Harvest Oil & Gas (HRST) 10-Q 14 Aug 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Aug. 09, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	Jun. 30, 2019
Entity Registrant Name	Harvest Oil & Gas Corp.
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		10,117,472
Entity Central Index Key	0001361937
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 13,650	$ 6,313
Equity securities		47,082
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	29,252	40,176
Other	1,355	4,496
Derivative asset	14,137	15,452
Other current assets	944	2,314
Total current assets	59,338	115,833
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; June 30, 2019, $7,175; December 31, 2018, $12,950	159,388	405,688
Assets held for sale	87,260
Long–term derivative asset	4,781	8,499
Other assets	7,112	4,474
Total assets	317,879	534,494
Current liabilities:
Accounts payable and accrued liabilities	25,095	26,146
Derivative liability		1,165
Other current liabilities	731
Total current liabilities	25,826	27,311
Asset retirement obligations	102,108	117,529
Long–term debt, net		115,000
Liabilities held for sale	10,618
Other long–term liabilities	1,804	1,036
Commitments and contingencies (Note 11)
Mezzanine equity	135	79
Stockholders’ equity:
Common stock – $0.01 par value; 65,000,000 shares authorized; 10,141,512 shares issued and 10,117,472 shares outstanding as of June 30, 2019; 10,054,816 shares issued and 10,042,468 shares outstanding as of December 31, 2018	101	100
Additional paid-in capital	250,414	249,717
Treasury stock at cost – 24,040 shares at June 30, 2019; 12,348 shares at December 31, 2018	(414)	(247)
Retained earnings (accumulated deficit)	(72,713)	23,969
Total stockholders’ equity	177,388	273,539
Total liabilities and equity	$ 317,879	$ 534,494

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$ 7,175	$ 12,950
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	65,000,000	65,000,000
Common stock, shares issued	10,141,512	10,054,816
Common stock, shares, outstanding	10,117,472	10,042,468
Treasury stock, shares	24,040	12,348

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended	5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019	May 31, 2018	Jun. 30, 2019
Revenues:
Total revenues	$ 21,720		$ 30,587		$ 74,433
Operating costs and expenses:
Lease operating expenses	9,375		21,754		44,954
Cost of purchased natural gas	129		315		714
Dry hole and exploration costs	43				39
Production taxes	970		1,450		3,643
Accretion expense on obligations	789		2,168		4,378
Depreciation, depletion and amortization	2,730		4,373		9,345
General and administrative expenses	2,029		6,653		13,023
Impairment of oil and natural gas properties			73,151		99,279
(Gain) loss on sales of oil and natural gas properties	(19)		(5)		(18)
Total operating costs and expenses	16,046		109,859		175,357
Operating income (loss)	5,674		(79,272)		(100,924)
Other income (expense), net:
Gain (loss) on derivatives, net	(4,232)		16,430		(344)
Interest expense	(1,199)		(1,315)		(2,834)
Gain on equity securities					4,593
Other income (expense), net	27		2,965		2,827
Total other income (expense), net	(5,404)		18,080		4,242
Reorganization items, net	(808)
Loss before income taxes	(538)		(61,192)		(96,682)
Income tax benefit (expense)			285
Net loss	$ (538)		$ (60,907)		$ (96,682)
Basic and diluted earnings per share / unit:
Net loss	$ (0.05)		$ (6.05)		$ (9.62)
Weighted average common shares / units outstanding:
Basic, share/unit	10,000		10,064		10,053
Diluted, share/unit	10,000		10,064		10,053
Oil, natural gas and natural gas liquids revenues
Revenues:
Total revenues	$ 21,535		$ 30,129		$ 73,415
Transportation and marketing-related revenues
Revenues:
Total revenues	$ 185		$ 458		$ 1,018
Predecessor
Revenues:
Total revenues		$ 43,089		$ 111,031
Operating costs and expenses:
Lease operating expenses		17,828		45,372
Cost of purchased natural gas		242		557
Dry hole and exploration costs		40		122
Production taxes		1,818		5,343
Accretion expense on obligations		1,279		3,176
Depreciation, depletion and amortization		19,194		46,196
General and administrative expenses		7,923		15,648
Restructuring costs				5,211
Impairment of oil and natural gas properties				3
(Gain) loss on sales of oil and natural gas properties		7		5
Total operating costs and expenses		48,331		121,633
Operating income (loss)		(5,242)		(10,602)
Other income (expense), net:
Gain (loss) on derivatives, net		45		444
Interest expense		(3,176)		(13,652)
Other income (expense), net		474		776
Total other income (expense), net		(2,657)		(12,432)
Reorganization items, net		(587,325)		(587,325)
Loss before income taxes		(595,224)		(610,359)
Income tax benefit (expense)		148		(166)
Net loss		$ (595,076)		$ (610,525)
Basic and diluted earnings per share / unit:
Net loss		$ (11.81)		$ (12.12)
Weighted average common shares / units outstanding:
Basic, share/unit		49,369		49,369
Diluted, share/unit		49,369		49,369
Predecessor | Oil, natural gas and natural gas liquids revenues
Revenues:
Total revenues		$ 42,749		$ 110,307
Predecessor | Transportation and marketing-related revenues
Revenues:
Total revenues		$ 340		$ 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) at Dec. 31, 2017							$ 648,371	$ (20,359)					$ 628,012
Net loss | Predecessor							(15,140)	(309)					(15,449)
Equity-based compensation | Predecessor							575	12					587
Ending Balance (Predecessor) at Mar. 31, 2018							633,806	(20,656)					613,150
Beginning Balance (Predecessor) at Dec. 31, 2017							648,371	(20,359)					628,012
Net loss | Predecessor													(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) at Mar. 31, 2018							633,806	(20,656)					613,150
Contributions from general partner | Predecessor								40					40
Issuance of common stock to Predecessor common unitholders | Predecessor							(11,967)						(11,967)
Issuance of warrants to Predecessor common unitholders | Predecessor							(9,345)						(9,345)
Cancellation of Predecessor common unitholders | Predecessor							(32,453)						(32,453)
Cancellation of Predecessor general partner interest | Predecessor								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							(583,174)	(11,902)					(595,076)
Equity-based compensation | Predecessor							$ 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 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													(96,682)
Ending Balance at Jun. 30, 2019									$ 101	250,414	(414)	(72,713)	177,388
Ending Balance (in shares) at Jun. 30, 2019									10,118
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

