 2020 without the availability of generally effective therapeutics or a vaccine for the disease, that may impact the Company’s financial condition and results of operations are unknown at this time. D ue to the adoption of the Plan of Liquidation, the Company’s results of operations for the three months and nine months ended September 30, 2020, are not indicative of its future results.
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 consolidated financial statements and notes in the Company’s Annual Report on Form 10‑K for the year ended December 31, 2019. 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. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. There have been no material changes in critical accounting policies during the nine months ended September 30, 2020, as compared to the critical accounting policies described in Item 8. “Financial Statements and Supplementary Data” of the Company’s Annual Report on Form 10-K for the year ended December 31, 2019. Based on the approval of the Plan of Liquidation in October 2020, discussed above, t he Company plans to adopt the liquidation basis of accounting in the fourth quarter of 2020.
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 impairment evaluations, estimates of the Company’s reserves of oil, natural gas and 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. 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 consolidated financial statements in future periods.
Fair Value of Financial Instruments	Fair Value of Financial Instruments The carrying values of the Company’s receivables, payables and credit facilities are estimated to be substantially the same as their fair values at September 30, 2020, and December 31, 2019. See Note 8 for details about the fair value of the Company’s derivative financial instruments.
Recently Adopted Accounting Standard	Recently Adopted Accounting Standard In June 2016, the FASB issued an ASU that is intended to change the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The Company adopted this ASU effective January 1, 2020, using the modified retrospective effective date method. The Company’s trade receivables due in one year or less represent substantially all the items that are within the scope of the new standard. The adoption of this ASU did not have a material impact on the Company’s results of operations or financial position. Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The Company maintains an allowance for doubtful accounts for estimated losses inherent in its accounts receivable portfolio. In establishing the required allowance, management considers historical losses, current receivables aging, and existing industry and national economic data. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential recovery is remote. The balance in the Company’s allowance for doubtful accounts related to trade accounts receivable was approximately $4 million and $1 million at September 30, 2020, and December 31, 2019, respectively.
Impairment of Assets Held for Sale and Long-Lived Assets	Impairment of Assets Held for Sale and Long-Lived Assets Proved Oil and Natural Gas Properties The Company evaluates the impairment of its proved oil and natural gas properties on a field-by-field basis whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of proved properties are reduced to fair value when the expected undiscounted future cash flows of proved and risk-adjusted probable and possible reserves are less than net book value or there are alternative indications of impairment. The fair values of proved properties are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount, or the Company takes into consideration contract prices from executed definitive agreements. Significant inputs used to determine the fair values of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. These assumptions represent Level 3 inputs. These inputs require assumptions by the Company’s management at the time of the valuation and are the most sensitive and subject to change. The underlying commodity prices embedded in the Company’s estimated cash flows are the product of a process that begins with New York Mercantile Exchange (“NYMEX”) forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Company management believes will impact realizable prices. Based on the analysis described above, during the nine months ended September 30, 2020, the Company recorded noncash impairment charges of approximately $101 million associated with proved oil and natural gas properties. Of this, approximately $85 million related to divested properties located in Oklahoma, approximately $12 million to divested properties located in North Louisiana, and approximately $4 million to divested properties located in East Texas. There was no such charge during the three months ended September 30, 2020. During the three months and nine months ended September 30, 2019, the Company recorded noncash impairment charges of approximately $95 million and $113 million, respectively, associated with divested proved oil and gas properties located in the Hugoton Basin and Michigan. The impairment charges in both periods were primarily due to a decline in commodity prices. The carrying values of the impaired proved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair value measurement. The charges are associated with the upstream reporting segment and are included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statements of operations. See Note 3 for additional information about divestitures. Unproved Oil and Natural Gas Properties The Company evaluates the impairment of its unproved oil and natural gas properties whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of unproved properties are reduced to fair value based on management’s experience in similar situations and other factors such as the lease terms of the properties and the relative proportion of such properties on which proved reserves have been found in the past. Based on the analysis described above, during the nine months ended September 30, 2020, the Company recorded a noncash impairment charge of approximately $3 million associated with unproved oil and natural gas properties located in Oklahoma. There was no such charge during the three months ended September 30, 2020. The impairment was primarily due to a decline in commodity prices. The charge is associated with the upstream reporting segment and is included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statement of operations. Other Property and Equipment and Other Assets The Company evaluates the impairment of its other property and equipment whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of other property and equipment are reduced to fair value when the expected undiscounted future cash flows are less than net book value or there are alternative indications of impairment. The fair values of other property and equipment are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount, or the Company takes into consideration contract prices from executed definitive agreements. Significant inputs used to determine the fair values of other property and equipment and other assets include estimates of future operating costs, future volumes and future commodity prices. These inputs require assumptions by the Company’s management at the time of the valuation and are the most sensitive and subject to change. At September 30, 2020, because of the Blue Mountain Divestiture, the Company performed an impairment evaluation of Blue Mountain Midstream’s other property and equipment and other assets. Based on the analysis described above, during the three months and nine months ended September 30, 2020, the Company recorded impairment charges of approximately $220 million and $237 million, respectively, to reduce the carrying value of Blue Mountain Midstream’s assets to fair value less cost to sell using Level 3 inputs. The impairment charges recorded in the three months ended September 30, 2020, were primarily triggered by the Company’s exit from the midstream business, with the fair value being predominantly driven by the contract price of the Blue Mountain Divestiture. The impairment charges recorded in the first quarter and second quarter of 2020 were primarily due to a decline in expected future volumes in the crude gathering business, related to the economics of customers drilling in the area. The charges are primarily associated with the Blue Mountain reporting segment, with $1 million of the charges associated with the upstream reporting segment and are included in “impairment of assets held for sale and long-lived assets” on the condensed consolidated statements of operations.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2020
Revenue From Contract With Customer [Abstract]
Schedule of Company's Disaggregated Revenues	The following tables present the Company’s disaggregated revenues by source and geographic area: Three Months Ended September 30, 2020 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Mid-Continent $ 2,140 $ 2,657 $ 645 $ 5,442 $ — $ 30 $ 5,472 East Texas (11 ) — — (11 ) — — (11 ) North Louisiana 1,675 187 53 1,915 113 — 2,028 Uinta Basin (13 ) — — (13 ) — — (13 ) Other divested properties 5 — 2 7 — (1 ) 6 Blue Mountain — — — — 28,941 — 28,941 Total $ 3,796 $ 2,844 $ 700 $ 7,340 $ 29,054 $ 29 $ 36,423 Three Months Ended September 30, 2019 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 12,057 $ 405 $ 5,561 $ 18,023 $ 9,810 $ 5,413 $ 33,246 Mid-Continent 3,870 8,387 1,171 13,428 — 78 13,506 East Texas 7,379 812 492 8,683 843 2 9,528 North Louisiana 6,849 467 141 7,457 442 2 7,901 Uinta Basin 2,845 — — 2,845 — 1 2,846 Michigan/Illinois 82 504 7 593 — 36 629 Blue Mountain — — — — 34,733 — 34,733 Total $ 33,082 $ 10,575 $ 7,372 $ 51,029 $ 45,828 $ 5,532 $ 102,389 Nine Months Ended September 30, 2020 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Mid-Continent $ 8,269 $ 10,369 $ 2,302 $ 20,940 $ — $ 87 $ 21,027 East Texas 2,510 328 444 3,282 2,282 2 5,566 North Louisiana 7,003 700 234 7,937 525 1 8,463 Uinta Basin 906 — (8 ) 898 — — 898 Other divested properties 7 27 (19 ) 15 4 (21 ) (2 ) Blue Mountain — — — — 82,029 — 82,029 Total $ 18,695 $ 11,424 $ 2,953 $ 33,072 $ 84,840 $ 69 $ 117,981 Nine Months Ended September 30, 2019 Natural Gas Oil NGL Oil, Natural Gas and NGL Sales Marketing Revenues Other Revenues Total (in thousands) Hugoton Basin $ 49,993 $ 1,198 $ 22,843 $ 74,034 $ 42,962 $ 16,485 $ 133,481 Mid-Continent 12,639 18,507 5,493 36,639 — 102 36,741 East Texas 28,228 2,609 1,500 32,337 2,740 6 35,083 North Louisiana 20,352 2,225 901 23,478 1,162 5 24,645 Uinta Basin 12,388 86 5 12,479 — 1 12,480 Michigan/Illinois 13,223 1,900 41 15,164 — 86 15,250 Blue Mountain — — — — 119,705 — 119,705 Total $ 136,823 $ 26,525 $ 30,783 $ 194,131 $ 166,569 $ 16,685 $ 377,385

