Harvest Oil & Gas (HRST) 10-Q 14 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Nov. 08, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Entity Registrant Name	Harvest Oil & Gas Corp.
Entity Central Index Key	0001361937
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		10,179,379

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 98,348	$ 6,313
Equity securities		47,082
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	21,538	40,176
Other	481	4,496
Derivative asset	8,745	15,452
Other current assets	406	2,314
Total current assets	129,518	115,833
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; September 30, 2019, $19,362; December 31, 2018, $12,950	142,471	405,688
Assets held for sale	9,284
Long–term derivative asset	1,933	8,499
Other assets	6,679	4,474
Total assets	289,885	534,494
Current liabilities:
Accounts payable and accrued liabilities	24,143	26,146
Derivative liability		1,165
Other current liabilities	684
Total current liabilities	24,827	27,311
Asset retirement obligations	101,374	117,529
Long-term debt, net		115,000
Liabilities held for sale	2,759
Other long–term liabilities	1,638	1,036
Commitments and contingencies (Note 11)
Mezzanine equity	135	79
Stockholders’ equity:
Common stock – $0.01 par value; 65,000,000 shares authorized; 10,213,888 shares issued and 10,179,379 shares outstanding as of September 30, 2019; 10,054,816 shares issued and 10,042,468 shares outstanding as of December 31, 2018	102	100
Additional paid-in capital	251,834	249,717
Treasury stock at cost – 34,509 shares at September 30, 2019; 12,348 shares at December 31, 2018	(542)	(247)
Retained earnings (accumulated deficit)	(92,242)	23,969
Total stockholders’ equity	159,152	273,539
Total liabilities and equity	$ 289,885	$ 534,494

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$ 19,362	$ 12,950
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	65,000,000	65,000,000
Common stock, shares issued	10,213,888	10,054,816
Common stock, shares, outstanding	10,179,379	10,042,468
Treasury stock, shares	34,509	12,348

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019
Revenues:
Total revenues	$ 23,249	$ 68,966	$ 90,686		$ 97,682
Operating costs and expenses:
Lease operating expenses	19,614	28,281	37,656		64,568
Cost of purchased natural gas	255	393	522		969
Dry hole and exploration costs	36	21	64		75
Production taxes	1,634	2,973	3,943		5,277
Accretion expense on obligations	1,995	2,345	3,134		6,373
Depreciation, depletion and amortization	1,367	7,860	10,590		10,712
General and administrative expenses	7,771	7,673	9,702		20,794
Impairment of oil and natural gas properties	16,325	2,565	2,565		115,604
(Gain) loss on sales of oil and natural gas properties	(661)	(28)	(47)		(679)
Total operating costs and expenses	48,336	52,083	68,129		223,693
Operating income (loss)	(25,087)	16,883	22,557		(126,011)
Other income (expense), net:
Gain (loss) on derivatives, net	5,718	(26,423)	(30,655)		5,374
Interest expense	(501)	(3,967)	(5,166)		(3,335)
Gain on equity securities		4,830	4,830		4,593
Other income (expense), net	341	(111)	(84)		3,168
Total other income (expense), net	5,558	(25,671)	(31,075)		9,800
Reorganization items, net		(972)	(1,780)
Loss before income taxes	(19,529)	(9,760)	(10,298)		(116,211)
Net loss	$ (19,529)	$ (9,760)	$ (10,298)		$ (116,211)
Basic and diluted earnings per share:
Net loss	$ (1.93)	$ (0.97)	$ (1.03)		$ (11.53)
Weighted average common shares / units outstanding:
Basic, share/unit	10,131	10,028	10,021		10,080
Diluted, share/unit	10,131	10,028	10,021		10,080
Oil, natural gas and natural gas liquids revenues
Revenues:
Total revenues	$ 22,870	$ 68,407	$ 89,942		$ 96,285
Transportation and marketing–related revenues
Revenues:
Total revenues	$ 379	$ 559	$ 744		$ 1,397
Predecessor [Member]
Revenues:
Total revenues				$ 111,031
Operating costs and expenses:
Lease operating expenses				45,372
Cost of purchased natural gas				557
Dry hole and exploration costs				122
Production taxes				5,343
Accretion expense on obligations				3,176
Depreciation, depletion and amortization				46,196
General and administrative expenses				15,648
Restructuring costs				5,211
Impairment of oil and natural gas properties				3
(Gain) loss on sales of oil and natural gas properties				5
Total operating costs and expenses				121,633
Operating income (loss)				(10,602)
Other income (expense), net:
Gain (loss) on derivatives, net				444
Interest expense				(13,652)
Other income (expense), net				776
Total other income (expense), net				(12,432)
Reorganization items, net				(587,325)
Loss before income taxes				(610,359)
Income tax benefit (expense)				(166)
Net loss				$ (610,525)
Basic and diluted earnings per share:
Net loss				$ (12.12)
Weighted average common shares / units outstanding:
Basic, share/unit				49,369
Diluted, share/unit				49,369
Predecessor [Member] | Oil, natural gas and natural gas liquids revenues
Revenues:
Total revenues				$ 110,307
Predecessor [Member] | Transportation and marketing–related revenues
Revenues:
Total revenues				$ 724

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Stockholders' Equity - USD ($) shares in Thousands, $ in Thousands	Senior Note Holders [Member]Common Stock [Member]	Senior Note Holders [Member]Additional Paid-in Capital [Member]	Senior Note Holders [Member]	Predecessor Unit Holders [Member]Common Stock [Member]	Predecessor Unit Holders [Member]Additional Paid-in Capital [Member]	Predecessor Unit Holders [Member]	Common Unitholders	General Partner Interest	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings (Accumulated Deficit) [Member]	Total
Beginning Balance (Predecessor [Member]) at Dec. 31, 2017							$ 648,371	$ (20,359)					$ 628,012
Net loss | Predecessor [Member]							(15,140)	(309)					(15,449)
Equity-based compensation | Predecessor [Member]							575	12					587
Ending Balance (Predecessor [Member]) at Mar. 31, 2018							633,806	(20,656)					613,150
Beginning Balance (Predecessor [Member]) at Dec. 31, 2017							648,371	(20,359)					628,012
Net loss | Predecessor [Member]													(610,525)
Ending Balance at May. 31, 2018									$ 100	$ 248,578			248,678
Ending Balance (in shares) at May. 31, 2018									10,000
Beginning Balance (Predecessor [Member]) at Mar. 31, 2018							633,806	(20,656)					613,150
Contributions from general partner | Predecessor [Member]								40					40
Issuance of common stock to Predecessor common unitholders | Predecessor [Member]							(11,967)						(11,967)
Issuance of warrants to Predecessor common unitholders | Predecessor [Member]							(9,345)						(9,345)
Cancellation of Predecessor common unitholders | Predecessor [Member]							(32,453)						(32,453)
Cancellation of Predecessor general partner interest | Predecessor [Member]								32,454					32,454
Issuance of successor commons stock to predecessor equity	9,500			500
Issuance of successor commons stock to predecessor equity, value	$ 95	$ 227,271	$ 227,366	$ 5	$ 11,962	$ 11,967
Issuance of warrants										9,345			9,345
Net loss | Predecessor [Member]							(583,174)	(11,902)					(595,076)
Equity-based compensation | Predecessor [Member]							$ 3,133	$ 64					3,197
Ending Balance at May. 31, 2018									$ 100	248,578			248,678
Ending Balance (in shares) at May. 31, 2018									10,000
Net loss												$ (538)	(538)
Ending Balance at Jun. 30, 2018									$ 100	248,578		(538)	248,140
Ending Balance (in shares) at Jun. 30, 2018									10,000
Beginning Balance at May. 31, 2018									$ 100	248,578			248,678
Beginning Balance (in shares) at May. 31, 2018									10,000
Net loss													(10,298)
Ending Balance at Sep. 30, 2018									$ 100	249,672	$ (247)	(10,298)	239,227
Ending Balance (in shares) at Sep. 30, 2018									10,043
Beginning Balance at Jun. 30, 2018									$ 100	248,578		(538)	248,140
Beginning Balance (in shares) at Jun. 30, 2018									10,000
Net loss												(9,760)	(9,760)
Share-based compensation										1,094			1,094
Restricted shares vested									$ 55
Purchase of treasury stock											(247)		(247)
Purchase of treasury stock (in shares)									(12)
Ending Balance at Sep. 30, 2018									$ 100	249,672	(247)	(10,298)	239,227
Ending Balance (in shares) at Sep. 30, 2018									10,043
Beginning Balance at Dec. 31, 2018									$ 100	249,717	(247)	23,969	273,539
Beginning Balance (in shares) at Dec. 31, 2018									10,043
Net loss												(35,775)	(35,775)
Share-based compensation										61			61
Ending Balance at Mar. 31, 2019									$ 100	249,778	(247)	(11,806)	237,825
Ending Balance (in shares) at Mar. 31, 2019									10,043
Beginning Balance at Dec. 31, 2018									$ 100	249,717	(247)	23,969	273,539
Beginning Balance (in shares) at Dec. 31, 2018									10,043
Net loss													(116,211)
Ending Balance at Sep. 30, 2019									$ 102	251,834	(542)	(92,242)	159,152
Ending Balance (in shares) at Sep. 30, 2019									10,179
Beginning Balance at Mar. 31, 2019									$ 100	249,778	(247)	(11,806)	237,825
Beginning Balance (in shares) at Mar. 31, 2019									10,043
Net loss												(60,907)	(60,907)
Share-based compensation										637			637
Restricted shares vested									$ 1	(1)
Restricted shares vested (in shares)									87
Purchase of treasury stock											(167)		(167)
Purchase of treasury stock (in shares)									(12)
Ending Balance at Jun. 30, 2019									$ 101	250,414	(414)	(72,713)	177,388
Ending Balance (in shares) at Jun. 30, 2019									10,118
Net loss												(19,529)	(19,529)
Share-based compensation										1,421			1,421
Restricted shares vested									$ 1	(1)
Restricted shares vested (in shares)									72
Purchase of treasury stock											(128)		(128)
Purchase of treasury stock (in shares)									(11)
Ending Balance at Sep. 30, 2019									$ 102	$ 251,834	$ (542)	$ (92,242)	$ 159,152
Ending Balance (in shares) at Sep. 30, 2019									10,179

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019
Cash flows from operating activities:
Net loss	$ (10,298)		$ (116,211)
Adjustments to reconcile net loss to net cash flows provided by operating activities:
Accretion expense on obligations	3,134		6,373
Depreciation, depletion and amortization	10,590		10,712
Share-based compensation cost	1,144		2,184
Impairment of oil and natural gas properties	2,565		115,604
(Gain) loss on sales of oil and natural gas properties	(47)		(679)
Gain on equity securities	(4,830)		(4,593)
(Gain) loss on derivatives, net	30,655		(5,374)
Cash settlements of derivative contracts	(1,847)		17,483
Other	780		1,571
Changes in operating assets and liabilities:
Accounts receivable	(2,014)		21,637
Other current assets	314		1,909
Accounts payable and accrued liabilities	(4,183)		(4,061)
Other, net	(38)		(2,531)
Net cash flows provided by operating activities	25,925		44,024
Cash flows from investing activities:
Additions to oil and natural gas properties	(22,307)		(2,096)
Reimbursements related to oil and natural gas properties	1,091		2,124
Proceeds from sale of oil and natural gas properties	136,483		111,575
Proceeds from sale of equity securities			51,675
Other	16		38
Net cash flows provided by (used in) investing activities	115,283		163,316
Cash flows from financing activities:
Repayment of long–term debt borrowings	(164,000)		(115,000)
Purchase of treasury stock	(247)		(295)
Other			(10)
Net cash flows provided by (used in) financing activities	(164,247)		(115,305)
Increase (decrease) in cash, cash equivalents and restricted cash	(23,039)		92,035
Cash, cash equivalents and restricted cash - beginning of period	28,732		6,313
Cash, cash equivalents and restricted cash - end of period	5,693	$ 28,732	$ 98,348
Predecessor [Member]
Cash flows from operating activities:
Net loss		(610,525)
Adjustments to reconcile net loss to net cash flows provided by operating activities:
Accretion expense on obligations		3,176
Depreciation, depletion and amortization		46,196
Share-based compensation cost		3,784
Impairment of oil and natural gas properties		3
(Gain) loss on sales of oil and natural gas properties		5
(Gain) loss on derivatives, net		(444)
Cash settlements of derivative contracts		3,099
Reorganization items, net		573,304
Other		248
Changes in operating assets and liabilities:
Accounts receivable		(3,518)
Other current assets		1,853
Accounts payable and accrued liabilities		4,405
Other, net		69
Net cash flows provided by operating activities		21,655
Cash flows from investing activities:
Additions to oil and natural gas properties		(29,727)
Reimbursements related to oil and natural gas properties		652
Proceeds from sale of oil and natural gas properties		3
Other		26
Net cash flows provided by (used in) investing activities		(29,046)
Cash flows from financing activities:
Long-term debt borrowings		34,000
Loan costs incurred		(2,813)
Contributions from general partner		40
Net cash flows provided by (used in) financing activities		31,227
Increase (decrease) in cash, cash equivalents and restricted cash		23,836
Cash, cash equivalents and restricted cash - beginning of period	$ 28,732	4,896
Cash, cash equivalents and restricted cash - end of period		$ 28,732