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	1 Months Ended	5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019
Cash flows from operating activities:
Net loss	$ (538)		$ (96,682)
Adjustments to reconcile net loss to net cash flows provided by operating activities:
Accretion expense on obligations	789		4,378
Depreciation, depletion and amortization	2,730		9,345
Share-based compensation cost			763
Impairment of oil and natural gas properties			99,279
(Gain) loss on sales of oil and natural gas properties	(19)		(18)
Gain on equity securities			(4,593)
(Gain) loss on derivatives, net	4,232		344
Cash settlements of matured derivative contracts			3,525
Other	60		1,218
Changes in operating assets and liabilities:
Accounts receivable	876		14,066
Other current assets	(354)		1,369
Accounts payable and accrued liabilities	1,490		(1,532)
Other, net	(790)		(2,382)
Net cash flows provided by operating activities	8,476		29,080
Cash flows from investing activities:
Additions to oil and natural gas properties	(7,220)		(1,794)
Reimbursements related to oil and natural gas properties			2,069
Proceeds from sale of oil and natural gas properties	16		41,458
Proceeds from sale of equity securities			51,675
Other			26
Net cash flows provided by (used in) investing activities	(7,204)		93,434
Cash flows from financing activities:
Repayment of long–term debt borrowings	(17,000)		(115,000)
Purchase of treasury stock			(167)
Other			(10)
Net cash flows provided by (used in) financing activities	(17,000)		(115,177)
Increase (decrease) in cash, cash equivalents and restricted cash	(15,728)		7,337
Cash, cash equivalents and restricted cash - beginning of period	28,732		6,313
Cash, cash equivalents and restricted cash - end of period	13,004	$ 28,732	$ 13,650
Predecessor
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 matured 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	6 Months Ended
	Jun. 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 initiated processes to divest 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 or concentrate in existing positions. As of June 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 Six Months One Month Two Months Five Months Ended Ended Ended Ended Ended June 30, 2019 June 30, 2019 June 30, 2018 May 31, 2018 May 31, 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ 128,700 $ 128,700 Fresh start valuation adjustments — — — (700,325) (700,325) Professional fees — — (808) (13,345) (13,345) Other — — — (2,355) (2,355) Reorganization items, net $ — $ — $ (808) $ (587,325) $ (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 six months ended June 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	6 Months Ended
	Jun. 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	6 Months Ended
	Jun. 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 Predecessor Three Months One Month Two Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Oil $ 8,076 $ 7,161 $ 17,555 Natural gas (1) 16,541 8,664 14,562 Natural gas liquids (1) 5,512 5,710 10,632 Oil, natural gas and natural gas liquids revenues 30,129 21,535 42,749 Transportation and marketing–related revenues 458 185 340 Total revenues $ 30,587 $ 21,720 $ 43,089 Successor Predecessor Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Oil $ 17,509 $ 7,161 $ 42,460 Natural gas (1) 40,342 8,664 40,951 Natural gas liquids (1) 15,564 5,710 26,896 Oil, natural gas and natural gas liquids revenues 73,415 21,535 110,307 Transportation and marketing–related revenues 1,018 185 724 Total revenues $ 74,433 $ 21,720 $ 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 June 30, 2019, wet gas revenues were $0.5 million which were recognized as natural gas liquids revenues. For the Successor period of the six months ended June 30, 2019, wet gas revenues were $3.8 million which were recognized as $1.5 million of natural gas revenues and $2.3 million of natural gas liquids revenues. For the Successor period of the one month ended June 30, 2018, wet gas revenues were $1.5 million which were recognized as $0.5 million of natural gas revenues and $1.0 million of natural gas liquids revenues. For the Predecessor period of the two months ended May 31, 2018, wet gas revenues were $3.3 million which were recognized as $1.4 million of natural gas revenues and $1.9 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 and from exploration and production companies that own interests in properties Harvest operates. As of June 30, 2019 and December 31, 2018, the Company had receivables of $26.7 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 and joint working interest owners 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 June 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	6 Months Ended
	Jun. 30, 2019
SHARE-BASED COMPENSATION [Abstract]
SHARE-BASED COMPENSATION	NOTE 4. SHARE–BASED COMPENSATION During the six months ended June 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 six months ended June 30, 2019, 150,000 shares are subject to a graded vesting over a three year period; 132,112 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; and 9,872 shares are scheduled to vest on June 5, 2020. The weighted average fair value of the restricted shares granted during the six months ended June 30, 2019, was $15.24 with a total fair value of approximately $4.9 million. No shares were forfeited during the six months ended June 30, 2019. Approximately 0.3 million shares remain available for grant under the 2018 Plan as of June 30, 2019. The Company recognized compensation cost related to outstanding restricted stock units of $0.6 million and $0.7 million for the three and six months ended June 30, 2019, respectively. These costs are included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations. As of June 30, 2019, there was $2.3 million of total unrecognized compensation cost related to unvested restricted stock units, which is expected to be recognized over a weighted average period of 1.9 years. As of June 30, 2019, there was also $2.0 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. During the three and six months ended June 30, 2019, the Company recognized $27 thousand and $65 thousand, respectively, 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 $3.2 million and $3.8 million for the two and five months ended May 31, 2018, respectively. These costs are included in “General and administrative expenses” in the unaudited condensed consolidated statements of operations.