Divestitures (Tables)

Divestitures (Tables)	9 Months Ended
	Sep. 30, 2020
Summarized Statements of Operations and Balance Sheet Information	The following unaudited pro forma financial information presents a summary of the Company’s condensed consolidated balance sheet as of September 30, 2020, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of September 30, 2020, and condensed consolidated results of operations for the three months and nine months ended September 30, 2020, and 2019, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of January 1, 2019: Pro Forma Condensed Consolidated Balance Sheet (Unaudited) September 30, 2020 (in thousands) Assets: Current assets $ 161,343 Oil and natural gas properties, net 2,584 Other property and equipment, net 525 Other noncurrent assets 1,062 $ 165,514 Liabilities: Current liabilities $ 52,117 Asset retirement obligations and other noncurrent liabilities 1,201 $ 53,318 Pro Forma Condensed Consolidated Statements of Operations (Unaudited) Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ (2,024 ) $ 158,806 $ 21,028 $ 237,137 Expenses 18,077 232,370 60,736 324,490 Other income (expenses) (360 ) (3,487 ) (1,839 ) (4,992 ) Loss from continuing operations before income taxes (20,461 ) (77,051 ) (41,547 ) (92,345 ) Income tax expense — 125,639 — 123,592 Loss from continuing operations $ (20,461 ) $ (202,690 ) $ (41,547 ) $ (215,937 )
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 sheet: December 31, 2019 (in thousands) Assets: Oil and natural gas properties, net $ 17,732 Other property and equipment, net 85,798 Other 1,243 Total assets held for sale $ 104,773 Liabilities: Asset retirement obligations $ 33,542 Other 1,635 Total liabilities held for sale $ 35,177
Mid-Continent Divestiture
Summarized Statements of Operations and Balance Sheet Information	The following are summarized results of operations and balance sheet information for the Mid-Continent Assets: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ 6,558 $ 9,763 $ 18,231 $ 33,373 Expenses 3,977 8,195 104,337 25,865 Income (loss) before income taxes 2,581 1,568 (86,106 ) 7,508 Income tax expense — 24,560 — 33,275 Net income (loss) $ 2,581 $ (22,992 ) $ (86,106 ) $ (25,767 ) September 30, 2020 (in thousands) Assets: Current assets $ 7,859 Oil and natural gas properties, net 11,325 Other property and equipment, net 1,825 $ 21,009 Liabilities: Current liabilities $ 5,003 Asset retirement obligations 14,487 $ 19,490
Blue Mountain Divestiture
Summarized Statements of Operations and Balance Sheet Information	The following are summarized results of operations and balance sheet information for the Blue Mountain Divestiture: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ 28,941 $ 34,407 $ 82,495 $ 119,548 Expenses 20,703 30,383 59,655 99,346 Other income (expenses) (226,737 ) (7,243 ) (254,284 ) (25,858 ) Loss before income taxes (218,499 ) (3,219 ) (231,444 ) (5,656 ) Income tax benefit — (28,204 ) — (27,775 ) Net (loss) income $ (218,499 ) $ 24,985 $ (231,444 ) $ 22,119 September 30, 2020 (in thousands) Assets: Current assets $ 21,777 Other property and equipment, net 101,683 Other noncurrent assets 3,628 $ 127,088 Liabilities: Current liabilities $ 10,227 Credit facility 80,000 Asset retirement obligations 716 Other noncurrent liabilities 936 $ 91,879

Oil and Natural Gas Properties

Oil and Natural Gas Properties (Tables)	9 Months Ended
	Sep. 30, 2020
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: September 30, 2020 December 31, 2019 (in thousands) Proved properties $ 122,307 $ 174,845 Unproved properties 3,082 5,462 125,389 180,307 Less accumulated depletion and amortization (111,480 ) (35,603 ) $ 13,909 $ 144,704

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2020
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Summary of Fair Value of Derivatives Outstanding on Gross Basis	The Company’s commodity derivatives are presented on a net basis in “derivative instruments” and “a sset retirement obligations and other noncurrent liabilities September 30, 2020 December 31, 2019 (in thousands) Assets: Commodity derivatives $ 375 $ 7,439 Liabilities: Commodity derivatives $ 1,795 $ 1,243
Summary of Gains and Losses on Derivatives	A summary of gains and losses on derivatives included on the condensed consolidated statements of operations is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Gains (losses) on commodity derivatives $ (2,948 ) $ 5,665 $ 3,773 $ 12,673 Marketing expenses — (1,326 ) — (6,287 ) Gains (losses) on commodity derivatives $ (2,948 ) $ 4,339 $ 3,773 $ 6,386

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Schedule of Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis: September 30, 2020 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 375 $ — $ 375 Liabilities: Commodity derivatives $ 1,795 $ — $ 1,795 (1) December 31, 2019 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 7,439 $ (156 ) $ 7,283 Liabilities: Commodity derivatives $ 1,243 $ (156 ) $ 1,087 (1)