ORGANIZATION AND NATURE OF BUSI

ORGANIZATION AND NATURE OF BUSINESS	9 Months Ended
	Sep. 30, 2019
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
ORGANIZATION AND NATURE OF BUSINESS	NOTE 1. ORGANIZATION AND NATURE OF BUSINESS Nature of Operations Harvest Oil & Gas Corp., a Delaware corporation, is the successor reporting company to EV Energy Partners, L.P. (“EVEP”) pursuant to Rule 15d‑5 of the Securities Exchange Act of 1934, as amended. As used herein, the terms “Successor”, “Harvest”, or the “Company” refer to Harvest Oil & Gas Corp. and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. When referring to the “Predecessor” or the “Partnership” in reference to the period prior to the emergence from bankruptcy, the intent is to refer to EVEP, the predecessor that was dissolved following the Effective Date (as defined below) of the Plan (as defined below) and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. Unless the context requires otherwise, references to: (i) the “Predecessor’s general partner” and “EV Energy GP” refer to EV Energy GP, L.P., a Delaware limited partnership, the Predecessor’s general partner, which was dissolved following the Effective Date of the Plan; (ii) “EV Management” refers to EV Management, LLC, a Delaware limited liability company, the former general partner of the Predecessor’s general partner; and (iii) “EnerVest” refers to EnerVest, Ltd., a Texas limited partnership, the owner of EV Management. Harvest is an independent oil and natural gas company that was formed in 2018, in connection with the reorganization of the Predecessor. The Predecessor was publicly traded from September 2006 to June 2018. As discussed further in Note 2, on April 2, 2018, EVEP and 13 affiliated debtors (collectively, the “Debtors”) each filed a voluntary petition (the cases commenced thereby, the “Chapter 11 proceedings”) for relief under Chapter 11 of Title 11 of the United States Bankruptcy Code (“Chapter 11”) for bankruptcy protection in the United States Bankruptcy Court for the District of Delaware (the “Bankruptcy Court”) via Case No. 18‑10814. The Debtors requested that their cases be jointly administered under Case No. 18‑10814 to pursue the prepackaged plan of reorganization. During the pendency of the Chapter 11 proceedings, EVEP continued to operate its businesses and manage its properties under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code and orders of the Bankruptcy Court as a “Debtors-in-Possession”. On May 17, 2018, the Bankruptcy Court entered an order (the “Confirmation Order”) confirming the Debtors’ First Modified Joint Prepackaged Plan of Reorganization (as amended, modified and supplemented from time to time, the “Plan”). The Plan became effective on June 4, 2018 (the “Effective Date”), when all remaining conditions to the effectiveness of the Plan were satisfied and the Company emerged from bankruptcy. The Company operates one reportable segment engaged in the development and production of oil and natural gas properties, and all of its operations are located in the United States. As a result of the ongoing review of the Company’s asset base in order to maximize shareholder value, the Company has divested, and is in the process of divesting, certain assets and, in the future, may look to divest additional assets or all of its remaining assets and use the proceeds to return capital to shareholders. As of September 30, 2019, the oil and natural gas properties of Harvest are located in the Barnett Shale, the Appalachian Basin (which includes the Utica Shale), Michigan, the Mid–Continent areas in Oklahoma, Texas, Kansas and Louisiana, the Permian Basin and the Monroe Field in Northern Louisiana. Basis of Presentation The Company’s unaudited condensed consolidated financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Accordingly, certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted. The Company believes that the presentations and disclosures herein are adequate to make the information not misleading. The unaudited condensed consolidated financial statements reflect all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the interim periods. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year. These interim financial statements should be read in conjunction with the audited consolidated financial statements and the related notes included in Harvest’s Annual Report on Form 10–K for the year ended December 31, 2018. All intercompany accounts and transactions have been eliminated in consolidation. In the Notes to Unaudited Condensed Consolidated Financial Statements, all dollar, share and unit amounts in tabulations are in thousands of dollars, shares and units, respectively, unless otherwise indicated. Bankruptcy Accounting The unaudited condensed consolidated financial statements have been prepared as if the Company is a going concern and reflect the application of Accounting Standards Codification 852 Reorganizations (“ASC 852”). ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 filing, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Accordingly, certain expenses, gains and losses that were realized or incurred related to the bankruptcy proceedings are recorded in “Reorganization items, net” on the Company’s condensed consolidated statements of operations. The following table summarizes the components of reorganization items, net included in the accompanying unaudited condensed consolidated statements of operations: Successor Predecessor Three Months Nine Months Three Months Four Months Five Months Ended Ended Ended Ended Ended September 30, September 30, September 30, September 30, May 31, 2019 2019 2018 2018 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ — $ 128,700 Fresh start valuation adjustments — — — — (700,325) Professional fees — — (972) (1,780) (13,345) Other — — — — (2,355) Reorganization items, net $ — $ — $ (972) $ (1,780) $ (587,325) Upon emergence from bankruptcy on June 4, 2018, the Company elected to adopt and apply the relevant guidance provided in GAAP with respect to the accounting and financial statement disclosures for entities that have emerged from Chapter 11 (“fresh start accounting”) effective May 31, 2018 to coincide with the timing of the Company’s normal accounting period close. As a result of the application of fresh start accounting and the effects of the implementation of the plan of reorganization, the condensed consolidated financial statements as of or after May 31, 2018 are not comparable with the condensed consolidated financial statements prior to that date. To facilitate the financial statement presentations, the Company refers to the reorganized company in these unaudited condensed consolidated financial statements and notes as the “Successor” for periods subsequent to May 31, 2018 and “Predecessor” for periods prior to June 1, 2018. Furthermore, the unaudited condensed consolidated financial statements and notes have been presented with a “black line” division to delineate the lack of comparability between the Predecessor and Successor. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and judgments that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates and judgments on historical experience and on various other assumptions and information that are believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be perceived with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the Company’s operating environment changes. While Harvest believes that the estimates and assumptions used in the preparation of the unaudited condensed consolidated financial statements are appropriate, actual results could differ from those estimates. New Accounting Standards In February 2016, the Financial Accounting Standards Board (the “FASB”) issued ASU No. 2016‑02, Leases (Topic 842) (“ASU 2016-02”). The main objective of ASU 2016‑02 is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The main difference between previous GAAP and Topic 842 is the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. ASU 2016‑02 requires lessees to recognize assets and liabilities arising from leases on the balance sheet. ASU 2016‑02 further defines a lease as a contract that conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Control over the use of the identified asset means that the customer has both (1) the right to obtain substantially all of the economic benefit from the use of the asset and (2) the right to direct the use of the asset. ASU 2016‑02 requires disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. In January 2018, the FASB issued ASU 2018‑01, Leases (Topic 842), Land Easement Practical Expedient for Transition to Topic 842 (“ASU 2018‑01”), which permits an entity an optional election to not evaluate under ASU 2016‑02 those existing or expired land easements that were not previously accounted for as leases prior to the adoption of ASU 2016‑02. In July 2018, the FASB issued ASU 2018‑11, Leases (Topic 842), Targeted Improvements (“ASU 2018‑11”), which permits an entity (i) to apply the provisions of ASU 2016‑02 at the adoption date instead of the earliest period presented in the financial statements, and, as a lessor, (ii) to account for lease and nonlease components as a single component as the nonlease components would otherwise be accounted for under the provisions of ASU 2014‑09. The Company adopted this new standard as of January 1, 2019 using a modified retrospective approach. The Company elected the package of practical expedients within ASU 2016‑02 that allows an entity to not reassess prior to the effective date (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification for any expired or existing leases or (iii) initial direct costs for any existing leases. Additionally, the Company elected the practical expedient under ASU 2018‑01 that allows an entity to not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date. The adoption of this standard resulted in an increase in the assets and liabilities on the Company’s unaudited condensed consolidated balance sheet. The quantitative impacts of the new standard were dependent on the leases in force at the time of adoption. The adoption of this ASU did not have a material impact on the Company’s unaudited condensed consolidated financial statements. See Note 10 for additional details about the impact upon adoption and related disclosures. No other new accounting pronouncements issued or effective during the nine months ended September 30, 2019 have had or are expected to have a material impact on the unaudited condensed consolidated financial statements other than those disclosed in Harvest’s Annual Report on Form 10‑K for the year ended December 31, 2018. Subsequent Events The Company evaluated subsequent events for appropriate accounting and disclosure through the date these unaudited condensed consolidated financial statements were issued.

EMERGENCE FROM VOLUNTARY REORGA

EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11	9 Months Ended
	Sep. 30, 2019
EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11 [Abstract]
EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11	NOTE 2. EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11 On March 13, 2018, the Debtors entered into a Restructuring Support Agreement (the “Restructuring Support Agreement”) with (i) holders of approximately 70% of the 8.0% senior unsecured notes due April 2019 (the “Senior Notes”) issued pursuant to that certain indenture, dated as of March 22, 2011 (as amended, restated, supplemented or otherwise modified from time to time, the “Indenture”), among EVEP, EV Energy Finance Corp., each of the guarantors party thereto, and Delaware Trust Company, as indenture trustee, that are signatories to the Restructuring Support Agreement; (ii) lenders under the Predecessor’s reserve-based lending facility, by and among EVEP, EV Properties, L.P., JPMorgan Chase Bank, N.A., as administrative agent, BNP Paribas and Wells Fargo, National Association, as co-syndication agents, the guarantors party thereto, that are signatory thereto, constituting approximately 94% of the principal amount outstanding thereunder; (iii) EnerVest; and (iv) EnerVest Operating, L.L.C. (“EnerVest Operating”). The Restructuring Support Agreement set forth, subject to certain conditions, the commitment of the Debtors and the consenting creditors to support a comprehensive restructuring of the Debtors’ long-term debt (the “Restructuring”). On April 2, 2018, the Debtors each filed Chapter 11 proceedings for relief under Chapter 11 in the Bankruptcy Court. The Debtors’ Chapter 11 proceedings were jointly administered under the caption In re EV Energy Partners, L.P., et al ., Case No. 18-10814. On May 17, 2018, the Bankruptcy Court entered the Confirmation Order confirming the Debtors’ Plan. On June 4, 2018, the Debtors satisfied the conditions to effectiveness of the Plan, the Plan became effective in accordance with its terms and the Company emerged from bankruptcy.