DIVESTITURES

DIVESTITURES	6 Months Ended
	Jun. 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 addition, 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 $37.2 million in cash, net of preliminary purchase price adjustments. The transaction had an effective date of October 1, 2018. The Company recognized an impairment of $25.6 million for these properties during the six months ended June 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 $2.4 million in cash, 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 $1.6 million for these properties during the six months ended June 30, 2019. In July 2019, the Company entered into a definitive agreement to sell certain oil and gas properties in the Mid-Continent area to a third party for total consideration of $6.5 million (subject to purchase price adjustments). The transaction is expected to close during the third quarter of 2019. As of June 30, 2019, these oil and gas properties were classified as assets held for sale; $10.8 million of the assets held for sale and $6.1 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 properties. Additionally, 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 $72.0 million (subject to purchase price adjustments). The transaction is expected to close during the third quarter of 2019. The Company recognized an impairment of $72.1 million for these properties during the six months ended June 30, 2019. As of June 30, 2019, these oil and gas properties were classified as assets held for sale; $76.5 million of the assets held for sale and $4.5 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 properties.

RISK MANAGEMENT

RISK MANAGEMENT	6 Months Ended
	Jun. 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 Company’s floating rate credit facility exposes it 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. As of June 30, 2019, the Company had entered into derivatives with the following terms: Weighted Average Period Covered Hedged Volume Fixed Price Oil (Bbls): Swaps - July 2019 to December 2019 372,600 $ 63.37 Swaps - January 2020 to December 2020 667,950 $ 60.51 Natural Gas (MMBtus): Swaps - July 2019 to December 2019 12,880,000 $ 2.77 Swaps - January 2020 to December 2020 23,790,000 $ 2.71 Natural Gas Liquids (Bbls): Swaps - July 2019 to December 2019 487,600 $ 18.73 Swaps - January 2020 to December 2020 768,600 $ 17.68 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 June 30, 2019: Derivative asset $ 14,137 $ — $ 14,137 Long-term derivative asset 4,781 — 4,781 Total $ 18,918 $ — $ 18,918 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	6 Months Ended
	Jun. 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 June 30, 2019: Assets: Oil, natural gas and natural gas liquids derivatives $ 18,918 $ — $ 18,918 $ — 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 six months ended June 30, 2019. At December 31, 2018, the Company’s equity securities consisted of 4.2 million shares of common stock of Magnolia which are 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 During the three and six months ended June 30, 2019, the Company recognized an impairment expense of $72.1 million related to proved oil and natural gas properties in the Barnett Shale; which were held for sale as of June 30, 2019. During the three and six months ended June 30, 2019, the Company also recognized an impairment expense of $1.1 million and $27.2 million, respectively, 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 one month ended June 30, 2018, the Predecessor did not recognize any impairment expense related to proved oil and natural gas properties. During the two and 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 of the oil and natural gas properties sold during April 2019 were determined using the transaction price of the then pending transactions. 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	6 Months Ended
	Jun. 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 339 Revisions (6) Accretion expense 4,378 Settlements and divestitures (9,904) Liabilities held for sale (10,618) ARO as of June 30, 2019 $ 103,795 As of June 30, 2019 and December 31, 2018, $1.7 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	6 Months Ended
	Jun. 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: June 30, 2019 December 31, 2018 Exit Credit Facility (1) $ — $ 115,000 (1) During the six months ended June 30, 2019, the Company repaid the remaining outstanding amount under the Exit Credit Facility. 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 June 30, 2019, the Company had a $0.2 million letter of credit outstanding. The terms of the 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 Inter–Bank 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 addition, 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. As of June 30, 2019, the borrowing base under the Exit Credit Facility was $110.0 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%. As of June 30, 2019, the Company was in compliance with all of these financial covenants.

LEASES

LEASES	6 Months Ended
	Jun. 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 June 30, 2019. Operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets were as follows: June 30, 2019 Other assets $ 1,499 Other current liabilities 731 Other long-term liabilities 768 Total operating lease liabilities $ 1,499 Weighted average remaining lease term (in years) 2.2 Weighted average discount rate During the three and six months ended June 30, 2019, the Company paid $1.0 million and $2.0 million, respectively, of lease cost. Furthermore, during the three and six months ended June 30, 2019, the Company recognized lease cost, net of reimbursements from other working interest owners, of $0.2 million and $0.4 million, respectively, for operating leases and $0.6 million and $1.3 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 June 30, 2019, were as follows: 2019 $ 436 2020 673 2021 438 2022 41 2023 4 Total lease payments 1,592 Less: imputed interest (93) Present value of lease liabilities $ 1,499

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 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. 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 2012, pursuant to which Harvest has an additional liability of approximately $2.0 million. This amount will be paid upon ONRR review and concurrence with the accuracy of royalties per the amended filings. The Company expects to submit amended royalty filings for the period of 2013 to 2018 later in 2019, pursuant to which Harvest may have an additional liability of approximately $3.0 million. The Company recognized an accrual for the estimated liability for the period of 2009 to 2018 as of both June 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 six months ended June 30, 2019. The Company does not believe the outcome of other such disputes or legal actions, other than addressed above, will have a material effect on its unaudited condensed consolidated financial statements. No amounts, other than as described above, were accrued at June 30, 2019 or December 31, 2018.