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2020
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Reconciliation of Company's Asset Retirement Obligations	The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2019 $ 21,497 Liabilities added from drilling 209 Liabilities associated with assets divested (5,628 ) Current year accretion expense 854 Settlements (1,008 ) Revision of estimates 299 Asset retirement obligations at September 30, 2020 $ 16,223

Operating Leases (Tables)

Operating Leases (Tables)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Schedule of Future Minimum Lease Payments	As of September 30, 2020, undiscounted future minimum lease payments were as follows (in thousands): 2020 $ 626 2021 2,333 2022 1,296 $ 4,255

Share-Based Compensation (Table

Share-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2020
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Summary of Share-Based Compensation Expenses	A summary of share-based compensation expenses included on the condensed consolidated statements of operations is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Marketing expenses $ — $ 54 $ (127 ) $ 216 General and administrative expenses 392 2,778 (2,831 ) 12,603 Total share-based compensation expenses $ 392 $ 2,832 $ (2,958 ) $ 12,819 Income tax benefit $ — $ — $ — $ —

Supplemental Disclosures to t_2

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Tables)	9 Months Ended
	Sep. 30, 2020
Supplemental Disclosures To The Condensed Consolidated Statements Of Cash Flows [Abstract]
Schedule of Other Current Assets	“Other current assets” reported on the condensed consolidated balance sheets include the following: September 30, 2020 December 31, 2019 (in thousands) Prepaids $ 4,570 $ 9,152 Inventories 6,777 1,116 Receivables and other 578 2,585 Other current assets $ 11,925 $ 12,853
Schedule of Accounts Payable and Accrued Expenses	“Accounts payable and accrued expenses” reported on the condensed consolidated balance sheets include the following: September 30, 2020 December 31, 2019 (in thousands) Accounts payable $ 27,040 $ 50,601 Accrued operating expenses 4,191 16,828 Accrued capital expenditures 711 10,087 Accrued general and administrative expenses 2,214 2,448 Other accrued expenses 751 615 Accounts payable and accrued expenses $ 34,907 $ 80,579
Schedule of Other Accrued Liabilities	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following: September 30, 2020 December 31, 2019 (in thousands) Accrued compensation $ 16,743 $ 11,314 Asset retirement obligations (current portion) 1,184 1,184 Deposits 13,765 6,111 Other 84 8,119 Other accrued liabilities $ 31,776 $ 26,728
Schedule of Reconciliation of Cash, Cash Equivalents and Restricted Cash	The following table provides a reconciliation of “cash and cash equivalents” reported on the condensed consolidated balance sheets to “cash, cash equivalents and restricted cash” reported on the condensed consolidated statement of cash flows: September 30, 2020 December 31, 2019 (in thousands) Cash and cash equivalents $ 94,548 $ 116,237 Restricted cash 24,887 32,932 Cash, cash equivalents and restricted cash $ 119,435 $ 149,169
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Nine Months Ended September 30, 2020 2019 (in thousands) Cash payments for interest, net of amounts capitalized $ 1,670 $ 2,941 Cash payments for income taxes $ — $ — Cash payments for reorganization items, net $ 721 $ 756 Noncash investing activities: Accrued capital expenditures $ 711 $ 6,593

Segments (Tables)

Segments (Tables)	9 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables present the Company’s financial information by reporting segment: Three Months Ended September 30, 2020 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 7,340 $ — $ 7,340 Marketing revenues 113 28,941 29,054 Other revenues 29 — 29 7,482 28,941 36,423 Lease operating expenses 2,367 — 2,367 Transportation expenses 818 — 818 Marketing expenses 6 20,278 20,284 Taxes other than income taxes 421 425 846 Total direct operating expenses 3,612 20,703 24,315 Field level cash flow 3,870 8,238 12,108 Losses on commodity derivatives (2,948 ) — (2,948 ) Other indirect income (expenses), net (19,602 ) (225,937 ) (245,539 ) Loss before income taxes $ (18,680 ) $ (217,699 ) $ (236,379 ) Three Months Ended September 30, 2019 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 51,029 $ — $ 51,029 Marketing revenues 11,095 34,733 45,828 Other revenues 5,532 — 5,532 67,656 34,733 102,389 Lease operating expenses 18,307 — 18,307 Transportation expenses 16,275 — 16,275 Marketing expenses 7,948 29,740 37,688 Taxes other than income taxes 4,468 643 5,111 Total direct operating expenses 46,998 30,383 77,381 Field level cash flow 20,658 4,350 25,008 Gains (losses) on commodity derivatives 5,991 (326 ) 5,665 Other indirect income (expenses), net (122,419 ) (7,243 ) (129,662 ) Loss before income taxes $ (95,770 ) $ (3,219 ) $ (98,989 ) Nine Months Ended September 30, 2020 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 33,072 $ — $ 33,072 Marketing revenues 2,811 82,029 84,840 Other revenues 69 — 69 35,952 82,029 117,981 Lease operating expenses 10,212 — 10,212 Transportation expenses 4,201 — 4,201 Marketing expenses 70 58,361 58,431 Taxes other than income taxes 2,142 1,294 3,436 Total direct operating expenses 16,625 59,655 76,280 Field level cash flow 19,327 22,374 41,701 Gains on commodity derivatives 3,307 466 3,773 Other indirect income (expenses), net (151,087 ) (253,484 ) (404,571 ) Loss before income taxes $ (128,453 ) $ (230,644 ) $ (359,097 ) Nine Months Ended September 30, 2019 Upstream Blue Mountain Consolidated (in thousands) Oil, natural gas and natural gas liquids sales $ 194,131 $ — $ 194,131 Marketing revenues 46,864 119,705 166,569 Other revenues 16,685 — 16,685 257,680 119,705 377,385 Lease operating expenses 66,204 — 66,204 Transportation expenses 53,478 — 53,478 Marketing expenses 35,568 97,320 132,888 Taxes other than income taxes 11,984 2,026 14,010 Total direct operating expenses 167,234 99,346 266,580 Field level cash flow 90,446 20,359 110,805 Gains (losses) on commodity derivatives 12,830 (157 ) 12,673 Other indirect income (expenses), net (188,113 ) (25,858 ) (213,971 ) Loss before income taxes $ (84,837 ) $ (5,656 ) $ (90,493 )