REVENUE

REVENUE	9 Months Ended
	Sep. 30, 2019
REVENUE [Abstract]
REVENUE	NOTE 3. REVENUE Revenue from contracts with customers includes the sale of oil, natural gas and natural gas liquids production (recorded in “Oil, natural gas and natural gas liquids revenues” in the unaudited condensed consolidated statements of operations) and gathering and transportation revenues (recorded in “Transportation and marketing-related revenues” in the unaudited condensed consolidated statements of operations). The following table disaggregates revenue by significant product and service type: Successor Three Months Three Months Ended Ended September 30, 2019 September 30, 2018 Oil $ 7,856 $ 23,254 Natural gas (1) 11,713 26,494 Natural gas liquids (1) 3,301 18,659 Oil, natural gas and natural gas liquids revenues 22,870 68,407 Transportation and marketing–related revenues 379 559 Total revenues $ 23,249 $ 68,966 Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Oil $ 25,365 $ 30,415 $ 42,460 Natural gas (1) 52,055 35,158 40,951 Natural gas liquids (1) 18,865 24,369 26,896 Oil, natural gas and natural gas liquids revenues 96,285 89,942 110,307 Transportation and marketing–related revenues 1,397 744 724 Total revenues $ 97,682 $ 90,686 $ 111,031 (1) The Company recognizes wet gas revenues, which are recorded net of transportation, gathering and processing expenses, partially as natural gas revenues and partially as natural gas liquids revenues based on the end products after processing occurs. For the Successor period of the three months ended September 30, 2019, wet gas revenues were $0.3 million which were recognized as natural gas liquids revenues. For the Successor period of the nine months ended September 30, 2019, wet gas revenues were $4.1 million which were recognized as $1.5 million of natural gas revenues and $2.6 million of natural gas liquids revenues. For the Successor period of the three months ended September 30, 2018, wet gas revenues were $5.9 million which were recognized as $2.0 million of natural gas revenues and $3.9 million of natural gas liquids revenues. For the Successor period of the four months ended September 30, 2018, wet gas revenues were $7.4 million which were recognized as $2.5 million of natural gas revenues and $4.9 million of natural gas liquids revenues. For the Predecessor period of the five months ended May 31, 2018, wet gas revenues were $8.4 million which were recognized as $3.2 million of natural gas revenues and $5.2 million of natural gas liquids revenues. Contract Balances Customers are invoiced once the Company’s performance obligations have been satisfied. Payment terms and conditions vary by contract type, although terms generally include a requirement of payment within 30 days. There are no significant judgments that significantly affect the amount or timing of revenue from contracts with customers. Accordingly, the Company’s product sales contracts do not give rise to material contract assets or contract liabilities. Accounts receivable are primarily from purchasers of oil, natural gas and natural gas liquids. As of September 30, 2019 and December 31, 2018, the Company had receivables of $21.5 million and $38.3 million, respectively. This industry concentration could affect overall exposure to credit risk, either positively or negatively, because the Company’s purchasers may be similarly affected by changes in economic, industry or other conditions. The Company routinely assesses the financial strength of its customers and bad debts are recorded based on an account-by-account review specifically identifying receivables that the Company believes may be uncollectible after all means of collection have been exhausted, and the potential recovery is considered remote. As of September 30, 2019 and December 31, 2018, the Company did not have any reserves for doubtful accounts. Performance Obligations The Company applies the optional exemptions in Topic 606 and does not disclose consideration for remaining performance obligations with an original expected duration of one year or less or for variable consideration related to unsatisfied performance obligations.

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2019
SHARE-BASED COMPENSATION [Abstract]
SHARE-BASED COMPENSATION	NOTE 4. SHARE–BASED COMPENSATION During the nine months ended September 30, 2019, the Company granted 322,172 shares of restricted stock under the Company’s 2018 Omnibus Incentive Plan (the “2018 Plan”). Of the shares of restricted stock granted during the nine months ended September 30, 2019, 150,000 shares are subject to a graded vesting over a three year period; 59,728 shares are subject to future events, such as divestitures; 30,188 shares vested during the three months ended June 30, 2019 as a result of the closing of the San Juan divestiture; 72,384 shares vested during the three months ended September 30, 2019 as a result of the closing of the Barnett and Mid-Continent divestitures; and 9,872 shares are scheduled to vest on June 5, 2020. The weighted average fair value of the restricted shares granted during the nine months ended September 30, 2019 was $15.24 with a total fair value of approximately $4.9 million. No shares were forfeited during the nine months ended September 30, 2019. Approximately 0.3 million shares remain available for grant under the 2018 Plan as of September 30, 2019. The Company recognized compensation cost related to outstanding restricted stock units of $1.4 million and $2.1 million for the three and nine months ended September 30, 2019, respectively. These costs are included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations. As of September 30, 2019, there was $2.0 million of total unrecognized compensation cost related to unvested time-based restricted stock units, which is expected to be recognized over a weighted average period of 1.6 years. As of September 30, 2019, there was also $0.9 million of total unrecognized compensation cost related to unvested restricted stock units with vesting subject to future events, which will not be recognized until those future events are probable. Series A Preferred Stock The Company estimated the fair value of the 21,000 shares of the 8% Cumulative Nonparticipating Redeemable Series A Preferred Stock (the “Series A Preferred Stock”) as of June 30, 2019 at $0.2 million. The redemption amount of these shares of Series A Preferred Stock is $0.2 million. The 21,000 shares of Series A Preferred Stock vested during June 2019. During the nine months ended September 30, 2019, the Company recognized $65 thousand of compensation cost related to the Series A Preferred Stock. These costs are included in “General and administrative expenses” in the unaudited condensed consolidated statement of operations. Predecessor Equity-Based Compensation EV Management had two long-term incentive plans, the 2006 Long-Term Incentive Plan and the 2016 Long-Term Incentive Plan for employees, consultants and directors of EV Management and its affiliates who performed services for EVEP. Equity–based awards under these plans consisted only of phantom units during the five months ended May 31, 2018. The Predecessor recognized compensation cost related to these phantom units of $3.8 million for the five months ended May 31, 2018. These costs are included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations.

DIVESTITURES

DIVESTITURES	9 Months Ended
	Sep. 30, 2019
DIVESTITURES [Abstract]
DIVESTITURES	NOTE 5. DIVESTITURES During January 2019, the Company sold all of its 4.2 million shares of common stock of Magnolia Oil & Gas Corporation (NYSE: MGY) (“Magnolia”) for net proceeds of $51.7 million. In January 2019, the Company closed on the sale of certain oil and gas properties in the Mid-Continent area to a third party for total consideration of $1.8 million, net of purchase price adjustments. The Company did not record a gain, loss or impairment related to this sale. In April 2019, the Company closed on the sale of its (i) oil and gas properties in the San Juan Basin and (ii) membership interests in EnerVest Mesa, LLC, a wholly-owned subsidiary of EV Properties, L.P., to a third party for total consideration of $36.9 million, net of preliminary purchase price adjustments. The transaction had an effective date of October 1, 2018. The Company recognized an impairment of $25.3 million for these properties during the nine months ended September 30, 2019. Also, during the second quarter of 2019, the Company closed on the sale of certain oil and gas properties in the Mid-Continent area to a third party for total consideration of $2.3 million, net of preliminary purchase price adjustments, which included $0.9 million of preferential rights to purchase that were exercised by other working interest owners. The transaction, excluding the preferential rights, closed in April 2019 and had an effective date of October 1, 2018. The sale of the assets associated with the preferential rights closed in June 2019. The Company recognized an impairment of $1.7 million for these properties during the nine months ended September 30, 2019. In July 2019, the Company entered into a definitive agreement to sell substantially all of its interests in the Barnett Shale to a third party for total consideration of $72.0 million (subject to purchase price adjustments). In September 2019, the Company closed on the sale of the majority of these properties in the Barnett Shale for total consideration of $62.4 million, net of preliminary purchase price adjustments. The sale of the remaining oil and gas properties in the Barnett Shale are expected to close during the fourth quarter of 2019 for total consideration of $6.4 million (subject to purchase price adjustments). The Company recognized an impairment of $75.3 million for these properties during the nine months ended September 30, 2019. As of September 30, 2019, the remaining oil and gas properties in the Barnett Shale were classified as assets held for sale; $6.7 million of the assets held for sale and $0.3 million of the asset retirement obligations classified as liabilities related to assets held for sale in the unaudited condensed consolidated balance sheet were attributable to these unsold properties. In September 2019, the Company closed on the sale of certain oil and gas properties in the Mid-Continent area to a third party for total consideration of $5.3 million, net of preliminary purchase price adjustments. The Company recognized a gain of $0.6 million related to this sale. Additionally, in September 2019, the Company entered into a definitive agreement to sell all of its interest in the Monroe Field in Northern Louisiana for total consideration of $0.2 million (subject to purchase price adjustments). The transaction closed in November 2019. The Company recognized an impairment of $1.6 million for these properties during the nine months ended September 30, 2019. As of September 30, 2019, these oil and gas properties were classified as assets held for sale; $2.6 million of the assets held for sale and $2.4 million of the asset retirement obligations classified as liabilities held for sale in the unaudited condensed consolidated balance sheet were attributable to these properties. In October 2019, the Company entered into a definitive agreement to sell all of its interest in the Permian Basin for total consideration of $3.0 million (subject to purchase price adjustments). The transaction is expected to close during the fourth quarter of 2019. The Company recognized an impairment of $8.1 million for these properties during the nine months ended September 30, 2019.

