Harvest Oil & Gas (HRST) 10-Q 9 Aug 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 29, 2016
Document Documentand Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Trading Symbol	evep
Entity Registrant Name	EV Energy Partners, LP
Entity Central Index Key	1,361,937
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		49,055,214

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 2,846	$ 20,415
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	31,772	24,285
Other	1,282	7,137
Derivative asset	13,940	60,662
Other current assets	3,193	3,057
Total current assets	53,033	115,556
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; June 30, 2016, $1,031; December 31, 2015, $971,499	1,733,698	1,790,455
Other property, net of accumulated depreciation and amortization; June 30, 2016, $986; December 31, 2015, $970	1,018	1,019
Long-term derivative asset	665	10,741
Other assets	4,588	5,831
Total assets	1,793,002	1,923,602
Current liabilities:
Third party	34,503	43,135
Related party	11,684	5,952
Income taxes		11,657
Derivative liability	3,265
Total current liabilities	49,452	60,744
Asset retirement obligations	176,211	174,003
Long-term debt	621,652	688,614
Long-term derivative liability	4,693
Other long-term liabilities	1,332	1,682
Commitments and contingencies
Owners' equity:
Common unitholders - 49,055,214 units and 48,871,399 units issued and outstanding as of June 30, 2016 and December 31, 2015, respectively	953,788	1,011,509
General partner interest	(14,126)	(12,950)
Total owners' equity	939,662	998,559
Total liabilities and owners' equity	$ 1,793,002	$ 1,923,602

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$ 1,031,352	$ 971,499
Other property, accumulated depreciation and amortization	$ 986	$ 970
Common Unitholders
Common unitholders, units issued	49,055,214	48,871,399
Common unitholders, units outstanding	49,055,214	48,871,399

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Oil, natural gas and natural gas liquids revenues	$ 42,365	$ 43,722	$ 80,104	$ 90,147
Transportation and marketing-related revenues	466	734	977	1,551
Total revenues	42,831	44,456	81,081	91,698
Operating costs and expenses:
Lease operating expenses	26,046	23,800	54,961	47,324
Cost of purchased natural gas	305	504	641	1,078
Dry hole and exploration costs	771	272	901	686
Production taxes	1,704	1,603	3,375	3,351
Accretion expense on obligations	2,049	1,213	4,089	2,414
Depreciation, depletion and amortization	31,648	25,337	59,853	51,233
General and administrative expenses	7,970	7,944	16,348	20,359
Impairment of oil and natural gas properties	1,997	48,284	2,684	106,457
Gain on settlement of contract			(3,185)
Loss (gain) on sales of oil and natural gas properties		6		(531)
Total operating costs and expenses	72,490	108,963	139,667	232,371
Operating loss	(29,659)	(64,507)	(58,586)	(140,673)
Other income (expense), net:
(Loss) gain on derivatives, net	(35,585)	(9,246)	(25,751)	14,364
Interest expense	(11,844)	(13,101)	(22,665)	(27,236)
Gain on early extinguishment of debt	47,695		47,695
Other income (expense), net	209	41	964	(155)
Total other income (expense), net	475	(22,306)	243	(13,027)
Loss from continuing operations before income taxes	(29,184)	(86,813)	(58,343)	(153,700)
Income taxes	191	473	350	623
Loss from continuing operations	(28,993)	(86,340)	(57,993)	(153,077)
Income from discontinued operations		250,442		255,512
Net (loss) income	$ (28,993)	$ 164,102	$ (57,993)	$ 102,435
Basic and diluted earnings per limited partner unit:
Loss per limited partner unit (basic and diluted), continuing	$ (0.58)	$ (1.74)	$ (1.16)	$ (3.08)
Earnings per limited partner unit (basic and diluted), discontinued		4.99		5.11
Net (loss) income	$ (0.58)	$ 3.25	$ (1.16)	$ 2.03
Weighted average limited partner units outstanding:
Weighted average limited partner units outstanding (basic and diluted)	49,055	48,871	49,041	48,833
Distributions declared per unit		$ 0.50		$ 1

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Changes in Owners' Equity - USD ($) $ in Thousands	Common Unitholders	General Partner Interest	Total
Beginning Balance at Dec. 31, 2014	$ 1,077,826	$ (11,713)	$ 1,066,113
Contributions from general partner		91	91
Distributions	(49,498)	(997)	(50,495)
Equity-based compensation	7,148	146	7,294
Net income (loss)	100,386	2,049	102,435
Ending Balance at Jun. 30, 2015	1,135,862	(10,424)	1,125,438
Beginning Balance at Dec. 31, 2015	1,011,509	(12,950)	998,559
Distributions	(3,793)	(75)	(3,868)
Equity-based compensation	2,905	59	2,964
Net income (loss)	(56,833)	(1,160)	(57,993)
Ending Balance at Jun. 30, 2016	$ 953,788	$ (14,126)	$ 939,662