Plan of Liquidation, Winding _2

Plan of Liquidation, Winding Up and Dissolution (Tables)	9 Months Ended
	Sep. 30, 2020
Plan Of Dissolution Winding Up And Liquidation [Abstract]
Summarized Statements of Operations and Balance Sheet Information	The following unaudited pro forma financial information presents a summary of the Company’s condensed consolidated balance sheet as of September 30, 2020, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of September 30, 2020, and condensed consolidated results of operations for the three months and nine months ended September 30, 2020, and 2019, giving effect to the Blue Mountain Divestiture and divestiture of Mid-Continent Assets as if they had been completed as of January 1, 2019: Pro Forma Condensed Consolidated Balance Sheet (Unaudited) September 30, 2020 (in thousands) Assets: Current assets $ 161,343 Oil and natural gas properties, net 2,584 Other property and equipment, net 525 Other noncurrent assets 1,062 $ 165,514 Liabilities: Current liabilities $ 52,117 Asset retirement obligations and other noncurrent liabilities 1,201 $ 53,318 Pro Forma Condensed Consolidated Statements of Operations (Unaudited) Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (in thousands) Revenues and other $ (2,024 ) $ 158,806 $ 21,028 $ 237,137 Expenses 18,077 232,370 60,736 324,490 Other income (expenses) (360 ) (3,487 ) (1,839 ) (4,992 ) Loss from continuing operations before income taxes (20,461 ) (77,051 ) (41,547 ) (92,345 ) Income tax expense — 125,639 — 123,592 Loss from continuing operations $ (20,461 ) $ (202,690 ) $ (41,547 ) $ (215,937 )

Basis of Presentation - Additio

Basis of Presentation - Additional Information (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)Segment	Sep. 30, 2019USD ($)	Dec. 31, 2019USD ($)
Basis Of Presentation [Line Items]
Number of reportable segments | Segment			2
Severance expenses	$ 10,000,000		$ 15,000,000
Allowance for doubtful accounts	4,000,000		4,000,000		$ 1,000,000
Proved Oil And Natural Gas Properties
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties	0		$ 101,000,000
Impairment charges due to decline in commodity prices			The impairment charges in both periods were primarily due to a decline in commodity prices.
Proved Oil And Natural Gas Properties | East Texas
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties			$ 4,000,000
Proved Oil And Natural Gas Properties | North Louisiana
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties			12,000,000
Proved Oil And Natural Gas Properties | Oklahoma
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties			85,000,000
Proved Oil And Natural Gas Properties | Hugoton Basin and Michigan
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties		$ 95,000,000		$ 113,000,000
Unproved Oil and Natural Gas Properties | Oklahoma
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties	0		$ 3,000,000
Impairment charges due to decline in commodity prices			The impairment was primarily due to a decline in commodity prices.
Other Property and Equipment | Blue Mountain Midstream
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties	220,000,000		$ 237,000,000
Impairment charges due to decline in commodity prices			The impairment charges recorded in the three months ended September 30, 2020, were primarily triggered by the Company’s exit from the midstream business, with the fair value being predominantly driven by the contract price of the Blue Mountain Divestiture.  The impairment charges recorded in the first quarter and second quarter of 2020 were primarily due to a decline in expected future volumes in the crude gathering business, related to the economics of customers drilling in the area.
Other Property and Equipment | Blue Mountain Midstream | Upstream
Basis Of Presentation [Line Items]
Impairment of oil and natural gas properties	$ 1,000,000

Revenues - Schedule of Company'

Revenues - Schedule of Company's Disaggregated Revenues (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Disaggregation Of Revenue [Line Items]
Revenues	$ 36,423	$ 102,389	$ 117,981	$ 377,385
Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	3,796	33,082	18,695	136,823
Oil
Disaggregation Of Revenue [Line Items]
Revenues	2,844	10,575	11,424	26,525
NGL
Disaggregation Of Revenue [Line Items]
Revenues	700	7,372	2,953	30,783
Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	7,340	51,029	33,072	194,131
Marketing
Disaggregation Of Revenue [Line Items]
Revenues	29,054	45,828	84,840	166,569
Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	29	5,532	69	16,685
Mid-Continent
Disaggregation Of Revenue [Line Items]
Revenues	5,472	13,506	21,027	36,741
Mid-Continent | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	2,140	3,870	8,269	12,639
Mid-Continent | Oil
Disaggregation Of Revenue [Line Items]
Revenues	2,657	8,387	10,369	18,507
Mid-Continent | NGL
Disaggregation Of Revenue [Line Items]
Revenues	645	1,171	2,302	5,493
Mid-Continent | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	5,442	13,428	20,940	36,639
Mid-Continent | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Mid-Continent | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	30	78	87	102
East Texas
Disaggregation Of Revenue [Line Items]
Revenues	(11)	9,528	5,566	35,083
East Texas | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	(11)	7,379	2,510	28,228
East Texas | Oil
Disaggregation Of Revenue [Line Items]
Revenues	0	812	328	2,609
East Texas | NGL
Disaggregation Of Revenue [Line Items]
Revenues	0	492	444	1,500
East Texas | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	(11)	8,683	3,282	32,337
East Texas | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	0	843	2,282	2,740
East Texas | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	0	2	2	6
North Louisiana
Disaggregation Of Revenue [Line Items]
Revenues	2,028	7,901	8,463	24,645
North Louisiana | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	1,675	6,849	7,003	20,352
North Louisiana | Oil
Disaggregation Of Revenue [Line Items]
Revenues	187	467	700	2,225
North Louisiana | NGL
Disaggregation Of Revenue [Line Items]
Revenues	53	141	234	901
North Louisiana | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	1,915	7,457	7,937	23,478
North Louisiana | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	113	442	525	1,162
North Louisiana | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	0	2	1	5
Uinta Basin
Disaggregation Of Revenue [Line Items]
Revenues	(13)	2,846	898	12,480
Uinta Basin | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	(13)	2,845	906	12,388
Uinta Basin | Oil
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	86
Uinta Basin | NGL
Disaggregation Of Revenue [Line Items]
Revenues	0	0	(8)	5
Uinta Basin | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	(13)	2,845	898	12,479
Uinta Basin | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Uinta Basin | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	0	1	0	1
Hugoton Basin
Disaggregation Of Revenue [Line Items]
Revenues		33,246		133,481
Hugoton Basin | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues		12,057		49,993
Hugoton Basin | Oil
Disaggregation Of Revenue [Line Items]
Revenues		405		1,198
Hugoton Basin | NGL
Disaggregation Of Revenue [Line Items]
Revenues		5,561		22,843
Hugoton Basin | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues		18,023		74,034
Hugoton Basin | Marketing
Disaggregation Of Revenue [Line Items]
Revenues		9,810		42,962
Hugoton Basin | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues		5,413		16,485
Michigan/Illinois
Disaggregation Of Revenue [Line Items]
Revenues		629		15,250
Michigan/Illinois | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues		82		13,223
Michigan/Illinois | Oil
Disaggregation Of Revenue [Line Items]
Revenues		504		1,900
Michigan/Illinois | NGL
Disaggregation Of Revenue [Line Items]
Revenues		7		41
Michigan/Illinois | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues		593		15,164
Michigan/Illinois | Marketing
Disaggregation Of Revenue [Line Items]
Revenues		0		0
Michigan/Illinois | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues		36		86
Other Divested Properties
Disaggregation Of Revenue [Line Items]
Revenues	6		(2)
Other Divested Properties | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	5		7
Other Divested Properties | Oil
Disaggregation Of Revenue [Line Items]
Revenues	0		27
Other Divested Properties | NGL
Disaggregation Of Revenue [Line Items]
Revenues	2		(19)
Other Divested Properties | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	7		15
Other Divested Properties | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	0		4
Other Divested Properties | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	(1)		(21)
Blue Mountain
Disaggregation Of Revenue [Line Items]
Revenues	28,941	34,733	82,029	119,705
Blue Mountain | Natural Gas
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Blue Mountain | Oil
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Blue Mountain | NGL
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Blue Mountain | Oil, Natural Gas and NGL Sales
Disaggregation Of Revenue [Line Items]
Revenues	0	0	0	0
Blue Mountain | Marketing
Disaggregation Of Revenue [Line Items]
Revenues	28,941	34,733	82,029	119,705
Blue Mountain | Other Revenues
Disaggregation Of Revenue [Line Items]
Revenues	$ 0	$ 0	$ 0	$ 0