RISK MANAGEMENT

RISK MANAGEMENT	9 Months Ended
	Sep. 30, 2019
RISK MANAGEMENT [Abstract]
RISK MANAGEMENT	NOTE 6. RISK MANAGEMENT The Company’s business activities expose it to risks associated with changes in the market price of oil, natural gas and natural gas liquids. In addition, the Exit Credit Facility and the New Credit Facility (each as defined below in Note 9) expose the Company to risks associated with changes in interest rates. As such, future earnings are subject to fluctuation due to changes in the market prices of oil, natural gas and natural gas liquids and interest rates. The Company uses derivatives to reduce its risk of volatility in the prices of oil, natural gas and natural gas liquids. The Company policies do not permit the use of derivatives for speculative purposes. The Company has elected not to designate any of its derivatives as hedging instruments . Accordingly, c hanges in the fair value of derivatives are recorded immediately to operations as “Gain (loss) on derivatives, net” in the unaudited condensed consolidated statements of operations. In September 2019, in conjunction with the closings of the sales of oil and natural gas properties in the Barnett Shale and the Mid-Continent area, the Company unwound certain of its derivatives, which resulted in the receipt of a cash settlement of $7.9 million. The natural gas derivatives unwound included 2,990,000 MMBtus and 10,980,000 MMBtus for the periods of October through December 2019 and January through December 2020, respectively. The crude oil derivatives unwound included 85,400 Bbls and 228,750 Bbls for the periods of September through December 2019 and January through December 2020, respectively. The natural gas liquids derivatives unwound included 283,040 Bbls and 656,970 Bbls for the periods of September through December 2019 and January through December 2020, respectively. As of September 30, 2019, the Company had entered into derivatives with the following terms: Weighted Average Period Covered Hedged Volume Fixed Price Oil (Bbls): Swaps - October 2019 to December 2019 121,900 $ 63.53 Swaps - January 2020 to December 2020 439,200 $ 60.50 Natural Gas (MMBtus): Swaps - October 2019 to December 2019 3,450,000 $ 2.78 Swaps - January 2020 to December 2020 12,810,000 $ 2.68 Natural Gas Liquids (Bbls): Swaps - October 2019 to December 2019 30,360 $ 22.50 Swaps - January 2020 to December 2020 111,630 $ 20.71 In November 2019, t he Company terminated 124,000 MMBtus of natural gas swaps for the month of December 2019 at a weighted average fixed price of $2.78 per MMBtu and 1,464,000 MMBtus of natural gas swaps for the period of January 2020 to December 2020 at a weighted average fixed price of $2.64 per MMBtu. These terminations resulted in a net cash settlement received of $150,000. The following table sets forth the fair values and classification of the Company’s outstanding derivatives: Net Amounts Gross Gross Amounts of Assets Amount of Offset in the Presented in the Recognized Consolidated Consolidated Assets Balance Sheet Balance Sheet As of September 30, 2019: Derivative asset $ 8,745 $ — $ 8,745 Long-term derivative asset 1,933 — 1,933 Total $ 10,678 $ — $ 10,678 As of December 31, 2018: Derivative asset $ 18,048 $ (2,596) $ 15,452 Long-term derivative asset 8,565 (66) 8,499 Total $ 26,613 $ (2,662) $ 23,951 Derivative liability $ 3,761 $ (2,596) $ 1,165 Long-term derivative liability 66 (66) — Total $ 3,827 $ (2,662) $ 1,165 The Company has entered into master netting arrangements with its counterparties. The amounts above are presented on a net basis in the unaudited condensed consolidated balance sheets when such amounts are with the same counterparty. In addition, the Company has recorded accounts payable and receivable balances related to settled derivatives that are subject to the master netting agreements. These amounts are not included in the above table; however, under the master netting agreements, the Company has the right to offset these positions against forward exposure related to outstanding derivatives.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2019
FAIR VALUE MEASUREMENTS [Abstract]
FAIR VALUE MEASUREMENTS	NOTE 7. FAIR VALUE MEASUREMENTS The fair value hierarchy has three levels based on the reliability of the inputs used to determine fair value. Level 1 refers to fair values determined based on quoted prices in active markets for identical assets or liabilities. Level 2 refers to fair values determined based on quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration. Level 3 refers to fair values determined based on the Company’s own assumptions used to measure assets and liabilities at fair value. Recurring Basis The following table presents the fair value hierarchy for the Company’s assets and liabilities that are required to be measured at fair value on a recurring basis: Fair Value Measurements at the End of the Reporting Period Quoted Prices in Active Significant Markets for Other Significant Identical Observable Unobservable Assets Inputs Inputs Fair Value (Level 1) (Level 2) (Level 3) As of September 30, 2019: Assets: Oil, natural gas and natural gas liquids derivatives $ 10,678 $ — $ 10,678 $ — As of December 31, 2018: Assets: Oil, natural gas and natural gas liquids derivatives $ 26,613 $ — $ 26,613 $ — Equity securities 47,082 47,082 — — $ 73,695 $ 47,082 $ 26,613 $ — Liabilities: Oil, natural gas and natural gas liquids derivatives $ 3,827 $ — $ 3,827 $ — The Company’s derivatives consist of over–the–counter contracts which are not traded on a public exchange. As the fair value of these derivatives is based on inputs using market prices obtained from independent brokers or determined using quantitative models that use as their basis readily observable market parameters that are actively quoted and can be validated through external sources, including third party pricing services, brokers and market transactions, the Company has categorized these derivatives as Level 2. The Company values these derivatives using the income approach with inputs such as the forward curve for commodity prices based on quoted market prices and prospective volatility factors related to changes in the forward curves and yield curves based on money market rates and interest rate swap data, such as forward LIBOR curves. Estimates of fair value have been determined at discrete points in time based on relevant market data. Furthermore, fair values are adjusted to reflect the credit risk inherent in the transaction, which may include amounts to reflect counterparty credit quality and/or the effect of the Company’s creditworthiness. These assumed credit risk adjustments are based on published credit ratings, public bond yield spreads and credit default swap spreads. There were no changes in valuation techniques or related inputs in the nine months ended September 30, 2019. At December 31, 2018, the Company’s equity securities consisted of 4.2 million shares of common stock of Magnolia that were traded on a public exchange. The Company categorized these equity securities as Level 1, as the fair value of these shares is based on market price. The Company sold all of its 4.2 million shares of common stock of Magnolia during January 2019 for net proceeds of $51.7 million. Nonrecurring Basis The following table presents the fair value hierarchy for the Company’s net assets and liabilities that are required to be measured at fair value on a nonrecurring basis: Fair Value Measurements Quoted Prices in Active Significant Markets for Other Significant Identical Observable Unobservable Assets Inputs Inputs Total Fair Value (Level 1) (Level 2) (Level 3) Losses Nine Months Ended September 30, 2019: Long–lived assets held and used $ 9,371 $ — $ — $ 9,371 $ 11,657 Long-lived Assets Held and Used As a result of reductions in estimated future net cash flows primarily caused by the decrease in prices for oil, natural gas and natural gas liquids, the Company incurred impairment charges of $11.7 million during the nine months ended September 30, 2019 to write down oil and natural gas properties that were held and used to their fair value. Of the $11.7 million impairment, $8.1 million related to oil and natural gas properties in the Permian Basin and $3.6 million related to oil and natural gas properties in the Mid-Continent area. These impairment charges were included in earnings during the period indicated. During the four months ended September 30, 2018, the Company did not recognize any impairment expense related to oil and natural gas properties that were held and used as of September 30, 2018. During the five months ended May 31, 2018, the Predecessor did not recognize any impairment expense related to proved oil and natural gas properties. The fair values were determined using the income approach and were based on the expected present value of the future net cash flows from reserves. Significant Level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis included estimates of future prices, production costs, development expenditures, anticipated production, appropriate risk-adjusted discount rates and other relevant data. Long-lived Assets Sold or Held For Sale During the nine months ended September 30, 2019, the Company recognized an impairment expense of $75.3 million related to proved oil and natural gas properties in the Barnett Shale, which were sold or held for sale as of September 30, 2019. During the nine months ended September 30, 2019, the Company also recognized an impairment expense of $27.0 million related to proved oil and natural gas properties in the San Juan Basin and the Mid-Continent area, which were sold during April 2019. During the nine months ended September 30, 2019, the Company recognized impairment expense of $1.6 million related to proved oil and natural gas properties in the Monroe Field, which was held for sale as of September 30, 2019. During the four months ended September 30, 2018, the Company recognized impairment expense of $2.6 million related to proved oil and natural gas properties in Central Texas and Karnes County, Texas, which were sold during August 2018. The fair values of the oil and natural gas properties sold were determined using the transaction price of the then pending transactions. The fair value of the oil and natural gas properties held for sale as of September 30, 2019 were determined using the transaction price for the pending transaction. Financial Instruments The estimated fair values of the Company’s financial instruments have been determined at discrete points in time based on relevant market information. The Company’s financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, derivatives and long–term debt. The carrying amounts of the Company’s financial instruments other than long–term debt approximate fair value because of the short–term nature of the items. Derivatives are recorded at fair value (see above). The carrying value of debt outstanding under the Exit Credit Facility (as defined in Note 9) approximated fair value because the credit facility’s variable interest rate resets frequently and approximates current market rates available to the Company.

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2019
ASSET RETIREMENT OBLIGATIONS [Abstract]
ASSET RETIREMENT OBLIGATIONS	NOTE 8. ASSET RETIREMENT OBLIGATIONS The Company records an asset retirement obligation (“ARO”) and capitalizes the asset retirement cost in oil and natural gas properties in the period in which the retirement obligation is incurred based upon the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells. After recording these amounts, the ARO is accreted to its future estimated value using an assumed cost of funds and the additional capitalized costs are depreciated on a unit–of–production basis. The changes in the aggregate ARO are as follows: ARO as of December 31, 2018 $ 119,606 Liabilities incurred 345 Revisions (6) Accretion expense 6,373 Settlements and divestitures (20,823) Liabilities held for sale (2,759) ARO as of September 30, 2019 $ 102,736 As of September 30, 2019 and December 31, 2018, $1.4 million and $2.1 million of ARO is classified as current and is included in “Accounts payable and accrued liabilities” in the unaudited condensed consolidated balance sheets, respectively.

LONG-TERM DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 2019
LONG-TERM DEBT [Abstract]
LONG-TERM DEBT	NOTE 9. LONG–TERM DEBT The following table presents the consolidated debt obligations at the dates indicated: September 30, 2019 December 31, 2018 Exit Credit Facility $ — $ 115,000 In connection with the Company’s emergence from bankruptcy, on the Effective Date, the Company entered into a Credit Agreement providing for a $1.0 billion new reserve-based revolving loan (the “Exit Credit Facility”). The Exit Credit Facility matures on February 26, 2021. Borrowings under the Exit Credit Facility are secured by a first priority lien on substantially all of the Company’s oil and natural gas properties. The Company may use borrowings under the Exit Credit Facility for acquiring and developing oil and natural gas properties, for working capital purposes and for general corporate purposes. The Company also may use up to $50.0 million of available borrowing capacity for letters of credit. As of September 30, 2019, the Company had a $0.1 million letter of credit outstanding. The terms of the Exit Credit Facility do not require any repayments of amounts outstanding until it matures in February 2021. Borrowings under the credit facility bear interest at a floating rate based on, at the Company’s election, a base rate or the London Interbank Offered Rate plus applicable premiums based on the percent of the borrowing base outstanding (weighted average effective interest rate of 5.10% at December 31, 2018). Borrowings under the Exit Credit Facility may not exceed a “borrowing base” determined by the lenders under the credit facility based on the Company’s oil and natural gas reserves. During the first quarter of 2019, as a result of divestitures consummated in the fourth quarter of 2018, the borrowing base was reduced by $2.0 million to $260.3 million. In May 2019, in conjunction with the semi-annual redetermination, the borrowing base was reduced by $150.3 million to $110 million, primarily as a result of the divestitures of the San Juan Basin and Mid-Continent assets as well as a decline in bank commodity price assumptions. In addition, in September 2019, as a result of divestitures during the third quarter of 2019, the borrowing base was further reduced by $60.0 million to $50.0 million. As of September 30, 2019, the borrowing base under the Exit Credit Facility was $50.0 million. The borrowing base is subject to scheduled redeterminations semi-annually as of April 1 and October 1 of each year with an additional redetermination once per calendar year at the election of either the Company or the lenders. The Exit Credit Facility requires the following (as defined in the Credit Agreement): · the Total Debt to EBITDAX ratio covenant to be no greater than 4.0 to 1.0; · the current consolidated assets (including unused commitments under the Exit Credit Facility) to current consolidated liabilities to be no less than 1.0 to 1.0; · the percentage of Mortgaged Properties to be no less than 95% of the total value of the Oil and Gas Properties evaluated in the most recent Reserve Report; · no later than 60 days following the Effective Date, 70% of projected production volumes (excluding projected production volumes from certain properties) be hedged (as of the date such swap agreements were executed) for the 18 months following the Effective Date; · cash held by the Company be limited to the greater of 5% of the current borrowing base or $30.0 million; and · no return of capital to shareholders, however dividends or distributions to shareholders can be made if the Total Debt to EBTIDAX ratio is less than 2.75 to 1.0 and unused availability under the borrowing base is greater than 15%. On October 4, 2019, the Company terminated the Exit Credit Facility. Also, on October 4, 2019, the Company entered into a new credit agreement providing for a $10.0 million revolving loan (the “New Credit Facility”). The New Credit Facility matures on October 4, 2020. The New Credit Facility may be renewed for a one-year term by mutual agreement between the Company and the lender. Borrowings under the New Credit Facility are secured by cash collateral and bear interest based upon the London Interbank Offered Rate plus 1%. The Company may use borrowings under the New Credit Facility for acquiring and developing oil and natural gas properties, for working capital purposes and for general corporate purposes. The Company also may use up to $2.0 million of available borrowing capacity for letters of credit.

LEASES

LEASES	9 Months Ended
	Sep. 30, 2019
LEASES
LEASES	NOTE 10. LEASES On January 1, 2019, Harvest adopted ASU No. 2016‑02, Leases (Topic 842) (“Topic 842”), using a modified retrospective method. Accordingly, the comparative information for the year ended December 31, 2018 has not been adjusted and continues to be reported under the previous lease standard. The adoption of Topic 842 did not have a material impact on the Company’s unaudited condensed consolidated financial statements. At adoption on January 1, 2019, an operating lease right of use asset of $1.8 million and an operating lease liability of $1.8 million was recorded. There was no cumulative earnings effect adjustment. There were no significant changes to the timing and amount of lease expense recognized in “Lease operating expenses” in the unaudited condensed consolidated statements of operations. However, as a result of the adoption of Topic 842, the Company recognized right of use assets and lease liabilities for certain commitments related to real estate, vehicles and field equipment that were previously accounted for as operating leases. The Company determines if an arrangement is a lease at inception. Operating lease right-of-use assets represent the Company’s right to use an underlying asset for the lease term and lease liabilities are recognized at commencement date based on the present value of lease payments over the lease term. The Company’s lease terms may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. Lease expense for lease payments is recognized on a straight-line basis over the lease term. Contracts with lease terms less than 12 months are not recorded on the unaudited condensed consolidated balance sheet, but instead are disclosed as short-term lease cost. During the normal course of business, Harvest leases office space, vehicles, IT equipment and field equipment. The Company’s leases have remaining lease terms of 1 year to 4 years, some of which include options to renew. The exercise of lease renewal options is at the Company’s sole discretion. The Company’s lease agreements do not contain any residual value guarantees or restrictive covenants. As most of the Company’s leases do not provide an implicit rate, the Company uses its incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. The Company used the incremental borrowing rate on January 1, 2019 for operating leases that commenced prior to that date. Operating leases are included in other assets, other current liabilities and other long-term liabilities on the unaudited condensed consolidated balance sheet as of September 30, 2019. Operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets were as follows: September 30, 2019 Other assets $ 1,284 Other current liabilities 684 Other long-term liabilities 600 Total operating lease liabilities $ 1,284 Weighted average remaining lease term (in years) 2.0 Weighted average discount rate During the three and nine months ended September 30, 2019, the Company paid $0.8 million and $2.8 million, respectively, of lease cost. Furthermore, during the three and nine months ended September 30, 2019, the Company recognized lease cost, net of reimbursements from other working interest owners, of $0.2 million and $0.6 million, respectively, for operating leases and $0.5 million and $1.8 million, respectively, for short-term leases, which is included in “Lease operating expenses” on the Company’s unaudited condensed consolidated statement of operations. Maturities of operating lease liabilities as of September 30, 2019, were as follows: 2019 $ 210 2020 670 2021 440 2022 36 2023 — Total lease payments 1,356 Less: imputed interest (72) Present value of lease liabilities $ 1,284