INCOME TAXES

INCOME TAXES	6 Months Ended
	Jun. 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 Predecessor Three Months One Month Two Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Current tax position: Federal $ (261) $ — $ — State (24) — (148) Total income tax provision $ (285) $ — $ (148) Successor Predecessor Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 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. For the three and six months ended June 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

EARNINGS PER SHARE/UNIT	6 Months Ended
	Jun. 30, 2019
EARNINGS PER SHARE/UNIT [Abstract]
EARNINGS PER SHARE/UNIT	NOTE 13. EARNINGS PER SHARE/UNIT The following sets forth the calculation of earnings per share/unit, for the periods indicated: Successor Predecessor Three Months Six Months One Month Two Months Five Months Ended Ended Ended Ended Ended June 30, 2019 June 30, 2019 June 30, 2018 May 31, 2018 May 31, 2018 Net loss attributable to Successor/ Predecessor $ (60,907) $ (96,682) $ (538) $ (595,076) $ (610,525) Predecessor’s general partner’s 2% interest in net loss — — — 11,902 12,211 Net loss available to common stockholders/limited partners $ (60,907) $ (96,682) $ (538) $ (583,174) $ (598,314) Weighted average common shares/units outstanding: Basic 10,064 10,053 10,000 49,369 49,369 Dilutive effect of potential common shares/units — — — — — Diluted 10,064 10,053 10,000 49,369 49,369 Net earnings per share/unit: Basic $ (6.05) $ (9.62) $ (0.05) $ (11.81) $ (12.12) Diluted $ (6.05) $ (9.62) $ (0.05) $ (11.81) $ (12.12) Antidilutive restricted stock units (1) 241,976 241,976 — — — Antidilutive warrants (2) 800,000 800,000 800,000 — — (1) Amount represents unvested restricted stock units 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.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Jun. 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 $2.9 million and $7.2 million for general and administrative services provided during the two and five months ended May 31, 2018, respectively. 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 $3.3 million and $8.4 million in the two and five months ended May 31, 2018, respectively, 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	6 Months Ended
	Jun. 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 Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Supplemental cash flows information: Cash paid for interest $ 1,119 $ 1,185 $ 6,008 Cash paid for reorganization items 472 111 6,691 June 30, 2019 June 30, 2018 Non–cash transactions: Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ 22 $ 6,732 Accounts payable and accrued liabilities consisted of the following: June 30, 2019 December 31, 2018 Lease operating expenses $ 10,859 $ 10,035 San Juan royalties 5,000 5,000 General and administrative expenses 3,347 3,321 Production and ad valorem taxes 3,304 4,680 Current portion of ARO 1,687 2,077 Litigation settlement 679 — Costs for additions to oil and natural gas properties 22 419 Interest — 12 Other 197 602 Total $ 25,095 $ 26,146

ORGANIZATION AND NATURE OF BU_2

ORGANIZATION AND NATURE OF BUSINESS (Policy)	6 Months Ended
	Jun. 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 Six Months One Month Two Months Five Months Ended Ended Ended Ended Ended June 30, 2019 June 30, 2019 June 30, 2018 May 31, 2018 May 31, 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ 128,700 $ 128,700 Fresh start valuation adjustments — — — (700,325) (700,325) Professional fees — — (808) (13,345) (13,345) Other — — — (2,355) (2,355) Reorganization items, net $ — $ — $ (808) $ (587,325) $ (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 six months ended June 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)	6 Months Ended
	Jun. 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)	6 Months Ended
	Jun. 30, 2019
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Summary of Reorganization Items	Successor Predecessor Three Months Six Months One Month Two Months Five Months Ended Ended Ended Ended Ended June 30, 2019 June 30, 2019 June 30, 2018 May 31, 2018 May 31, 2018 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ 128,700 $ 128,700 Fresh start valuation adjustments — — — (700,325) (700,325) Professional fees — — (808) (13,345) (13,345) Other — — — (2,355) (2,355) Reorganization items, net $ — $ — $ (808) $ (587,325) $ (587,325)

REVENUE (Tables)

REVENUE (Tables)	6 Months Ended
	Jun. 30, 2019
REVENUE [Abstract]
Schedule of Revenue Disaggregated by Product and Service	The following table disaggregates revenue by significant product and service type: Successor Predecessor Three Months One Month Two Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Oil $ 8,076 $ 7,161 $ 17,555 Natural gas (1) 16,541 8,664 14,562 Natural gas liquids (1) 5,512 5,710 10,632 Oil, natural gas and natural gas liquids revenues 30,129 21,535 42,749 Transportation and marketing–related revenues 458 185 340 Total revenues $ 30,587 $ 21,720 $ 43,089 Successor Predecessor Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Oil $ 17,509 $ 7,161 $ 42,460 Natural gas (1) 40,342 8,664 40,951 Natural gas liquids (1) 15,564 5,710 26,896 Oil, natural gas and natural gas liquids revenues 73,415 21,535 110,307 Transportation and marketing–related revenues 1,018 185 724 Total revenues $ 74,433 $ 21,720 $ 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 June 30, 2019, wet gas revenues were $0.5 million which were recognized as natural gas liquids revenues. For the Successor period of the six months ended June 30, 2019, wet gas revenues were $3.8 million which were recognized as $1.5 million of natural gas revenues and $2.3 million of natural gas liquids revenues. For the Successor period of the one month ended June 30, 2018, wet gas revenues were $1.5 million which were recognized as $0.5 million of natural gas revenues and $1.0 million of natural gas liquids revenues. For the Predecessor period of the two months ended May 31, 2018, wet gas revenues were $3.3 million which were recognized as $1.4 million of natural gas revenues and $1.9 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)	6 Months Ended
	Jun. 30, 2019
RISK MANAGEMENT [Abstract]
Commodity Contracts	Weighted Average Period Covered Hedged Volume Fixed Price Oil (Bbls): Swaps - July 2019 to December 2019 372,600 $ 63.37 Swaps - January 2020 to December 2020 667,950 $ 60.51 Natural Gas (MMBtus): Swaps - July 2019 to December 2019 12,880,000 $ 2.77 Swaps - January 2020 to December 2020 23,790,000 $ 2.71 Natural Gas Liquids (Bbls): Swaps - July 2019 to December 2019 487,600 $ 18.73 Swaps - January 2020 to December 2020 768,600 $ 17.68
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 June 30, 2019: Derivative asset $ 14,137 $ — $ 14,137 Long-term derivative asset 4,781 — 4,781 Total $ 18,918 $ — $ 18,918 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)	6 Months Ended
	Jun. 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 June 30, 2019: Assets: Oil, natural gas and natural gas liquids derivatives $ 18,918 $ — $ 18,918 $ — 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 $ —