Revenues - Additional Informati

Revenues - Additional Information (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Revenue From Contract With Customer [Abstract]
Contract with Customer, Accounts Receivable	$ 16	$ 43

Divestitures - Additional Infor

Divestitures - Additional Information (Details) - USD ($)

Oct. 08, 2020

Oct. 01, 2020

Sep. 01, 2020

Apr. 02, 2020

Feb. 28, 2020

Feb. 14, 2020

Jan. 31, 2020

Jan. 15, 2020

Nov. 22, 2019

Sep. 05, 2019

Aug. 30, 2019

Jul. 03, 2019

May 31, 2019

Jan. 17, 2019

Dec. 31, 2020

Sep. 30, 2020

Jun. 30, 2020

Sep. 30, 2019

Sep. 30, 2020

Sep. 30, 2019

Dec. 31, 2019

Dec. 31, 2018

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Deposits

$ 13,765,000

$ 13,765,000

$ 6,111,000

Gain (loss) on disposition of oil and gas property

$ 4,000,000

Impairment of assets held for sale and long-lived assets

219,606,000

$ 95,080,000

341,264,000

$ 113,470,000

Income (loss) before income taxes

(236,379,000)

(98,989,000)

(359,097,000)

(90,493,000)

Subsequent Event

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Repayments of line of credit

$ 80,000,000

Drunkards Wash Field Uinta Basin Interest In Properties Sales

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 4,000,000

Deposits

450,000

Gain (loss) on disposition of oil and gas property

$ 1,000,000

Overton Field Of East Texas Interest In Properties Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 17,000,000

Deposits

2,000,000

Personville Field Of East Texas Interest In Properties Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 28,000,000

Deposits

$ 3,000,000

Oklahoma City Office Building Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 21,000,000

East Texas Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 392,000

North Louisiana Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 23,000,000

$ 2,000,000

Gain (loss) on disposition of oil and gas property

$ (1,000,000)

$ 376,000

Impairment of assets held for sale and long-lived assets

$ 12,000,000

Mid-Continent Divestiture

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Income (loss) before income taxes

2,581,000

1,568,000

(86,106,000)

7,508,000

Mid-Continent Divestiture | Forecast

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Gain (loss) on disposition of oil and gas property

$ 16,000,000

Mid-Continent Divestiture | Subsequent Event

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 13,000,000

Deposits

$ 2,000,000

Blue Mountain Divestiture

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Deposits

11,000,000

11,000,000

Impairment of assets held for sale and long-lived assets

220,000,000

237,000,000

Income (loss) before income taxes

$ (218,499,000)

(3,219,000)

$ (231,444,000)

(5,656,000)

Blue Mountain Divestiture | Subsequent Event

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

114,000,000

Blue Mountain Divestiture | Subsequent Event | Blue Mountain Credit Facility

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Repayments of line of credit

$ 80,000,000

Hugoton Basin Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 286,000,000

$ 29,000,000

Gain (loss) on disposition of oil and gas property

$ 10,000,000

Impairment of assets held for sale and long-lived assets

$ 95,000,000

Income (loss) before income taxes

$ (98,000,000)

$ (89,000,000)

Illinois Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 4,000,000

Michigan Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 39,000,000

Impairment of assets held for sale and long-lived assets

$ 18,000,000

Arkoma Assets Sale

Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]

Proceeds from divestiture of businesses

$ 64,000,000

Deposits

$ 5,000,000

Gain (loss) on disposition of oil and gas property

$ 28,000,000

Divestitures - Summarized State

Divestitures - Summarized Statement of Operation of Mid-Continent Divestiture (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	$ 33,475			$ 108,054			$ 121,754	$ 390,058
Expenses	268,635			203,835			476,462	473,684
Income (loss) before income taxes	(236,379)			(98,989)			(359,097)	(90,493)
Income tax expense	0			126,646			0	129,092
Net income (loss)	(236,379)	$ (21,212)	$ (101,506)	(225,635)	$ (6,676)	$ 12,726	(359,097)	(219,585)
Mid-Continent Divestiture
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	6,558			9,763			18,231	33,373
Expenses	3,977			8,195			104,337	25,865
Income (loss) before income taxes	2,581			1,568			(86,106)	7,508
Income tax expense	0			24,560			0	33,275
Net income (loss)	$ 2,581			$ (22,992)			$ (86,106)	$ (25,767)

Divestitures - Summarized Balan

Divestitures - Summarized Balance Sheet of Mid-Continent Divestiture (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
ASSETS
Current assets	$ 153,929	$ 325,433
Oil and natural gas properties, net	13,909	144,704
Other property and equipment, net	104,033	338,470
Total assets	276,561	816,259
Liabilities:
Current liabilities	68,478	$ 143,571
Mid-Continent Divestiture
ASSETS
Current assets	7,859
Oil and natural gas properties, net	11,325
Other property and equipment, net	1,825
Total assets	21,009
Liabilities:
Current liabilities	5,003
Asset retirement obligations	14,487
Liabilities	$ 19,490

Divestitures - Summarized Resul

Divestitures - Summarized Results of Operation of Blue Mountain Divestiture (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	$ 33,475			$ 108,054			$ 121,754	$ 390,058
Expenses	268,635			203,835			476,462	473,684
Other income (expenses)	(309)			(595)			(1,317)	(708)
Income (loss) before income taxes	(236,379)			(98,989)			(359,097)	(90,493)
Income tax benefit	0			(126,646)			0	(129,092)
Net income (loss)	(236,379)	$ (21,212)	$ (101,506)	(225,635)	$ (6,676)	$ 12,726	(359,097)	(219,585)
Blue Mountain Divestiture
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	28,941			34,407			82,495	119,548
Expenses	20,703			30,383			59,655	99,346
Other income (expenses)	(226,737)			(7,243)			(254,284)	(25,858)
Income (loss) before income taxes	(218,499)			(3,219)			(231,444)	(5,656)
Income tax benefit	0			(28,204)			0	(27,775)
Net income (loss)	$ (218,499)			$ 24,985			$ (231,444)	$ 22,119