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net income (loss)	$ (57,993)	$ 102,435
Adjustments to reconcile net (loss) income to net cash flows provided by operating activities:
Income from discontinued operations		(255,512)
Amortization of volumetric production payment liability	(2,043)
Accretion expense on obligations	4,089	2,414
Depreciation, depletion and amortization	59,853	51,233
Equity-based compensation cost	2,964	7,294
Impairment of oil and natural gas properties	2,684	106,457
Loss (gain) on sales of oil and natural gas properties		(531)
Loss (gain) on derivatives, net	25,751	(14,364)
Cash settlements of matured derivatives contracts	36,506	62,477
Gain on early extinguishment of debt	(47,695)
Other	1,760	890
Changes in operating assets and liabilities:
Accounts receivable	(1,835)	6,350
Other current assets	(259)	457
Accounts payable and accrued liabilities	2,510	4,714
Income taxes	(11,657)	(583)
Other, net	(201)
Net cash flows provided by operating activities from continuing operations	14,434	73,731
Net cash flows used in operating activities from discontinued operations		(372)
Net cash flows provided by operating activities	14,434	73,359
Cash flows from investing activities:
Additions to oil and natural gas properties	(12,988)	(44,854)
Proceeds from sale of oil and natural gas properties	2,420	774
Cash settlements from acquired derivative contracts	2,499
Restricted cash		33,768
Other	33	32
Net cash flows used in investing activities from continuing operations	(8,036)	(10,280)
Net cash flows provided by investing activities from discontinued operations		572,160
Net cash flows (used in) provided by investing activities	(8,036)	561,880
Cash flows from financing activities:
Repayment of long-term debt borrowings	(33,000)	(561,000)
Long-term debt borrowings	48,000	30,000
Redemption of Senior Notes due 2019	(34,978)
Loan costs incurred	(121)	(3,277)
Contributions from general partner		91
Distributions paid	(3,868)	(50,495)
Net cash flows used in financing activities	(23,967)	(584,681)
(Decrease) increase in cash and cash equivalents	(17,569)	50,558
Cash and cash equivalents - beginning of year	20,415	8,255
Cash and cash equivalents - end of period	$ 2,846	$ 58,813

ORGANIZATION AND NATURE OF BUSI

ORGANIZATION AND NATURE OF BUSINESS	6 Months Ended
	Jun. 30, 2016
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
ORGANIZATION AND NATURE OF BUSINESS	NOTE 1. ORGANIZATION AND NATURE OF BUSINESS Nature of Operations EV Energy Partners, L.P. together with its wholly owned subsidiaries (“we,” “our” or “us”) is a publicly held limited partnership. Our general partner is EV Energy GP, L.P. (“EV Energy GP”), a Delaware limited partnership, and the general partner of our general partner is EV Management, LLC (“EV Management”), a Delaware limited liability company. EV Management is a wholly owned subsidiary of EnerVest, Ltd. (“EnerVest”), a Texas limited partnership. EnerVest and its affiliates also have a significant interest in us through their 71.25 % ownership of EV Energy GP which, in turn, owns a 2 % general partner interest in us and all of our incentive distribution rights. Basis of Presentation Our 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 have been condensed or omitted. We believe 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 included in Item 8 of our Annual Report on Form 10–K for the year ended December 31, 2015. All intercompany accounts and transactions have been eliminated in consolidation. In the Notes to Unaudited Condensed Consolidated Financial Statements, all dollar and unit amounts in tabulations are in thousands of dollars and units, respectively, unless otherwise indicated.  Subsequent Events  We evaluated subsequent events for appropriate accounting and disclosure through the date these unaudited condensed consolidated financial statements were issued.