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	6 Months Ended
	Jun. 30, 2019
ASSET RETIREMENT OBLIGATIONS [Abstract]
Changes in Aggregate Asset Retirement Obligations	ARO as of December 31, 2018 $ 119,606 Liabilities incurred 339 Revisions (6) Accretion expense 4,378 Settlements and divestitures (9,904) Liabilities held for sale (10,618) ARO as of June 30, 2019 $ 103,795

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	6 Months Ended
	Jun. 30, 2019
LONG-TERM DEBT [Abstract]
Long Term Debt	June 30, 2019 December 31, 2018 Exit Credit Facility (1) $ — $ 115,000 (1) During the six months ended June 30, 2019, the Company repaid the remaining outstanding amount under the Exit Credit Facility.

LEASES (Tables)

LEASES (Tables)	6 Months Ended
	Jun. 30, 2019
LEASES
Summary of operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets	Operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets were as follows: June 30, 2019 Other assets $ 1,499 Other current liabilities 731 Other long-term liabilities 768 Total operating lease liabilities $ 1,499 Weighted average remaining lease term (in years) 2.2 Weighted average discount rate
Summary of maturities of operating lease liabilities	Maturities of operating lease liabilities as of June 30, 2019, were as follows: 2019 $ 436 2020 673 2021 438 2022 41 2023 4 Total lease payments 1,592 Less: imputed interest (93) Present value of lease liabilities $ 1,499

INCOME TAXES (Tables)

INCOME TAXES (Tables)	6 Months Ended
	Jun. 30, 2019
Income Taxes [Abstract]
Schedule of income tax provision	The Company’s income tax provision consists of the following: Successor Predecessor Three Months One Month Two Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Current tax position: Federal $ (261) $ — $ — State (24) — (148) Total income tax provision $ (285) $ — $ (148) Successor Predecessor Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Current tax position: Federal $ — $ — $ — State — — 166 Total income tax provision $ — $ — $ 166

EARNINGS PER SHARE_UNIT (Tables

EARNINGS PER SHARE/UNIT (Tables)	6 Months Ended
	Jun. 30, 2019
EARNINGS PER SHARE/UNIT [Abstract]
Calculation of Earnings Per Share/Unit	The following sets forth the calculation of earnings per share/unit, for the periods indicated: Successor Predecessor Three Months Six Months One Month Two Months Five Months Ended Ended Ended Ended Ended June 30, 2019 June 30, 2019 June 30, 2018 May 31, 2018 May 31, 2018 Net loss attributable to Successor/ Predecessor $ (60,907) $ (96,682) $ (538) $ (595,076) $ (610,525) Predecessor’s general partner’s 2% interest in net loss — — — 11,902 12,211 Net loss available to common stockholders/limited partners $ (60,907) $ (96,682) $ (538) $ (583,174) $ (598,314) Weighted average common shares/units outstanding: Basic 10,064 10,053 10,000 49,369 49,369 Dilutive effect of potential common shares/units — — — — — Diluted 10,064 10,053 10,000 49,369 49,369 Net earnings per share/unit: Basic $ (6.05) $ (9.62) $ (0.05) $ (11.81) $ (12.12) Diluted $ (6.05) $ (9.62) $ (0.05) $ (11.81) $ (12.12) Antidilutive restricted stock units (1) 241,976 241,976 — — — Antidilutive warrants (2) 800,000 800,000 800,000 — — (1) Amount represents unvested restricted stock units 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)	6 Months Ended
	Jun. 30, 2019
OTHER SUPPLEMENTAL INFORMATION [Abstract]
Supplemental Cash Flows and Non-Cash Transactions	Supplemental cash flows and noncash transactions were as follows: Successor Predecessor Six Months One Month Five Months Ended Ended Ended June 30, 2019 June 30, 2018 May 31, 2018 Supplemental cash flows information: Cash paid for interest $ 1,119 $ 1,185 $ 6,008 Cash paid for reorganization items 472 111 6,691 June 30, 2019 June 30, 2018 Non–cash transactions: Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ 22 $ 6,732
Schedule of Accounts Payable and Accrued Liabilities	Accounts payable and accrued liabilities consisted of the following: June 30, 2019 December 31, 2018 Lease operating expenses $ 10,859 $ 10,035 San Juan royalties 5,000 5,000 General and administrative expenses 3,347 3,321 Production and ad valorem taxes 3,304 4,680 Current portion of ARO 1,687 2,077 Litigation settlement 679 — Costs for additions to oil and natural gas properties 22 419 Interest — 12 Other 197 602 Total $ 25,095 $ 26,146

ORGANIZATION AND NATURE OF BU_4

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	6 Months Ended
	Jun. 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	1 Months Ended	2 Months Ended	5 Months Ended
	Jun. 30, 2018	May 31, 2018	May 31, 2018
Reorganization Adjustments Predecessor Cancellations [Abstract]
Payment of professional fees	$ (808)
Reorganization items, net	$ (808)
Predecessor
Reorganization Adjustments Predecessor Cancellations [Abstract]
Gain on settlement of liabilities subject to compromise		$ 128,700	$ 128,700
Fresh start valuation adjustments		(700,325)	(700,325)
Payment of professional fees		(13,345)	(13,345)
Other		(2,355)	(2,355)
Reorganization items, net		$ (587,325)	$ (587,325)