Divestitures - Summarized Res_2

Divestitures - Summarized Results of Balance Sheet of Blue Mountain Divestiture (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
ASSETS
Current assets	$ 153,929	$ 325,433
Other property and equipment, net	104,033	338,470
Other noncurrent assets	4,690	7,652
Total assets	276,561	816,259
Liabilities:
Current liabilities	68,478	143,571
Credit facilities	80,000	69,800
Other noncurrent liabilities	16,209	$ 29,337
Blue Mountain Divestiture
ASSETS
Current assets	21,777
Other property and equipment, net	101,683
Other noncurrent assets	3,628
Total assets	127,088
Liabilities:
Current liabilities	10,227
Credit facilities	80,000
Asset retirement obligations	716
Other noncurrent liabilities	936
Liabilities	$ 91,879

Divestitures - Disclosure of Lo

Divestitures - Disclosure of Long Lived Assets Held-for-sale (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
ASSETS
Oil and natural gas properties, net		$ 17,732
Other property and equipment, net		85,798
Other		1,243
Total assets held for sale	$ 0	104,773
Liabilities:
Asset retirement obligations		33,542
Other		1,635
Total liabilities held for sale	$ 0	$ 35,177

Equity (Deficit) - Additional I

Equity (Deficit) - Additional Information (Details) - USD ($)

Oct. 12, 2020

May 11, 2020

Jun. 30, 2020

Mar. 31, 2020

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Sep. 30, 2020

Dec. 31, 2019

Apr. 23, 2020

Mar. 09, 2020

Jul. 18, 2019

Class Of Stock [Line Items]

Stock repurchased during period, value

$ 2,066,000

$ 65,353,000

$ 43,307,000

$ 34,437,000

Cash distributions declared, per share

$ 0.75

$ 1

Dividends paid

$ 43,000,000

$ 43,430,000

57,908,000

$ 58,000,000

Dividends payment date

Apr. 22, 2020

Dividends payment date of record

Apr. 8, 2020

Share based compensation award nonvested future distribution amount

$ 1,000,000

$ 11,000,000

Subsequent Event

Class Of Stock [Line Items]

Cash distributions declared, per share

$ 1.35

Dividends paid

$ 78,000,000

Dividends payment date

Oct. 28, 2020

Dividends payment date of record

Oct. 23, 2020

Common Stock

Class Of Stock [Line Items]

Stock repurchased during period, shares

282,742

Share repurchased program average price per share

$ 7.31

Stock repurchased during period, value

3,000

$ 50,000

$ 32,000

$ 25,000

Dividends paid

$ 0

$ 0

Common Stock | Share Repurchase Program

Class Of Stock [Line Items]

Stock repurchased during period, value

$ 2,000,000

Common Stock | Maximum

Class Of Stock [Line Items]

Stock repurchase program, authorized amount

$ 150,000,000

Oil and Natural Gas Propertie_2

Oil and Natural Gas Properties - Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Oil and Natural Gas Capitalized Costs
Proved properties	$ 122,307	$ 174,845
Unproved properties	3,082	5,462
Capitalized cost, oil and gas producing activities	125,389	180,307
Less accumulated depletion and amortization	(111,480)	(35,603)
Capitalized costs, oil and gas producing activities, net	$ 13,909	$ 144,704

Debt - Additional Information (

Debt - Additional Information (Details) - USD ($)	Oct. 08, 2020	Sep. 02, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Oct. 30, 2020	Jun. 30, 2020	Mar. 31, 2020
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity				$ 200,000,000
Margin for interest on borrowings increase				0.25%
Subsequent Event
Debt Instrument [Line Items]
Repayments of line of credit	$ 80,000,000
Riviera Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity				$ 7,000,000			$ 30,000,000	$ 90,000,000
Long-term line of credit				0
Line of Credit Facility, Remaining Borrowing Capacity				6,000,000
Letters of Credit Outstanding, Amount				$ 1,000,000
Line of credit, maturity date				Aug. 4, 2021
Line of credit facility, maximum amount outstanding during period		$ 30,000,000
Cash deposit with a lender bank related to letter of credit commitments				$ 540,000
Finance fees expenses			$ 700,000	$ 468,000	$ 700,000
Line of credit facility, unused capacity, commitment fee percentage				0.50%
Line of credit facility, interest payment term				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 six months, at the end of the three-month intervals during such interest period.
Line of credit facility portion of properties required to maintain mortgages				85.00%
Riviera Credit Facility | Minimum
Debt Instrument [Line Items]
Current ratio				100.00%
Riviera Credit Facility | Maximum
Debt Instrument [Line Items]
Debt to EBITDA ratio				350.00%
Riviera Credit Facility | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				2.25%
Riviera Credit Facility | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				3.25%
Riviera Credit Facility | ABR | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				1.25%
Riviera Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				2.25%
Riviera Credit Facility | Subsequent Event
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity						$ 540,000
Blue Mountain Credit Facility | Blue Mountain Midstream
Debt Instrument [Line Items]
Long-term line of credit				$ 80,000,000
Line of Credit Facility, Remaining Borrowing Capacity				110,000,000
Letters of Credit Outstanding, Amount				$ 10,000,000

Derivatives - Additional Inform

Derivatives - Additional Information (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Unwinding cost of natural gas, oil and PEPL basis swaps	$ 356,000
Concentration risk, credit risk, financial instrument, maximum exposure			$ 375,000
Cash settlements on derivatives	$ 5,000,000	$ 8,000,000	$ 11,389,000	$ 5,740,000

Derivatives - Summary of Fair V

Derivatives - Summary of Fair Value of Derivatives Outstanding on Gross Basis (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Assets:
Commodity derivatives	$ 375	$ 7,439
Liabilities:
Commodity derivatives	$ 1,795	$ 1,243

Derivatives - Summary of Gains

Derivatives - Summary of Gains and Losses on Derivatives (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative Instruments Gain Loss [Line Items]
Gains (losses) on commodity derivatives	$ (2,948)	$ 4,339	$ 3,773	$ 6,386
Gains (losses) on commodity derivatives
Derivative Instruments Gain Loss [Line Items]
Gains (losses) on commodity derivatives	(2,948)	5,665	3,773	12,673
Marketing expenses
Derivative Instruments Gain Loss [Line Items]
Gains (losses) on commodity derivatives	$ 0	$ (1,326)	$ 0	$ (6,287)