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2019
COMMITMENTS AND CONTINGENCIES [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 11. COMMITMENTS AND CONTINGENCIES On the Effective Date, Harvest entered into a Services Agreement (the “Services Agreement”) with EnerVest and EnerVest Operating (together, the “EnerVest Group”). Pursuant to the Services Agreement, the EnerVest Group provides certain administrative, management, operating and other services and support (the “Services”) to Harvest following the Effective Date. In addition, the EnerVest Group also provides Harvest with sufficient office space, equipment and office supplies pursuant to the Services Agreement. The Services Agreement covers the people EnerVest employs who provide direct support to the Company’s operations; however, the Services Agreement does not cover the five full-time employees of Harvest which include the Chief Executive Officer and the Chief Financial Officer. The management fee is subject to an annual redetermination by agreement of the parties and will also be adjusted for acquisitions or divestitures over $5 million. The EnerVest Group will provide the Services until December 31, 2020. During October 2019, the EnerVest Group informed Harvest that there are approximately $4.1 million of uncollectible accounts receivable from third party working interest owners in oil and natural gas properties where Harvest owns a significant working interest for which the EnerVest Group believes Harvest may be responsible. The costs related to these receivables were primarily incurred over the last 8 years and were paid by the EnerVest Group as the contract operator for such properties. Harvest is currently assessing its obligations, if any, with respect to these amounts, as well as its rights and obligations under the Services Agreement and similar agreements. Accordingly, Harvest has determined that the amount of its obligations with respect to these accounts receivable is not estimable at this time and has not accrued any losses with respect to the EnerVest Group’s uncollectible accounts receivable as of September 30, 2019. In August 2018, the Company was notified by the Office of Natural Resources Revenue (“ONRR”) of potential underpayments of royalties related to certain leases for the period of 2009 through 2018. The Company has submitted amended royalty filings for the period of 2009 to 2018, pursuant to which Harvest has an additional liability of approximately $5.0 million. This amount will be paid upon ONRR review and concurrence with the accuracy of royalties per the amended filings. The Company recognized an accrual for the estimated liability for the period of 2009 to 2018 as of both September 30, 2019 and December 31, 2018. The Company is involved in other disputes or legal actions arising in the ordinary course of business. In August 2019, the Company agreed to a litigation settlement of $0.7 million related to such matters in the ordinary course of business, the expense for which is included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations for the nine months ended September 30, 2019. The Company does not believe the outcome of other such disputes or legal actions will have a material effect on its unaudited condensed consolidated financial statements. No amounts, other than as described above, were accrued at September 30, 2019 or December 31, 2018.

INCOME TAXES

INCOME TAXES	9 Months Ended
	Sep. 30, 2019
Income Taxes [Abstract]
Income Taxes	NOTE 12. INCOME TAXES Effective June 4, 2018, pursuant to the Plan, the Successor became a corporation subject to federal and state income taxes. Prior to the Plan being effective, the Predecessor was a limited partnership and organized as a pass-through entity for federal and most state income tax purposes. As a result, the Predecessor’s limited partners were responsible for federal and state income taxes on their share of taxable income. The Predecessor was subject to the Texas margin tax for partnership activity in the state of Texas. Tax obligations of the Predecessor and Successor are recorded as “Income taxes” in the unaudited condensed consolidated statements of operations. The Company’s income tax provision consists of the following: Successor Three Months Three Months Ended Ended September 30, 2019 September 30, 2018 Current tax position: Federal $ — $ — State — — Total income tax provision $ — $ — Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Current tax position: Federal $ — $ — $ — State — — 166 Total income tax provision $ — $ — $ 166 Management assesses the available positive and negative evidence to estimate whether it is more likely than not that sufficient future taxable income will be generated to realize the Company’s deferred tax assets. In making this determination, Management considers all available positive and negative evidence and makes certain assumptions. Management considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends and its outlook for future years. Due to significant negative evidence, the Company has established a full valuation allowance against its net deferred tax assets at December 31, 2018. As of September 30, 2019, the Company continued to record a full valuation allowance against its net deferred tax assets. The Company will continue to assess the valuation allowance against deferred tax assets considering all available information obtained in future reporting periods.

EARNINGS PER SHARE_UNIT AND STO

EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY	9 Months Ended
	Sep. 30, 2019
EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY [Abstract]
EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY	NOTE 13. EARNINGS PER SHARE/UNIT AND STOCKHOLDERS’ EQUITY The following sets forth the calculation of earnings per share/unit, for the periods indicated: Successor Predecessor Three Months Nine Months Three Months Four Months Five Months Ended Ended Ended Ended Ended September 30, September 30, September 30, September 30, May 31, 2019 2019 2018 2018 2018 Net loss attributable to Successor/ Predecessor $ (19,529) $ (116,211) $ (9,760) $ (10,298) $ (610,525) Predecessor’s general partner’s 2% interest in net loss — — — — 12,211 Net loss available to common stockholders/limited partners $ (19,529) $ (116,211) $ (9,760) $ (10,298) $ (598,314) Weighted average common shares/units outstanding: Basic 10,131 10,080 10,028 10,021 49,369 Dilutive effect of potential common shares/units — — — — — Diluted 10,131 10,080 10,028 10,021 49,369 Net earnings per share/unit: Basic $ (1.93) $ (11.53) $ (0.97) $ (1.03) $ (12.12) Diluted $ (1.93) $ (11.53) $ (0.97) $ (1.03) $ (12.12) Antidilutive restricted stock shares (1) 169,600 169,600 — — — Antidilutive warrants (2) 800,000 800,000 800,000 800,000 — (1) Amount represents unvested restricted stock shares as of the end of the period that are excluded from the diluted net earnings per share calculations because of their antidilutive effect. (2) Amount represents warrants to purchase 800,000 shares of the Company’s common stock at a per share exercise price of $37.48 that are excluded from the diluted net earnings per share calculations because of their antidilutive effect. On October 8, 2019, the Board of Directors of Harvest declared a dividend of $7.00 per share of common stock payable on October 28, 2019 to its shareholders of record as of the close of business on October 18, 2019. In accordance with the terms of the outstanding warrants, the declaration of the dividend resulted in an adjustment to the warrant exercise price from $37.48 to $30.48 per share, effective immediately prior to the opening of business on October 21, 2019.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2019
RELATED PARTY TRANSACTIONS [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 14. RELATED PARTY TRANSACTIONS Prior to emergence from bankruptcy, the Predecessor’s general partner was EV Energy GP, and the general partner of its general partner was EV Management. EV Management is a wholly-owned subsidiary of EnerVest. EnerVest and its affiliates also had a significant interest in the Partnership through their 71.25% ownership of EV Energy GP which, in turn, owned a 2% general partner interest in the Partnership and all of its incentive distribution rights. In addition, the Predecessor’s board of directors included directors who were also executives of EnerVest. As a result, EnerVest was considered a related party to the Predecessor. As a result of the Restructuring, EnerVest is no longer a related party to the Company. Pursuant to a prior services agreement, the Predecessor paid EnerVest $7.2 million for general and administrative services provided during the five months ended May 31, 2018. These fees were based on an allocation of charges between EnerVest and EVEP based on the estimated use of such services by each party, and the Partnership believed that the allocation method employed by EnerVest was reasonable and reflective of the estimated level of costs the Partnership would have incurred on a standalone basis. These fees are included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations. The Partnership entered into operating agreements whereby a wholly-owned subsidiary of EnerVest and its affiliates acted as contract operator of the oil and natural gas wells and related gathering systems and production facilities in which EVEP owned an interest. The Predecessor reimbursed EnerVest approximately $8.4 million in the five months ended May 31, 2018, for direct expenses incurred in the operation of its wells and related gathering systems and production facilities and for the allocable share of the costs of EnerVest employees who performed services on its properties. These costs are included in “Lease operating expenses” in the unaudited condensed consolidated statements of operations.

OTHER SUPPLEMENTAL INFORMATION

OTHER SUPPLEMENTAL INFORMATION	9 Months Ended
	Sep. 30, 2019
OTHER SUPPLEMENTAL INFORMATION [Abstract]
OTHER SUPPLEMENTAL INFORMATION	NOTE 15. OTHER SUPPLEMENTAL INFORMATION Supplemental cash flows and noncash transactions were as follows: Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Supplemental cash flows information: Cash paid for interest $ 1,119 $ 4,383 $ 6,008 Cash paid for reorganization items (1) 472 8,733 6,691 (1) Includes approximately $6.9 million disbursed from the restricted cash account during the four months ended September 30, 2018. September 30, 2019 September 30, 2018 Non–cash transactions: Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ 282 $ 4,232 Accounts payable and accrued liabilities consisted of the following: September 30, 2019 December 31, 2018 Lease operating expenses $ 8,521 $ 10,035 San Juan royalties 5,000 5,000 Production and ad valorem taxes 4,285 4,680 General and administrative expenses 2,303 3,321 Current portion of ARO 1,362 2,077 Litigation settlement 679 — Costs for additions to oil and natural gas properties 282 419 Interest — 12 Other 1,711 602 Total $ 24,143 $ 26,146

ORGANIZATION AND NATURE OF BU_2

ORGANIZATION AND NATURE OF BUSINESS (Policy)	9 Months Ended
	Sep. 30, 2019
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Basis of Presentation	Basis of Presentation The Company’s unaudited condensed consolidated financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Accordingly, certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted. The Company believes that the presentations and disclosures herein are adequate to make the information not misleading. The unaudited condensed consolidated financial statements reflect all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the interim periods. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year. These interim financial statements should be read in conjunction with the audited consolidated financial statements and the related notes included in Harvest’s Annual Report on Form 10–K for the year ended December 31, 2018. All intercompany accounts and transactions have been eliminated in consolidation. In the Notes to Unaudited Condensed Consolidated Financial Statements, all dollar, share and unit amounts in tabulations are in thousands of dollars, shares and units, respectively, unless otherwise indicated.
Bankruptcy Accounting	Bankruptcy Accounting The unaudited condensed consolidated financial statements have been prepared as if the Company is a going concern and reflect the application of Accounting Standards Codification 852 Reorganizations (“ASC 852”). ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 filing, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Accordingly, certain expenses, gains and losses that were realized or incurred related to the bankruptcy proceedings are recorded in “Reorganization items, net” on the Company’s condensed consolidated statements of operations. The following table summarizes the components of reorganization items, net included in the accompanying unaudited condensed consolidated statements of operations: Successor Predecessor Three Months Nine Months Three Months Four Months Five Months Ended Ended Ended Ended Ended September 30, September 30, September 30, September 30, May 31, 2019 2019 2018 2018 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ — $ 128,700 Fresh start valuation adjustments — — — — (700,325) Professional fees — — (972) (1,780) (13,345) Other — — — — (2,355) Reorganization items, net $ — $ — $ (972) $ (1,780) $ (587,325) Upon emergence from bankruptcy on June 4, 2018, the Company elected to adopt and apply the relevant guidance provided in GAAP with respect to the accounting and financial statement disclosures for entities that have emerged from Chapter 11 (“fresh start accounting”) effective May 31, 2018 to coincide with the timing of the Company’s normal accounting period close. As a result of the application of fresh start accounting and the effects of the implementation of the plan of reorganization, the condensed consolidated financial statements as of or after May 31, 2018 are not comparable with the condensed consolidated financial statements prior to that date. To facilitate the financial statement presentations, the Company refers to the reorganized company in these unaudited condensed consolidated financial statements and notes as the “Successor” for periods subsequent to May 31, 2018 and “Predecessor” for periods prior to June 1, 2018. Furthermore, the unaudited condensed consolidated financial statements and notes have been presented with a “black line” division to delineate the lack of comparability between the Predecessor and Successor.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and judgments that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company bases its estimates and judgments on historical experience and on various other assumptions and information that are believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be perceived with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the Company’s operating environment changes. While Harvest believes that the estimates and assumptions used in the preparation of the unaudited condensed consolidated financial statements are appropriate, actual results could differ from those estimates.
New Accounting Standards	New Accounting Standards In February 2016, the Financial Accounting Standards Board (the “FASB”) issued ASU No. 2016‑02, Leases (Topic 842) (“ASU 2016-02”). The main objective of ASU 2016‑02 is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The main difference between previous GAAP and Topic 842 is the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. ASU 2016‑02 requires lessees to recognize assets and liabilities arising from leases on the balance sheet. ASU 2016‑02 further defines a lease as a contract that conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Control over the use of the identified asset means that the customer has both (1) the right to obtain substantially all of the economic benefit from the use of the asset and (2) the right to direct the use of the asset. ASU 2016‑02 requires disclosures by lessees and lessors to meet the objective of enabling users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. In January 2018, the FASB issued ASU 2018‑01, Leases (Topic 842), Land Easement Practical Expedient for Transition to Topic 842 (“ASU 2018‑01”), which permits an entity an optional election to not evaluate under ASU 2016‑02 those existing or expired land easements that were not previously accounted for as leases prior to the adoption of ASU 2016‑02. In July 2018, the FASB issued ASU 2018‑11, Leases (Topic 842), Targeted Improvements (“ASU 2018‑11”), which permits an entity (i) to apply the provisions of ASU 2016‑02 at the adoption date instead of the earliest period presented in the financial statements, and, as a lessor, (ii) to account for lease and nonlease components as a single component as the nonlease components would otherwise be accounted for under the provisions of ASU 2014‑09. The Company adopted this new standard as of January 1, 2019 using a modified retrospective approach. The Company elected the package of practical expedients within ASU 2016‑02 that allows an entity to not reassess prior to the effective date (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification for any expired or existing leases or (iii) initial direct costs for any existing leases. Additionally, the Company elected the practical expedient under ASU 2018‑01 that allows an entity to not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date. The adoption of this standard resulted in an increase in the assets and liabilities on the Company’s unaudited condensed consolidated balance sheet. The quantitative impacts of the new standard were dependent on the leases in force at the time of adoption. The adoption of this ASU did not have a material impact on the Company’s unaudited condensed consolidated financial statements. See Note 10 for additional details about the impact upon adoption and related disclosures. No other new accounting pronouncements issued or effective during the nine months ended September 30, 2019 have had or are expected to have a material impact on the unaudited condensed consolidated financial statements other than those disclosed in Harvest’s Annual Report on Form 10‑K for the year ended December 31, 2018.
Subsequent Events	Subsequent Events The Company evaluated subsequent events for appropriate accounting and disclosure through the date these unaudited condensed consolidated financial statements were issued.