EMERGENCE FROM VOLUNTARY REOR_2

EMERGENCE FROM VOLUNTARY REORGANIZATION UNDER CHAPTER 11 (Narrative) (Details) - USD ($) $ in Millions	Mar. 13, 2018	Jun. 30, 2019	May 14, 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
Credit facility, maximum borrowing capacity		$ 110	$ 110
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	1 Months Ended	2 Months Ended	3 Months Ended	5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019	May 31, 2018	Jun. 30, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Total revenues	$ 21,720		$ 30,587		$ 74,433
Receivables			29,252		29,252	$ 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
Disaggregation of Revenue [Line Items]
Total revenues		$ 43,089		$ 111,031
Wet Gas Products [Member]
Disaggregation of Revenue [Line Items]
Total revenues	1,500				$ 3,800
Wet Gas Products [Member] | Predecessor
Disaggregation of Revenue [Line Items]
Total revenues		3,300		8,400
Wet Gas Natural Gas [Member]
Disaggregation of Revenue [Line Items]
Total revenues	500				1,500
Wet Gas Natural Gas [Member] | Predecessor
Disaggregation of Revenue [Line Items]
Total revenues		1,400		3,200
Wet Gas Natural Gas Liquids [Member]
Disaggregation of Revenue [Line Items]
Total revenues	$ 1,000		500		2,300
Wet Gas Natural Gas Liquids [Member] | Predecessor
Disaggregation of Revenue [Line Items]
Total revenues		$ 1,900		$ 5,200
Accounts receivable
Disaggregation of Revenue [Line Items]
Receivables			$ 26,700		$ 26,700	$ 38,300

REVENUE (Schedule of Revenue Di

REVENUE (Schedule of Revenue Disaggregated by Product and Service) (Details) - USD ($) $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended	5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019	May 31, 2018	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Disaggregated revenues	$ 21,720		$ 30,587		$ 74,433
Oil, natural gas and natural gas liquids revenues
Disaggregation of Revenue [Line Items]
Disaggregated revenues	21,535		30,129		73,415
Oil Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues	7,161		8,076		17,509
Natural Gas Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues	8,664		16,541		40,342
Natural Gas Liquids Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues	5,710		5,512		15,564
Transportation and marketing-related revenues
Disaggregation of Revenue [Line Items]
Disaggregated revenues	$ 185		$ 458		$ 1,018
Predecessor
Disaggregation of Revenue [Line Items]
Disaggregated revenues		$ 43,089		$ 111,031
Predecessor | Oil, natural gas and natural gas liquids revenues
Disaggregation of Revenue [Line Items]
Disaggregated revenues		42,749		110,307
Predecessor | Oil Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues		17,555		42,460
Predecessor | Natural Gas Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues		14,562		40,951
Predecessor | Natural Gas Liquids Product [Member]
Disaggregation of Revenue [Line Items]
Disaggregated revenues		10,632		26,896
Predecessor | Transportation and marketing-related revenues
Disaggregation of Revenue [Line Items]
Disaggregated revenues		$ 340		$ 724

SHARE-BASED COMPENSATION (Detai

SHARE-BASED COMPENSATION (Details) - USD ($) $ / shares in Units, $ in Thousands	2 Months Ended	3 Months Ended	5 Months Ended	6 Months Ended
	May 31, 2018	Jun. 30, 2019	May 31, 2018	Jun. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost				$ 763
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation, other than options		$ 2,300		$ 2,300
Unrecognized compensation, other than options, period of recognition				1 year 10 months 24 days
Restricted stock units | Vesting Subject to Future Events [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation, other than options		$ 2,000		$ 2,000
Restricted stock units | 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				132,112
Units vested				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
Units vested, fair value				$ 4,900
Restricted stock units | Management Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost		$ 600		700
Series A Preferred Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost		27		$ 65
Rate for preferred stock				8.00%
Deferred compensation arrangement with individual, fair value of shares issued				$ 200
Redemption amount, preferred stock		$ 200		$ 200
Predecessor
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost			$ 3,784
Predecessor | Unvested Phantom Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation cost	$ 3,200		$ 3,800
Employee [Member] | Series A Preferred Stock
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	6 Months Ended
	Jul. 31, 2019	Apr. 30, 2019	Jan. 31, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties				$ 16		$ 41,458
Impairment of oil and gas properties					$ 73,151	99,279
Assets held for sale					87,260	87,260
Liabilities related to assets held for sale					10,618	10,618
Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [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]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale					10,800	10,800
Liabilities related to assets held for sale					6,100	6,100
Mid Continent Area Oil and Gas Properties [Member] | Third Party Acquirer [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties	$ 6,500		$ 1,800		2,400
Preferential rights to purchase that were exercised by other working interest owners					900
Impairment of oil and gas properties						1,600
San Juan Property [Member] | Third Party Acquirer [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties		$ 37,200
Impairment of oil and gas properties						25,600
Barnett Shale Property [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment of oil and gas properties						72,100
Assets held for sale					76,500	76,500
Liabilities related to assets held for sale					$ 4,500	$ 4,500
Barnett Shale Property [Member] | Third Party Acquirer [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties	$ 72,000

RISK MANAGEMENT (Details)

RISK MANAGEMENT (Details)	6 Months Ended
	Jun. 30, 2019
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 Company's floating rate credit facility exposes it 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.