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Thousands		Sep. 30, 2020	Dec. 31, 2019
Assets:
Commodity derivatives		$ 375	$ 7,439
Commodity derivatives	[1]	0	(156)
Commodity derivatives		375	7,283
Liabilities:
Commodity derivatives		1,795	1,243
Commodity derivatives	[1]	0	(156)
Commodity derivatives		$ 1,795	$ 1,087
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Reconciliation of Company's Asset Retirement Obligations (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 21,497
Liabilities added from drilling	209
Liabilities associated with assets divested	(5,628)
Current year accretion expense	854
Settlements	(1,008)
Revision of estimates	299
Asset retirement obligations at end of period	$ 16,223

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Sep. 30, 2020
Loss Contingencies [Line Items]
Severance termination benefit		$ 10	$ 15
Omnibus Incentive Plan | Forecast
Loss Contingencies [Line Items]
Share-based compensation	$ 2
Severance termination benefit	$ 2

Operating Leases - Additional I

Operating Leases - Additional Information (Details) - USD ($)	3 Months Ended			9 Months Ended
	Jun. 30, 2020	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Lessor Lease Description [Line Items]
Operating lease expenses	$ 1,000,000		$ 1,000,000	$ 3,000,000	$ 3,000,000
Operating lease expiration year				2022
Total undiscounted lease payments				$ 4,255,000
Operating lease, Term of contract				2 years
Operating lease, Option to terminate term				1 year
Reduction in future minimum lease payment upon cancellation of lease				$ 734,000
Lease income		$ 1,000,000			$ 2,000,000
Blue Mountain Midstream
Lessor Lease Description [Line Items]
Total undiscounted lease payments				$ 3,000,000
Weighted-average remaining lease term				2 years

Operating Leases - Future Minim

Operating Leases - Future Minimum Lease Payments (Details) $ in Thousands	Sep. 30, 2020USD ($)
Leases [Abstract]
2020	$ 626
2021	2,333
2022	1,296
Total undiscounted lease payments	$ 4,255

Share-Based Compensation - Addi

Share-Based Compensation - Additional Information (Details) - USD ($)	3 Months Ended						9 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expenses for award outstanding, expected		$ 392,000		$ 2,832,000			$ (2,958,000)	$ 12,819,000
Percentage of parent's employee-related expenses							100.00%
Stock repurchased during period, value			$ 2,066,000	$ 65,353,000	$ 43,307,000	$ 34,437,000
Class A Units | LINN Energy
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based payment liability		$ 1,000,000					$ 1,000,000		$ 10,000,000
Class A Units | Blue Mountain Midstream
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common unit, issued		738,213					738,213
Class B Common Stock | Blue Mountain Midstream
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common unit, issued		0					0
Maximum | Class B Common Stock | Blue Mountain Midstream
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common unit, issued		58,750					58,750
Common Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock repurchased during period, shares			323,000	4,989,000	3,170,000	2,488,000
Stock repurchased during period, value			$ 3,000	$ 50,000	$ 32,000	$ 25,000
Issuance of common stock, shares			62,000			82,000
Restricted Stock Units (RSUs)
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							15,357
Stock repurchased during period, shares							100,956	132,632
Stock repurchased during period, value							$ 706,000	$ 2,000,000
Issuance of common stock, shares							61,645	81,923
Share-based compensation arrangement by share-based payment award, equity instruments other than options, vested in period, fair value							$ 125,000
Riviera Performance Shares
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							1,847,950
Blue Mountain Midstream Phantom Share Units
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							36,262
Omnibus Incentive Plan | Common Stock | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based compensation arrangement, shares/units available for issuance		451,757					451,757
Omnibus Incentive Plan | Restricted Stock Units (RSUs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares issuable under the plan		1,995,853					1,995,853
Share based compensation arrangement by share based payment award equity instruments other than options, grants in period							146,260
Omnibus Incentive Plan | Restricted Stock Units (RSUs) | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based compensation arrangement, shares/units available for issuance		361,799					361,799
Omnibus Incentive Plan | Riviera Performance Shares
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							1,847,950
Omnibus Incentive Plan | Riviera Performance Shares | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based compensation arrangement, shares/units available for issuance		89,958					89,958
Omnibus Incentive Plan | Forecast
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expenses for award outstanding, expected	$ 1,000,000
BMM Incentive Plan
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							36,262
BMM Incentive Plan | Class A Units | Linn Holdco II | Blue Mountain Midstream
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common stock, ownership percentage							100.00%
BMM Incentive Plan | Class B Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares issuable under the plan		45,272					45,272
BMM Incentive Plan | Restricted Stock Units (RSUs) | Class B Units
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							9,010
BMM Incentive Plan | Riviera Performance Shares | Class B Units
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							18,131

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Share-Based Compensation Expenses (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Share/unit-based compensation expenses	$ 392	$ 2,832	$ (2,958)	$ 12,819
Income tax benefit	0	0	0	0
Marketing expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Share/unit-based compensation expenses	0	54	(127)	216
General and Administrative Expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Share/unit-based compensation expenses	$ 392	$ 2,778	$ (2,831)	$ 12,603

Loss Per Share - Additional Inf

Loss Per Share - Additional Information (Details) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Restricted Stock Units (RSUs)
Earnings Per Share Basic [Line Items]
Anti dilutive restricted stock units	489,000	318,000	152,000	199,000

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Effective income tax rate reconciliation, percent	0.00%	(128.00%)	0.00%	(143.00%)
Income tax expense	$ 0	$ 126,646	$ 0	$ 129,092
Blended tax rate	25.00%		25.00%
Deferred tax assets, valuation allowance	$ 259,000		$ 259,000		$ 171,000
Operating loss carryforwards					$ 246,000

Supplemental Disclosures to t_3

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Schedule of Other Current Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Other current assets
Prepaids	$ 4,570	$ 9,152
Inventories	6,777	1,116
Receivables and other	578	2,585
Other current assets	$ 11,925	$ 12,853

Supplemental Disclosures to t_4

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Schedule of Accounts Payable and Accrued Expenses (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Accounts Payable and Accrued Expenses
Accounts payable	$ 27,040	$ 50,601
Accrued operating expenses	4,191	16,828
Accrued capital expenditures	711	10,087
Accrued general and administrative expenses	2,214	2,448
Other accrued expenses	751	615
Accounts payable and accrued expenses	$ 34,907	$ 80,579

Supplemental Disclosures to t_5

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Schedule of Other Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Other accrued liabilities
Accrued compensation	$ 16,743	$ 11,314
Asset retirement obligations (current portion)	1,184	1,184
Deposits	13,765	6,111
Other	84	8,119
Other accrued liabilities	$ 31,776	$ 26,728

Supplemental Disclosures to t_6

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Schedule of Reconciliation of Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Cash Cash Equivalents Restricted Cash And Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	$ 94,548	$ 116,237
Restricted cash	24,887	32,932
Cash, cash equivalents and restricted cash	$ 119,435	$ 149,169	$ 128,918	$ 49,777