ASSET RETIREMENT OBLIGATIONS (P

ASSET RETIREMENT OBLIGATIONS (Policy)	9 Months Ended
	Sep. 30, 2019
ASSET RETIREMENT OBLIGATIONS [Abstract]
Asset Retirement Obligations	The Company records an asset retirement obligation (“ARO”) and capitalizes the asset retirement cost in oil and natural gas properties in the period in which the retirement obligation is incurred based upon the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells. After recording these amounts, the ARO is accreted to its future estimated value using an assumed cost of funds and the additional capitalized costs are depreciated on a unit–of–production basis.

ORGANIZATION AND NATURE OF BU_3

ORGANIZATION AND NATURE OF BUSINESS (Tables)	9 Months Ended
	Sep. 30, 2019
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Summary of Reorganization Items	Successor Predecessor Three Months Nine Months Three Months Four Months Five Months Ended Ended Ended Ended Ended September 30, September 30, September 30, September 30, May 31, 2019 2019 2018 2018 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ — $ 128,700 Fresh start valuation adjustments — — — — (700,325) Professional fees — — (972) (1,780) (13,345) Other — — — — (2,355) Reorganization items, net $ — $ — $ (972) $ (1,780) $ (587,325)

REVENUE (Tables)

REVENUE (Tables)	9 Months Ended
	Sep. 30, 2019
REVENUE [Abstract]
Schedule of Revenue Disaggregated by Product and Service	The following table disaggregates revenue by significant product and service type: Successor Three Months Three Months Ended Ended September 30, 2019 September 30, 2018 Oil $ 7,856 $ 23,254 Natural gas (1) 11,713 26,494 Natural gas liquids (1) 3,301 18,659 Oil, natural gas and natural gas liquids revenues 22,870 68,407 Transportation and marketing–related revenues 379 559 Total revenues $ 23,249 $ 68,966 Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Oil $ 25,365 $ 30,415 $ 42,460 Natural gas (1) 52,055 35,158 40,951 Natural gas liquids (1) 18,865 24,369 26,896 Oil, natural gas and natural gas liquids revenues 96,285 89,942 110,307 Transportation and marketing–related revenues 1,397 744 724 Total revenues $ 97,682 $ 90,686 $ 111,031 (1) The Company recognizes wet gas revenues, which are recorded net of transportation, gathering and processing expenses, partially as natural gas revenues and partially as natural gas liquids revenues based on the end products after processing occurs. For the Successor period of the three months ended September 30, 2019, wet gas revenues were $0.3 million which were recognized as natural gas liquids revenues. For the Successor period of the nine months ended September 30, 2019, wet gas revenues were $4.1 million which were recognized as $1.5 million of natural gas revenues and $2.6 million of natural gas liquids revenues. For the Successor period of the three months ended September 30, 2018, wet gas revenues were $5.9 million which were recognized as $2.0 million of natural gas revenues and $3.9 million of natural gas liquids revenues. For the Successor period of the four months ended September 30, 2018, wet gas revenues were $7.4 million which were recognized as $2.5 million of natural gas revenues and $4.9 million of natural gas liquids revenues. For the Predecessor period of the five months ended May 31, 2018, wet gas revenues were $8.4 million which were recognized as $3.2 million of natural gas revenues and $5.2 million of natural gas liquids revenues.

RISK MANAGEMENT (Tables)

RISK MANAGEMENT (Tables)	9 Months Ended
	Sep. 30, 2019
RISK MANAGEMENT [Abstract]
Commodity Contracts	Weighted Average Period Covered Hedged Volume Fixed Price Oil (Bbls): Swaps - October 2019 to December 2019 121,900 $ 63.53 Swaps - January 2020 to December 2020 439,200 $ 60.50 Natural Gas (MMBtus): Swaps - October 2019 to December 2019 3,450,000 $ 2.78 Swaps - January 2020 to December 2020 12,810,000 $ 2.68 Natural Gas Liquids (Bbls): Swaps - October 2019 to December 2019 30,360 $ 22.50 Swaps - January 2020 to December 2020 111,630 $ 20.71
Fair Value of Derivatives	Net Amounts Gross Gross Amounts of Assets Amount of Offset in the Presented in the Recognized Consolidated Consolidated Assets Balance Sheet Balance Sheet As of September 30, 2019: Derivative asset $ 8,745 $ — $ 8,745 Long-term derivative asset 1,933 — 1,933 Total $ 10,678 $ — $ 10,678 As of December 31, 2018: Derivative asset $ 18,048 $ (2,596) $ 15,452 Long-term derivative asset 8,565 (66) 8,499 Total $ 26,613 $ (2,662) $ 23,951 Derivative liability $ 3,761 $ (2,596) $ 1,165 Long-term derivative liability 66 (66) — Total $ 3,827 $ (2,662) $ 1,165

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
FAIR VALUE MEASUREMENTS [Abstract]
Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis	Fair Value Measurements at the End of the Reporting Period Quoted Prices in Active Significant Markets for Other Significant Identical Observable Unobservable Assets Inputs Inputs Fair Value (Level 1) (Level 2) (Level 3) As of September 30, 2019: Assets: Oil, natural gas and natural gas liquids derivatives $ 10,678 $ — $ 10,678 $ — As of December 31, 2018: Assets: Oil, natural gas and natural gas liquids derivatives $ 26,613 $ — $ 26,613 $ — Equity securities 47,082 47,082 — — $ 73,695 $ 47,082 $ 26,613 $ — Liabilities: Oil, natural gas and natural gas liquids derivatives $ 3,827 $ — $ 3,827 $ —
Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Nonrecurring Basis	Fair Value Measurements Quoted Prices in Active Significant Markets for Other Significant Identical Observable Unobservable Assets Inputs Inputs Total Fair Value (Level 1) (Level 2) (Level 3) Losses Nine Months Ended September 30, 2019: Long–lived assets held and used $ 9,371 $ — $ — $ 9,371 $ 11,657

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2019
ASSET RETIREMENT OBLIGATIONS [Abstract]
Changes in Aggregate Asset Retirement Obligations	ARO as of December 31, 2018 $ 119,606 Liabilities incurred 345 Revisions (6) Accretion expense 6,373 Settlements and divestitures (20,823) Liabilities held for sale (2,759) ARO as of September 30, 2019 $ 102,736

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	9 Months Ended
	Sep. 30, 2019
LONG-TERM DEBT [Abstract]
Long Term Debt	September 30, 2019 December 31, 2018 Exit Credit Facility $ — $ 115,000

LEASES (Tables)

LEASES (Tables)	9 Months Ended
	Sep. 30, 2019
LEASES
Summary of operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets	September 30, 2019 Other assets $ 1,284 Other current liabilities 684 Other long-term liabilities 600 Total operating lease liabilities $ 1,284 Weighted average remaining lease term (in years) 2.0 Weighted average discount rate
Summary of maturities of operating lease liabilities	2019 $ 210 2020 670 2021 440 2022 36 2023 — Total lease payments 1,356 Less: imputed interest (72) Present value of lease liabilities $ 1,284

INCOME TAXES (Tables)

INCOME TAXES (Tables)	9 Months Ended
	Sep. 30, 2019
Income Taxes [Abstract]
Schedule of income tax provision	Successor Three Months Three Months Ended Ended September 30, 2019 September 30, 2018 Current tax position: Federal $ — $ — State — — Total income tax provision $ — $ — Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Current tax position: Federal $ — $ — $ — State — — 166 Total income tax provision $ — $ — $ 166

EARNINGS PER SHARE_UNIT AND S_2

EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY (Tables)	9 Months Ended
	Sep. 30, 2019
EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY [Abstract]
Calculation of Earnings Per Share/Unit	Successor Predecessor Three Months Nine Months Three Months Four Months Five Months Ended Ended Ended Ended Ended September 30, September 30, September 30, September 30, May 31, 2019 2019 2018 2018 2018 Net loss attributable to Successor/ Predecessor $ (19,529) $ (116,211) $ (9,760) $ (10,298) $ (610,525) Predecessor’s general partner’s 2% interest in net loss — — — — 12,211 Net loss available to common stockholders/limited partners $ (19,529) $ (116,211) $ (9,760) $ (10,298) $ (598,314) Weighted average common shares/units outstanding: Basic 10,131 10,080 10,028 10,021 49,369 Dilutive effect of potential common shares/units — — — — — Diluted 10,131 10,080 10,028 10,021 49,369 Net earnings per share/unit: Basic $ (1.93) $ (11.53) $ (0.97) $ (1.03) $ (12.12) Diluted $ (1.93) $ (11.53) $ (0.97) $ (1.03) $ (12.12) Antidilutive restricted stock shares (1) 169,600 169,600 — — — Antidilutive warrants (2) 800,000 800,000 800,000 800,000 — (1) Amount represents unvested restricted stock shares as of the end of the period that are excluded from the diluted net earnings per share calculations because of their antidilutive effect. (2) Amount represents warrants to purchase 800,000 shares of the Company’s common stock at a per share exercise price of $37.48 that are excluded from the diluted net earnings per share calculations because of their antidilutive effect.