RISK MANAGEMENT (Commodity Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	Jun. 30, 2019MMBTU$ / MMBTU$ / bblbbl
Oil | Swaps - July 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls) | bbl	372,600
Weighted average fixed price | $ / bbl	63.37
Oil | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls) | bbl	667,950
Weighted average fixed price | $ / bbl	60.51
Natural Gas | Swaps - July 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MMBtus) | MMBTU	12,880,000
Weighted average fixed price | $ / MMBTU	2.77
Natural Gas | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MMBtus) | MMBTU	23,790,000
Weighted average fixed price | $ / MMBTU	2.71
Natural Gas Liquids | Swaps - July 2019 to December 2019
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls) | bbl	487,600
Weighted average fixed price | $ / bbl	18.73
Natural Gas Liquids | Swaps - January 2020 to December 2020
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (Bbls) | bbl	768,600
Weighted average fixed price | $ / bbl	17.68

RISK MANAGEMENT - Fair Value of

RISK MANAGEMENT - Fair Value of Derivatives (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Derivative Assets [Abstract]
Derivative asset, fair value	$ 18,918	$ 26,613
Derivative asset, liability		(2,662)
Derivative asset	14,137	15,452
Long–term derivative asset	4,781	8,499
Total derivative asset	18,918	23,951
Derivative Liabilities [Abstract]
Derivative liability, fair value		3,827
Derivative liability, asset		(2,662)
Derivative liability		1,165
Total derivative liability		1,165
Current Derivatives Asset
Derivative Assets [Abstract]
Derivative asset, fair value	14,137	18,048
Derivative asset, liability		(2,596)
Derivative asset	14,137	15,452
Noncurrent Derivative Asset
Derivative Assets [Abstract]
Derivative asset, fair value	4,781	8,565
Derivative asset, liability		(66)
Long–term derivative asset	$ 4,781	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	Jun. 30, 2019	Dec. 31, 2018
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative asset, fair value	$ 18,918	$ 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	18,918	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	$ 18,918	26,613
Derivative liability, fair value		$ 3,827

FAIR VALUE MEASUREMENTS (Detail

FAIR VALUE MEASUREMENTS (Details) - USD ($) shares in Millions	1 Months Ended	2 Months Ended	3 Months Ended	5 Months Ended	6 Months Ended	12 Months Ended
	Jan. 31, 2019	May 31, 2018	Jun. 30, 2019	May 31, 2018	Jun. 30, 2019	Dec. 31, 2018
Fair Value Measurements [Line Items]
Impairment of oil and gas properties			$ 73,151,000		$ 99,279,000
Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Fair Value Measurements [Line Items]
Common stock of Mangolia sold	4.2
Proceeds from sale of available-for-sale securities, equity	$ 51,700,000
Quoted Prices in Active Markets for Identical Assets (Level 1) | Magnolia Oil Gas Parent LLC And Magnolia Oil Gas Corporation [Member]
Fair Value Measurements [Line Items]
Common stock of Magnolia traded in public exchange						4.2
Nonrecurring basis | Proved Property Barnett Shale
Fair Value Measurements [Line Items]
Impairment of oil and gas properties			72,100,000		72,100,000
Nonrecurring basis | Proved Property San Juan Basin and Mid-continent Area
Fair Value Measurements [Line Items]
Impairment of oil and gas properties			$ 1,100,000		$ 27,200,000
Predecessor
Fair Value Measurements [Line Items]
Impairment of oil and gas properties				$ 3,000
Predecessor | Nonrecurring basis | Proved Properties [Member]
Fair Value Measurements [Line Items]
Impairment of oil and gas properties		$ 0		$ 0

ASSET RETIREMENT OBLIGATIONS (C

ASSET RETIREMENT OBLIGATIONS (Changes in Aggregate Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2019	Dec. 31, 2018
ASSET RETIREMENT OBLIGATIONS [Abstract]
Asset retirement obligation, current		$ 1,687	$ 1,687	$ 2,077
Changes in aggregate ARO
Balance at beginning of period			119,606
Liabilities incurred			339
Revisions			(6)
Accretion expense	$ 789	2,168	4,378
Settlements and divestitures			(9,904)
Liabilities held for sale			(10,618)
Balance at end of period		$ 103,795	$ 103,795

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	6 Months Ended
	Jun. 30, 2019	May 14, 2019	Mar. 31, 2019	Dec. 31, 2018
Exit Credit Facility
Credit facility, maximum borrowing capacity	$ 110	$ 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 percentate, dividends or distributions to shareholders, minimum	15
Revolving Credit Facility
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
Debt instrument, covenant compliance	As of June 30, 2019, the Company was in compliance with all of these financial covenants
Revolving Credit Facility | Secured Debt
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			$ 2
Line of credit, borrowing base			$ 260.3
Standby Letters of Credit
Exit Credit Facility
Credit facility, maximum borrowing capacity	$ 50
Letter of credit outstanding	$ 0.2
Minimum | Revolving Credit Facility
Exit Credit Facility
Debt instrument covenant percentage of total value of mortgaged properties evaluated in reserve report	95.00%
Maximum | Revolving Credit Facility
Exit Credit Facility
Total debt to earnings ratio required under credit facility	4
Borrowing Base Determination, Period One | Revolving Credit Facility
Exit Credit Facility
Borrowing base scheduled redetermination date	--04-01
Borrowing Base Determination, Period Two | Revolving Credit Facility
Exit Credit Facility
Borrowing base scheduled redetermination date	--10-01

LEASES (Details)