Supplemental Disclosures to t_7

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Supplemental Disclosures To The Condensed Consolidated Statements Of Cash Flows [Abstract]
Cash payments for interest, net of amounts capitalized	$ 1,670	$ 2,941
Cash payments for income taxes	0	0
Cash payments for reorganization items, net	721	756
Noncash investing activities:
Accrued capital expenditures	$ 711	$ 6,593

Supplemental Disclosures to t_8

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows - Additional Information (Details) - USD ($) $ in Thousands	2 Months Ended
	Feb. 28, 2017	Sep. 30, 2020	Dec. 31, 2019
Schedule Of Supplemental Cash Flow Disclosures [Line Items]
Increase (Decrease) in Restricted Cash for Operating Activities	$ 80,000
Restricted cash		$ 24,887	$ 32,932
Professional fees
Schedule Of Supplemental Cash Flow Disclosures [Line Items]
Restricted cash		10,000	16,000
Deposits for divestitures
Schedule Of Supplemental Cash Flow Disclosures [Line Items]
Restricted cash		14,000	6,000
Potential future distributions for nonvested share-based compensation awards
Schedule Of Supplemental Cash Flow Disclosures [Line Items]
Restricted cash		$ 1,000	$ 11,000

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Related Party Transaction [Line Items]
Revenues	$ 36,423	$ 102,389	$ 117,981	$ 377,385
Roan Resources LLC
Related Party Transaction [Line Items]
Revenues		9,000		17,000
Related party transaction, purchases from related party		$ 19,000		$ 78,000

Segments - Additional Informati

Segments - Additional Information (Details)	9 Months Ended
	Sep. 30, 2020Segment
Segment Reporting [Abstract]
Number of reportable segments	2

Segments - Schedule of Segment

Segments - Schedule of Segment Reporting Information, by Segment (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Revenues	$ 36,423	$ 102,389	$ 117,981	$ 377,385
Lease operating expenses	2,367	18,307	10,212	66,204
Transportation expenses	818	16,275	4,201	53,478
Marketing expenses	20,284	37,688	58,431	132,888
Taxes, other than income taxes	846	5,111	3,436	14,010
Total direct operating expenses	24,315	77,381	76,280	266,580
Field level cash flow	12,108	25,008	41,701	110,805
Gains (losses) on commodity derivatives	(2,948)	5,665	3,773	12,673
Other indirect income (expenses), net	(245,539)	(129,662)	(404,571)	(213,971)
Loss before income taxes	(236,379)	(98,989)	(359,097)	(90,493)
Upstream
Segment Reporting Information [Line Items]
Revenues	7,482	67,656	35,952	257,680
Lease operating expenses	2,367	18,307	10,212	66,204
Transportation expenses	818	16,275	4,201	53,478
Marketing expenses	6	7,948	70	35,568
Taxes, other than income taxes	421	4,468	2,142	11,984
Total direct operating expenses	3,612	46,998	16,625	167,234
Field level cash flow	3,870	20,658	19,327	90,446
Gains (losses) on commodity derivatives	(2,948)	5,991	3,307	12,830
Other indirect income (expenses), net	(19,602)	(122,419)	(151,087)	(188,113)
Loss before income taxes	(18,680)	(95,770)	(128,453)	(84,837)
Blue Mountain
Segment Reporting Information [Line Items]
Revenues	28,941	34,733	82,029	119,705
Lease operating expenses		0		0
Transportation expenses		0		0
Marketing expenses	20,278	29,740	58,361	97,320
Taxes, other than income taxes	425	643	1,294	2,026
Total direct operating expenses	20,703	30,383	59,655	99,346
Field level cash flow	8,238	4,350	22,374	20,359
Gains (losses) on commodity derivatives		(326)	466	(157)
Other indirect income (expenses), net	(225,937)	(7,243)	(253,484)	(25,858)
Loss before income taxes	(217,699)	(3,219)	(230,644)	(5,656)
Oil, Natural Gas and NGL Sales
Segment Reporting Information [Line Items]
Revenues	7,340	51,029	33,072	194,131
Oil, Natural Gas and NGL Sales | Upstream
Segment Reporting Information [Line Items]
Revenues	7,340	51,029	33,072	194,131
Oil, Natural Gas and NGL Sales | Blue Mountain
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Marketing
Segment Reporting Information [Line Items]
Revenues	29,054	45,828	84,840	166,569
Marketing | Upstream
Segment Reporting Information [Line Items]
Revenues	113	11,095	2,811	46,864
Marketing | Blue Mountain
Segment Reporting Information [Line Items]
Revenues	28,941	34,733	82,029	119,705
Other Revenues
Segment Reporting Information [Line Items]
Revenues	29	5,532	69	16,685
Other Revenues | Upstream
Segment Reporting Information [Line Items]
Revenues	29	5,532	69	16,685
Other Revenues | Blue Mountain
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 0	$ 0

Plan of Liquidation, Winding _3

Plan of Liquidation, Winding Up and Dissolution - Additional Information (Details) $ in Millions	Sep. 30, 2020USD ($)
Minimum
Liquidating distributions payable to shareholders	$ 0
Maximum
Liquidating distributions payable to shareholders	$ 40

Plan of Liquidation, Winding _4

Plan of Liquidation, Winding Up and Dissolution - Summarized Balance Sheet of Blue Mountain and Mid-Continent Divestiture (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
ASSETS
Current assets	$ 153,929	$ 325,433
Oil and natural gas properties, net	13,909	144,704
Other property and equipment, net	104,033	338,470
Other noncurrent assets	4,690	7,652
Total assets	276,561	816,259
Liabilities:
Current liabilities	68,478	143,571
Asset retirement obligations and other noncurrent liabilities	16,209	$ 29,337
Blue Mountain and Mid-Continent Divestiture
ASSETS
Current assets	161,343
Oil and natural gas properties, net	2,584
Other property and equipment, net	525
Other noncurrent assets	1,062
Total assets	165,514
Liabilities:
Current liabilities	52,117
Asset retirement obligations and other noncurrent liabilities	1,201
Liabilities	$ 53,318

Plan of Liquidation, Winding _5

Plan of Liquidation, Winding Up and Dissolution - Summarized Statement of Operation of Blue Mountain and Mid-Continent Divestiture (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	$ 33,475	$ 108,054	$ 121,754	$ 390,058
Expenses	268,635	203,835	476,462	473,684
Other income (expenses)	(1,009)	(2,924)	(3,685)	(6,111)
Income tax expense	0	126,646	0	129,092
Blue Mountain and Mid-Continent Divestiture
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues and other	(2,024)	158,806	21,028	237,137
Expenses	18,077	232,370	60,736	324,490
Other income (expenses)	(360)	(3,487)	(1,839)	(4,992)
Loss from continuing operations before income taxes	(20,461)	(77,051)	(41,547)	(92,345)
Income tax expense	0	125,639	0	123,592
Loss from continuing operations	$ (20,461)	$ (202,690)	$ (41,547)	$ (215,937)