OTHER SUPPLEMENTAL INFORMATION

OTHER SUPPLEMENTAL INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2019
OTHER SUPPLEMENTAL INFORMATION [Abstract]
Supplemental Cash Flows and Non-Cash Transactions	Successor Predecessor Nine Months Four Months Five Months Ended Ended Ended September 30, 2019 September 30, 2018 May 31, 2018 Supplemental cash flows information: Cash paid for interest $ 1,119 $ 4,383 $ 6,008 Cash paid for reorganization items (1) 472 8,733 6,691 (1) Includes approximately $6.9 million disbursed from the restricted cash account during the four months ended September 30, 2018. September 30, 2019 September 30, 2018 Non–cash transactions: Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ 282 $ 4,232
Schedule of Accounts Payable and Accrued Liabilities	September 30, 2019 December 31, 2018 Lease operating expenses $ 8,521 $ 10,035 San Juan royalties 5,000 5,000 Production and ad valorem taxes 4,285 4,680 General and administrative expenses 2,303 3,321 Current portion of ARO 1,362 2,077 Litigation settlement 679 — Costs for additions to oil and natural gas properties 282 419 Interest — 12 Other 1,711 602 Total $ 24,143 $ 26,146

ORGANIZATION AND NATURE OF BU_4

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	9 Months Ended
	Sep. 30, 2019segment
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Number of Reportable Segments	1

ORGANIZATION AND NATURE OF BU_5

ORGANIZATION AND NATURE OF BUSINESS - Reorganization items (Details) - USD ($) $ in Thousands	3 Months Ended	4 Months Ended	5 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	May 31, 2018
Reorganization Adjustments Predecessor Cancellations [Abstract]
Professional fees	$ (972)	$ (1,780)
Reorganization items, net	$ (972)	$ (1,780)
Predecessor [Member]
Reorganization Adjustments Predecessor Cancellations [Abstract]
Gain on settlement of liabilities subject to compromise			$ 128,700
Fresh start valuation adjustments			(700,325)
Professional fees			(13,345)
Other			(2,355)
Reorganization items, net			$ (587,325)

EMERGENCE FROM VOLUNTARY REOR_2

EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11 (Narrative) (Details)	Mar. 13, 2018	Sep. 30, 2019	Jun. 04, 2018
Bankruptcy proceedings, date petition for bankruptcy filed		Apr. 2, 2018
Bankruptcy proceedings, description of proceedings		On April 2, 2018, the Debtors each filed Chapter 11 proceedings for relief under Chapter 11 in the Bankruptcy Court. The Debtors' Chapter 11 proceedings were jointly administered under the caption In re EV Energy Partners, L.P., et al., Case No. 18-10814.
Plan of reorganization, date plan confirmed		May 17, 2018
Plan of reorganization, date plan is effective		Jun. 4, 2018
Restructuring Support Agreement percentage of senior notes holders	70.00%
Plan support agreement lenders percentage of loans related to credit facility	94.00%
8.0% Senior Notes due 2019
Debt instrument interest rate stated percentage			8.00%

REVENUE (Details)

REVENUE (Details) - USD ($) $ in Thousands	3 Months Ended		4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Total revenues	$ 23,249	$ 68,966	$ 90,686		$ 97,682
Receivables	21,538				21,538	$ 40,176
Allowance for doubtful accounts receivable	0				$ 0	0
Performance Obligations
Practical expedient to not disclose consideration for remaining performance obligations with original expected duration of one year or less					true
Predecessor [Member]
Disaggregation of Revenue [Line Items]
Total revenues				$ 111,031
Wet Gas Products [Member]
Disaggregation of Revenue [Line Items]
Total revenues	300	5,900	7,400		$ 4,100
Wet Gas Products [Member] | Predecessor [Member]
Disaggregation of Revenue [Line Items]
Total revenues				8,400
Wet Gas Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Total revenues		2,000	2,500		1,500
Wet Gas Natural Gas [Member] | Predecessor [Member]
Disaggregation of Revenue [Line Items]
Total revenues				3,200
Wet Gas Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Total revenues	300	$ 3,900	$ 4,900		2,600
Wet Gas Natural Gas Liquids [Member] | Predecessor [Member]
Disaggregation of Revenue [Line Items]
Total revenues				$ 5,200
Accounts receivable
Disaggregation of Revenue [Line Items]
Receivables	$ 21,500				$ 21,500	$ 38,300

REVENUE (Schedule of Revenue Di

REVENUE (Schedule of Revenue Disaggregated by Product and Service) (Details) - USD ($) $ in Thousands	3 Months Ended		4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019
Disaggregated revenues	$ 23,249	$ 68,966	$ 90,686		$ 97,682
Oil, natural gas and natural gas liquids revenues
Disaggregated revenues	22,870	68,407	89,942		96,285
Oil Product [Member]
Disaggregated revenues	7,856	23,254	30,415		25,365
Natural Gas Product [Member]
Disaggregated revenues	11,713	26,494	35,158		52,055
Natural Gas Liquids Product [Member]
Disaggregated revenues	3,301	18,659	24,369		18,865
Wet Gas Products [Member]
Disaggregated revenues	300	5,900	7,400		4,100
Wet Gas Natural Gas [Member]
Disaggregated revenues		2,000	2,500		1,500
Wet Gas Natural Gas Liquids [Member]
Disaggregated revenues	300	3,900	4,900		2,600
Transportation and marketing–related revenues
Disaggregated revenues	$ 379	$ 559	$ 744		$ 1,397
Predecessor [Member]
Disaggregated revenues				$ 111,031
Predecessor [Member] | Oil, natural gas and natural gas liquids revenues
Disaggregated revenues				110,307
Predecessor [Member] | Oil Product [Member]
Disaggregated revenues				42,460
Predecessor [Member] | Natural Gas Product [Member]
Disaggregated revenues				40,951
Predecessor [Member] | Natural Gas Liquids Product [Member]
Disaggregated revenues				26,896
Predecessor [Member] | Wet Gas Products [Member]
Disaggregated revenues				8,400
Predecessor [Member] | Wet Gas Natural Gas [Member]
Disaggregated revenues				3,200
Predecessor [Member] | Wet Gas Natural Gas Liquids [Member]
Disaggregated revenues				5,200
Predecessor [Member] | Transportation and marketing–related revenues
Disaggregated revenues				$ 724

SHARE-BASED COMPENSATION (Detai

SHARE-BASED COMPENSATION (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost			$ 1,144		$ 2,184
Restricted stock shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation, other than options	$ 2,000				$ 2,000
Unrecognized compensation, other than options, period of recognition					1 year 7 months 6 days
Restricted stock shares | Vesting Subject to Future Events [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation, other than options	$ 900				$ 900
Restricted stock shares | Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted					322,172
Shares vesting over period					150,000
Vesting period					3 years
Shares future events					59,728
Units vested	72,384	30,188
Shares vesting on future date					9,872
Shares forfeited					0
Number of shares available for grant	300,000				300,000
Weighted average fair value of phantom units					$ 15.24
Fair value of shares granted					$ 4,900
Restricted stock shares | Management Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost	$ 1,400				2,100
Series A Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost					$ 65
Rate for preferred stock					8.00%
Deferred compensation arrangement with individual, fair value of shares issued					$ 200
Share-based compensation arrangement by share-based payment award, options, vested, number of shares					21,000
Redemption amount, preferred stock	$ 200				$ 200
Predecessor [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost				$ 3,784
Predecessor [Member] | Unvested Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost				$ 3,800
Employee [Member] | Series A Preferred Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares issued					21,000

DIVESTITURES (Details)

DIVESTITURES (Details) - USD ($) $ in Thousands, shares in Millions	1 Months Ended			3 Months Ended			4 Months Ended	9 Months Ended
	Sep. 30, 2019	Apr. 30, 2019	Jan. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2019	Dec. 31, 2019	Oct. 31, 2019	Jul. 31, 2019
Significant Acquisitions And Disposals [Line Items]
Proceeds from sale of oil and natural gas properties							$ 136,483	$ 111,575
Gain on sale of certain oil and gas properties				$ 661		$ 28	47	679
Impairment of oil and gas properties				16,325		$ 2,565	$ 2,565	115,604
Assets held for sale	$ 9,284			9,284				9,284
Liabilities related to assets held for sale	2,759			2,759				2,759
Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Significant Acquisitions And Disposals [Line Items]
Business acquisition equity interests issued or issuable number of shares originally acquired then sold			4.2
Proceeds from sale of available-for-sale securities, equity			$ 51,700
Mid Continent Area Oil and Gas Properties [Member] | Third Party Acquirer [Member]
Significant Acquisitions And Disposals [Line Items]
Proceeds from sale of oil and natural gas properties	5,300		$ 1,800		$ 2,300
Gain on sale of certain oil and gas properties								600
Preferential rights to purchase that were exercised by other working interest owners					$ 900
Impairment of oil and gas properties								1,700
San Jun Property [Member] | Third Party Acquirer [Member]
Significant Acquisitions And Disposals [Line Items]
Proceeds from sale of oil and natural gas properties		$ 36,900
Impairment of oil and gas properties								25,300
Barnett Shale Property [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment of oil and gas properties								75,300
Assets held for sale	6,700			6,700				6,700
Liabilities related to assets held for sale	300			300				300
Barnett Shale Property [Member] | Third Party Acquirer [Member]
Significant Acquisitions And Disposals [Line Items]
Total purchase consideration											$ 72,000
Proceeds from sale of oil and natural gas properties	62,400
Barnett Shale Property [Member] | Scenario | Third Party Acquirer [Member]
Significant Acquisitions And Disposals [Line Items]
Total purchase consideration									$ 6,400
Monroe Field Property
Significant Acquisitions And Disposals [Line Items]
Total purchase consideration	200			200				200
Impairment of oil and gas properties								1,600
Assets held for sale	2,600			2,600				2,600
Liabilities related to assets held for sale	$ 2,400			$ 2,400				2,400
Permian Basin Property [Member]
Significant Acquisitions And Disposals [Line Items]
Impairment of oil and gas properties								$ 8,100
Permian Basin Property [Member] | Subsequent Event
Significant Acquisitions And Disposals [Line Items]
Total purchase consideration										$ 3,000

RISK MANAGEMENT (Details)

RISK MANAGEMENT (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
RISK MANAGEMENT [Abstract]
Description of derivative risk management policy	The Company's business activities expose it to risks associated with changes in the market price of oil, natural gas and natural gas liquids. In addition, the Exit Credit Facility and the New Credit Facility (each as defined below in Note 9) expose the Company to risks associated with changes in interest rates. As such, future earnings are subject to fluctuation due to changes in the market prices of oil, natural gas and natural gas liquids and interest rates. The Company uses derivatives to reduce its risk of volatility in the prices of oil, natural gas and natural gas liquids. The Company policies do not permit the use of derivatives for speculative purposes.
Derivative, cash received on hedge	$ 7.9

RISK MANAGEMENT (Commodity Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	1 Months Ended	9 Months Ended
	Nov. 30, 2019USD ($)MMBTU$ / MMBTU	Sep. 30, 2019USD ($)MMBTU$ / MMBTU$ / bblbbl
Derivative Instruments Related to Oil and Gas Production [Line Items]
Derivative, net cash settlement | $		$ 7,900,000
Subsequent Event
Derivative Instruments Related to Oil and Gas Production [Line Items]
Derivative, net cash settlement | $	$ 150,000
Oil | Swaps - October 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls)		121,900
Weighted average fixed price | $ / bbl		63.53
Oil | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls)		439,200
Weighted average fixed price | $ / bbl		60.50
Derivative unwound volume (Bbls)		228,750
Oil | Swaps - September through December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Derivative unwound volume (Bbls)		85,400
Natural Gas | Swaps - October 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MMBtus) | MMBTU		3,450,000
Weighted average fixed price | $ / MMBTU		2.78
Derivative unwound volume (MMBtus) | MMBTU		2,990,000
Natural Gas | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MMBtus) | MMBTU		12,810,000
Weighted average fixed price | $ / MMBTU		2.68
Derivative unwound volume (MMBtus) | MMBTU		10,980,000
Natural Gas | Swaps - January 2020 to December 2020 | Subsequent Event
Derivative Instruments Related to Oil and Gas Production [Line Items]
Weighted average fixed price | $ / MMBTU	2.64
Derivative unwound volume (MMBtus) | MMBTU	1,464,000
Natural Gas | December 2019 | Subsequent Event
Derivative Instruments Related to Oil and Gas Production [Line Items]
Weighted average fixed price | $ / MMBTU	2.78
Derivative unwound volume (MMBtus) | MMBTU	124,000
Natural Gas Liquids | Swaps - October 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls)		30,360
Weighted average fixed price | $ / bbl		22.50
Natural Gas Liquids | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls)		111,630
Weighted average fixed price | $ / bbl		20.71
Derivative unwound volume (Bbls)		656,970
Natural Gas Liquids | Swaps - September through December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Derivative unwound volume (Bbls)		283,040

RISK MANAGEMENT (Fair Value of

RISK MANAGEMENT (Fair Value of Derivatives) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Derivative Assets [Abstract]
Derivative asset, fair value	$ 10,678	$ 26,613
Derivative asset, liability		(2,662)
Derivative asset	8,745	15,452
Long–term derivative asset	1,933	8,499
Derivative asset, Net recorded fair value	10,678	23,951
Derivative Liabilities [Abstract]
Derivative liability, fair value		3,827
Derivative liability, asset		(2,662)
Derivative liability		1,165
Derivative liability, Net recorded fair value		1,165
Current Derivatives Asset
Derivative Assets [Abstract]
Derivative asset, fair value	8,745	18,048
Derivative asset, liability		(2,596)
Derivative asset	8,745	15,452
Noncurrent Derivative Asset
Derivative Assets [Abstract]
Derivative asset, fair value	1,933	8,565
Derivative asset, liability		(66)
Long–term derivative asset	$ 1,933	8,499
Current Derivatives Liability
Derivative Liabilities [Abstract]
Derivative liability, fair value		3,761
Derivative liability, asset		(2,596)
Derivative liability		1,165
Noncurrent Derivative Liability
Derivative Liabilities [Abstract]
Derivative liability, fair value		66
Derivative liability, asset		$ (66)