LEASES (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Jan. 01, 2019
Lessee, Lease, Description [Line Items]
Operating lease right of use asset	$ 1,499	$ 1,499
Operating lease liability	1,499	$ 1,499
Option to extend		true
Short-term lease, cost	600	$ 1,300
Operating lease, payments	$ 1,000	$ 2,000
Minimum
Lessee, Lease, Description [Line Items]
Remaining lease terms	1 year	1 year
Maximum
Lessee, Lease, Description [Line Items]
Remaining lease terms	4 years	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	Jun. 30, 2019USD ($)
Operating lease right of use assets and lease liabilities included on the unaudited condensed consolidated balance sheets
Right of use assets	$ 1,499
Other assets	us-gaap:OtherAssetsNoncurrent
Lease liabilities, current	$ 731
Other current liabilities	us-gaap:OtherLiabilitiesCurrent
Lease liabilities, noncurrent	$ 768
Other long-term liabilities	us-gaap:OtherLiabilitiesNoncurrent
Total operating lease liabilities	$ 1,499
Weighted average remaining lease term (in years)	2 years 2 months 12 days
Weighted average discount rate	5.80%

LEASES - Supplemental Cash Flow

LEASES - Supplemental Cash Flows and Noncash Transactions (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
LEASES
Supplemental cash flows information: Cash paid for operating leases	$ 1	$ 2
Lease cost, net of reimbursements from other working interest owners	$ 0.2	$ 0.4

LEASES - Maturities of Operatin

LEASES - Maturities of Operating Lease Liabilities (Details) $ in Thousands	Jun. 30, 2019USD ($)
Maturities of operating lease liabilities
2019	$ 436
2020	673
2021	438
2022	41
2023	4
Total lease payments	1,592
Less: imputed interest	(93)
Present value of lease liabilities	$ 1,499

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	Jun. 04, 2018USD ($)employee	Jun. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Long-term Purchase Commitment [Line Items]
Litigation settlement		$ 0.7
Loss contingency accrual		0	$ 0
Other Commitment for Periods 2009 through 2012 [Member]
Long-term Purchase Commitment [Line Items]
Additional liability		2
Other Commitment for Periods 2013 through 2018 [Member]
Long-term Purchase Commitment [Line Items]
Additional liability		$ 3
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

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	2 Months Ended	3 Months Ended	5 Months Ended
	May 31, 2018	Jun. 30, 2019	May 31, 2018
Income tax expense		$ (285)
Predecessor
Income tax expense	$ (148)		$ 166

INCOME TAXES (Schedule of incom

INCOME TAXES (Schedule of income tax provision) (Details) - USD ($) $ in Thousands	2 Months Ended	3 Months Ended	5 Months Ended
	May 31, 2018	Jun. 30, 2019	May 31, 2018
Federal		$ (261)
State		(24)
Total income tax provision		$ (285)
Predecessor
State	$ (148)		$ 166
Total income tax provision	$ (148)		$ 166

EARNINGS PER SHARE_UNIT (Detail

EARNINGS PER SHARE/UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	1 Months Ended	2 Months Ended	3 Months Ended			5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019	Mar. 31, 2019	Mar. 31, 2018	May 31, 2018	Jun. 30, 2019
Earnings Per Share Disclosure [Line Items]
Net loss	$ (538)		$ (60,907)	$ (35,775)			$ (96,682)
Net loss available to common stockholders/limited partners	$ (538)		$ (60,907)				$ (96,682)
Weighted average limited partner units outstanding:
Weighted average common shares/units outstanding, basic	10,000		10,064				10,053
Weighted average common shares/units outstanding, diluted	10,000		10,064				10,053
Basic and diluted earnings per share / unit:
Basic, share/unit	$ (0.05)		$ (6.05)				$ (9.62)
Diluted, share/unit	$ (0.05)		(6.05)				(9.62)
Exercise price of warrants			$ 37.48				$ 37.48
Restricted stock units
Basic and diluted earnings per share / unit:
Equity awards not included in computation of diluted net income (loss) per limited partner unit			241,976				241,976
Antidilutive warrants
Basic and diluted earnings per share / unit:
Equity awards not included in computation of diluted net income (loss) per limited partner unit	800,000		800,000				800,000
Predecessor
Earnings Per Share Disclosure [Line Items]
Net loss		$ (595,076)			$ (15,449)	$ (610,525)
General partner's 2% interest in net loss		11,902				12,211
Net loss available to common stockholders/limited partners		$ (583,174)				$ (598,314)
Weighted average limited partner units outstanding:
Weighted average common shares/units outstanding, basic		49,369				49,369
Weighted average common shares/units outstanding, diluted		49,369				49,369
Basic and diluted earnings per share / unit:
Basic, share/unit		$ (11.81)				$ (12.12)
Diluted, share/unit		$ (11.81)				$ (12.12)

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - Predecessor - USD ($) $ in Millions	2 Months Ended	5 Months Ended
	May 31, 2018	May 31, 2018
EnerVest, Ltd.
Related Party Transaction [Line Items]
Administrative fees paid to related party	$ 2.9	$ 7.2
Direct expenses incurred and reimbursed to related party	$ 3.3	$ 8.4
EV Energy GP | EnerVest, Ltd.
Related Party Transaction [Line Items]
Percentage of general partnership interest		71.25%
EVEP | EV Energy GP
Related Party Transaction [Line Items]
Percentage of general partnership interest		2.00%

OTHER SUPPLEMENTAL INFORMATIO_2

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) - USD ($) $ in Thousands	1 Months Ended	5 Months Ended	6 Months Ended
	Jun. 30, 2018	May 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Supplemental cash flows information:
Cash paid for interest	$ 1,185		$ 1,119
Cash paid for reorganization items	$ 111		472
Non-cash transactions:
Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities			$ 22	$ 6,732
Predecessor
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	Jun. 30, 2019	Dec. 31, 2018
Other Supplemental Information Disclosure [Abstract]
Lease operating expenses	$ 10,859	$ 10,035
San Juan royalties	5,000	5,000
General and administrative expenses	3,347	3,321
Production and ad valorem taxes	3,304	4,680
Current portion of ARO	1,687	2,077
Litigation settlement	679
Costs for additions to oil and natural gas properties	22	419
Interest		12
Other	197	602
Total	$ 25,095	$ 26,146