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative asset, fair value	$ 10,678	$ 26,613
Equity securities		47,082
Derivative liability, fair value		3,827
Recurring basis
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity securities		47,082
Total, Derivative asset, fair value		73,695
Recurring basis | Commodity contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative asset, fair value	10,678	26,613
Derivative liability, fair value		3,827
Recurring basis | Quoted Prices in Active Markets for Identical Assets (Level 1)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity securities		47,082
Total, Derivative asset, fair value		47,082
Recurring basis | Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total, Derivative asset, fair value		26,613
Recurring basis | Significant Other Observable Inputs (Level 2) | Commodity contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative asset, fair value	$ 10,678	26,613
Derivative liability, fair value		$ 3,827

FAIR VALUE MEASUREMENTS (Narrat

FAIR VALUE MEASUREMENTS (Narrative) (Details) - USD ($) shares in Millions	1 Months Ended	2 Months Ended	3 Months Ended		4 Months Ended	5 Months Ended	9 Months Ended	12 Months Ended
	Jan. 31, 2019	May 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties			$ 16,325,000	$ 2,565,000	$ 2,565,000		$ 115,604,000
Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Business acquisition equity interests issued or issuable number of shares originally acquired then sold	4.2
Proceeds from sale of available-for-sale securities, equity	$ 51,700,000
Nonrecurring basis | Proved property in Barnett Shale [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							75,300,000
Nonrecurring basis | Proved property in San Juan Basin And Mid Continent Area [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							27,000,000
Nonrecurring basis | Proved property in Monroe Field [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							1,600,000
Nonrecurring basis | Proved property in Central Texas and Karnes County [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties					2,600,000
Long Lived Assets Held and Used [Member] | Nonrecurring basis
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties					$ 0		11,700,000
Quoted Prices in Active Markets for Identical Assets (Level 1) | Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Common stock of Magnolia traded in public exchange								4.2
Mid Continent Area Oil and Gas Properties [Member] | Long Lived Assets Held and Used [Member] | Nonrecurring basis
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							3,600,000
Permian Basin Property [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							8,100,000
Permian Basin Property [Member] | Long Lived Assets Held and Used [Member] | Nonrecurring basis
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties							$ 8,100,000
Predecessor [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties						$ 3,000
Predecessor [Member] | Nonrecurring basis | Proved properties [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and natural gas properties		$ 0				$ 0

FAIR VALUE MEASUREMENTS (Fair_2

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Net Assets and Liabilities Measured Fair Value on Nonrecurring Basis) (Details) - Nonrecurring basis - Long Lived Assets Held and Used [Member] $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets	$ 9,371
Total losses	11,657
Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets	$ 9,371

ASSET RETIREMENT OBLIGATIONS (C

ASSET RETIREMENT OBLIGATIONS (Changes in Aggregate Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	3 Months Ended		4 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2019	Dec. 31, 2018
ASSET RETIREMENT OBLIGATIONS [Abstract]
Asset retirement obligation, current	$ 1,362			$ 1,362	$ 2,077
Changes in aggregate ARO
Balance at beginning of period				119,606
Liabilities incurred				345
Revisions				(6)
Accretion expense	1,995	$ 2,345	$ 3,134	6,373
Settlements and divestitures				(20,823)
Liabilities held for sale				(2,759)
Balance at end of period	$ 102,736			$ 102,736

LONG-TERM DEBT (Long Term Debt)

LONG-TERM DEBT (Long Term Debt) (Details) $ in Thousands	Dec. 31, 2018USD ($)
LONG-TERM DEBT [Abstract]
Credit facility outstanding	$ 115,000

LONG-TERM DEBT - Exit Credit Fa

LONG-TERM DEBT - Exit Credit Facility (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Oct. 04, 2019	May 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Exit Credit Facility
Credit facility, maximum borrowing capacity	$ 50		$ 110
Period the projected production volumes must be hedged	18 months
Total debt to earnings ratio, dividends or distributions to shareholders, maximum	2.75
Unused availability percentage, dividends or distributions to shareholders, minimum	15
Revolving Credit Facility [Member]
Exit Credit Facility
Reduction in borrowing base			$ 150.3
Debt instrument ratio current consolidated assets to current consolidated liabilities	1
Debt instrument covenant percentage related to projected production volumes	70.00%
Maximum amount of cash that may be held per covenant, as a percent of borrowing base	5.00%
Maximum amount of cash that may be held if more than the specified percentage of borrowing base	$ 30
Revolving Credit Facility [Member] | Secured Debt [Member]
Exit Credit Facility
Credit facility, maximum borrowing capacity	$ 1,000
Credit facility expiration date	Feb. 26, 2021
Weighted average effective interest rate					5.10%
Reduction in borrowing base	$ 60			$ 2
Line of credit, borrowing base				$ 260.3
Standby Letters of Credit [Member]
Exit Credit Facility
Credit facility, maximum borrowing capacity	50
Letter of credit outstanding	$ 0.1
Minimum | Revolving Credit Facility [Member]
Exit Credit Facility
Debt instrument covenant percentage of total value of mortgaged properties evaluated in reserve report	95.00%
Maximum | Revolving Credit Facility [Member]
Exit Credit Facility
Total debt to earnings ratio required under credit facility	4
Borrowing Base Determination, Period One | Revolving Credit Facility [Member]
Exit Credit Facility
Borrowing base scheduled redetermination date	--04-01
Borrowing Base Determination, Period Two | Revolving Credit Facility [Member]
Exit Credit Facility
Borrowing base scheduled redetermination date	--10-01
Subsequent Event | Letter of Credit | Standby Letters of Credit [Member]
Exit Credit Facility
Credit facility, maximum borrowing capacity		$ 2
Subsequent Event | Revolving Credit Facility [Member]
Exit Credit Facility
Credit facility, maximum borrowing capacity		$ 10

LEASES (Details)

LEASES (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Jan. 01, 2019
Lessee, Lease, Description [Line Items]
Operating lease right of use asset	$ 1,284
Operating lease liability	$ 1,284
Option to extend	true
Option to terminate	true
Minimum
Lessee, Lease, Description [Line Items]
Remaining lease terms	1 year
Maximum
Lessee, Lease, Description [Line Items]
Remaining lease terms	4 years
ASU 2016-02 | Restatement
Lessee, Lease, Description [Line Items]
Operating lease right of use asset		$ 1,800
Operating lease liability		$ 1,800

LEASES - Operating Lease (Detai

LEASES - Operating Lease (Details) $ in Thousands	Sep. 30, 2019USD ($)
Operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets
Right of use assets	$ 1,284
Other assets	us-gaap:OtherAssetsNoncurrent
Lease liabilities, current	$ 684
Other current liabilities	us-gaap:OtherLiabilitiesCurrent
Lease liabilities, noncurrent	$ 600
Other long-term liabilities	us-gaap:OtherLiabilitiesNoncurrent
Total operating lease liabilities	$ 1,284
Weighted average remaining lease term (in years)	2 years
Weighted average discount rate	5.80%

LEASES - Supplemental Cash Flow

LEASES - Supplemental Cash Flows and Noncash Transactions (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
LEASES
Supplemental cash flows information: Cash paid for operating leases	$ 0.8	$ 2.8
Lease cost, net of reimbursements from other working interest owners	0.2	0.6
Short-term lease, cost	$ 0.5	$ 1.8

LEASES - Maturities of Operatin

LEASES - Maturities of Operating Lease Liabilities (Details) $ in Thousands	Sep. 30, 2019USD ($)
Maturities of operating lease liabilities
2019	$ 210
2020	670
2021	440
2022	36
Total lease payments	1,356
Less: imputed interest	(72)
Present value of lease liabilities	$ 1,284

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	Jun. 04, 2018USD ($)employee	Aug. 31, 2019USD ($)	Oct. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Long-term Purchase Commitment [Line Items]
Litigation settlement		$ 0.7
Loss contingency accrual				$ 0	$ 0
Other Commitment for Periods 2013 through 2018 [Member]
Long-term Purchase Commitment [Line Items]
Additional liability				$ 5
Services Agreement
Long-term Purchase Commitment [Line Items]
Number of full-time employees not included in the services agreement | employee	5
Service agreement acquisition and/or divestiture minimum amount	$ 5
Subsequent Event
Long-term Purchase Commitment [Line Items]
Loss contingency, estimate of possible loss			$ 4.1

INCOME TAXES (Schedule of incom

INCOME TAXES (Schedule of income tax provision) (Details) - Predecessor [Member] $ in Thousands	5 Months Ended
	May 31, 2018USD ($)
State	$ 166
Total income tax provision	$ 166

EARNINGS PER SHARE_UNIT AND S_3

EARNINGS PER SHARE/UNIT AND STOCKHOLDERS' EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 08, 2019	Jun. 30, 2018	May 31, 2018	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019	Oct. 21, 2019
Earnings Per Share Disclosure [Line Items]
Net loss		$ (538)		$ (19,529)	$ (60,907)	$ (35,775)	$ (9,760)		$ (10,298)		$ (116,211)
Net loss available to common stockholders/limited partners				$ (19,529)			$ (9,760)		$ (10,298)		$ (116,211)
Weighted average common shares/units outstanding:
Weighted average common shares/units outstanding, basic				10,131,000			10,028,000		10,021,000		10,080,000
Weighted average common shares/units outstanding, diluted				10,131,000			10,028,000		10,021,000		10,080,000
Basic and diluted earnings per share:
Basic, share/unit				$ (1.93)			$ (0.97)		$ (1.03)		$ (11.53)
Diluted, share/unit				$ (1.93)			$ (0.97)		$ (1.03)		$ (11.53)
Class of warrant or right, number of securities called by warrants or rights				800,000							800,000
Exercise price of warrants				$ 37.48							$ 37.48
Restricted stock shares
Basic and diluted earnings per share:
Equity awards not included in computation of diluted net income (loss) per limited partner unit				169,600							169,600
Antidilutive warrants
Basic and diluted earnings per share:
Equity awards not included in computation of diluted net income (loss) per limited partner unit				800,000			800,000		800,000		800,000
Subsequent Event
Basic and diluted earnings per share:
Common stock dividend declared per share	$ 7
Exercise price of warrants												$ 30.48
Predecessor [Member]
Earnings Per Share Disclosure [Line Items]
Net loss			$ (595,076)					$ (15,449)		$ (610,525)
General partner's 2% interest in net loss										12,211
Net loss available to common stockholders/limited partners										$ (598,314)
Weighted average common shares/units outstanding:
Weighted average common shares/units outstanding, basic										49,369,000
Weighted average common shares/units outstanding, diluted										49,369,000
Basic and diluted earnings per share:
Basic, share/unit										$ (12.12)
Diluted, share/unit										$ (12.12)

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - Predecessor [Member] $ in Millions	5 Months Ended
	May 31, 2018USD ($)
Ener Vest Ltd [Member] | EV Energy GP
Related Party Transaction [Line Items]
Percentage of general partnership interest	71.25%
EV Energy GP | EVEP
Related Party Transaction [Line Items]
Percentage of general partnership interest	2.00%
Ener Vest Ltd [Member]
Related Party Transaction [Line Items]
Administrative fees paid to related party	$ 7.2
Direct expenses incurred and reimbursed to related party	$ 8.4

OTHER SUPPLEMENTAL INFORMATIO_2

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) - USD ($) $ in Thousands	4 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2018	May 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Supplemental cash flows information:
Cash paid for interest	$ 4,383		$ 1,119
Cash paid for reorganization items	8,733		472
Disbursed from restricted cash account	$ 6,900
Non-cash transactions:
Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities			$ 282	$ 4,232
Predecessor [Member]
Supplemental cash flows information:
Cash paid for interest		$ 6,008
Cash paid for reorganization items		$ 6,691

OTHER SUPPLEMENTAL INFORMATIO_3

OTHER SUPPLEMENTAL INFORMATION (Schedule of Accounts Payable and Accrued Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Other Supplemental Information Disclosure [Abstract]
Lease operating expenses	$ 8,521	$ 10,035
San Juan royalties	5,000	5,000
Production and ad valorem taxes	4,285	4,680
General and administrative expenses	2,303	3,321
Current portion of ARO	1,362	2,077
Litigation settlement	679
Costs for additions to oil and natural gas properties	282	419
Interest		12
Other	1,711	602
Total	$ 24,143	$ 26,146