EQUITY-BASED COMPENSATION

EQUITY-BASED COMPENSATION	6 Months Ended
	Jun. 30, 2016
EQUITY-BASED COMPENSATION [Abstract]
EQUITY-BASED COMPENSATION	NOTE 2. EQUITY–BASED COMPENSATION We grant various forms of equity–based awards to employees, consultants and directors of EV Management and its affiliates who perform services for us. These equity–based awards consist of phantom units and performance units.  We estimated the fair value of the phantom units using the Black–Scholes option pricing model. Compensation cost is recognized for these phantom units on a straight–line basis over the service period and is net of estimated forfeitures. These phantom units are subject to graded vesting over a four year period. We recognized compensation cost related to these phantom units of $1.4 million and $2.3 million in the three months ended June 30 , 2016 and 2015, respectively , and $3.0 million and $7.1 million in the six months ended June 30, 2016 and 2015, respectively . These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.  As of June 30, 2016, there was $10.9 million of total unrecognized compensation cost related to unvested phantom units which is expected to be recognized over a weighted average period of 2.2 years. In September 2011, we issued 0.3 million performance units to certain employees and executive officers of EV Management and its affiliates. These performance units were fully vested as of January 2015, and we recognized compensation cost related to these performance units of $0.2 million in the six months ended June 30 , 2015. These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.  

ACQUISITIONS

ACQUISITIONS	6 Months Ended
	Jun. 30, 2016
ACQUISITIONS [Abstract]
ACQUISITIONS	NOTE 3. ACQUISITIONS  In October 2015, we made the following acquisitions from certain institutional partnerships managed by EnerVest, a related party:  · we acquired Belden & Blake Corporation (“Belden”) for $111.1 million;  · we acquired oil and natural gas properties in the Austin Chalk for $25.9 million; and  · we acquired oil and natural gas properties in the Appalachian Basin and the San Juan Basin for $122.0 million.  These acquisitions were not accounted for as common control transactions as EnerVest does not control the institutional partnerships that sold the oil and natural gas properties.  As part of the acquisition of oil and natural gas properties in the San Juan Basin, we assumed an obligation to deliver approximately 2.4 billion cubic feet (“Bcf”) of natural gas through December 31, 2016 under previously existing volumetric production payment (“VPP”) agreements. Under these agreements, certain of these oil and natural gas properties are subject to fixed–term overriding royalty interests which had been conveyed to the VPP purchaser. While we are obligated under these agreements to produce and deliver to the purchaser its portion of future natural gas production from these oil and natural gas properties, we retain control of these oil and natural gas properties and rights to future development drilling. If production from the oil and natural gas properties subject to the VPP is inadequate to deliver the natural gas provided for in the VPP, we have an obligation to make up the shortfall in accordance with the provisions of the agreements. At June 30, 2016 and December 31, 2015, the remaining obligation under these agreements was approximately 0.9 Bcf and 1.9 Bcf, respectively, of natural gas.  At June 30, 2016 and December 31, 2015, we have recorded a liability of $2.0 million and $4.0 million, respectively, which is included in “Accounts payable and accrued liabilities” in our unaudited condensed consolidated balance sheets, for the cost to produce and deliver to the VPP purchasers their portion of future natural gas production from these oil and natural gas properties. In the three months and six months ended June 30, 2016, we recorded $0.04 million and $0.1 million, respectively, of accretion expense related to this VPP obligation.  We accounted for these acquisitions as business combinations. The following table reflects pro forma revenues and net income for the three months and six months ended June 30, 2015 as if these acquisitions had taken place on January 1, 2015. These unaudited pro forma amounts do not purport to be indicative of the results that would have actually been obtained during the periods presented or that may be obtained in the future.      Three Months Six Months  Ended Ended  June 30, June 30,  2015 2015  Revenues:  Historical $ 44,456 $ 91,698  Belden 7,919 16,031  Austin Chalk 3,414 6,626  Appalachian and San Juan Basins 8,245 16,210  Pro forma revenues $ 64,034 $ 130,565   Net income:  Historical $ 164,102 $ 102,435  Belden (59,079) (59,702)  Austin Chalk 985 1,558  Appalachian and San Juan Basins 696 654  Pro forma net income $ 106,704 $ 44,945 

RISK MANAGEMENT

RISK MANAGEMENT	6 Months Ended
	Jun. 30, 2016
RISK MANAGEMENT [Abstract]
RISK MANAGEMENT	NOTE 4. RISK MANAGEMENT Our business activities expose us to risks associated with changes in the market price of oil, natural gas and natural gas liquids. In addition, our floating rate credit facility exposes us 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. We use derivatives to reduce our risk of volatility in the prices of oil, natural gas and natural gas liquids and interest rates. Our policies do not permit the use of derivatives for speculative purposes. We have elected not to designate any of our derivatives as hedging instruments . Accordingly, c hanges in the fair value of our derivatives are recorded immediately to operations as “ (Loss) g ain on derivatives, net” in our unaudited condensed consolidated statements of operations. As of June 30, 2016, we had entered into commodity contracts with the following terms:          Weighted Weighted Weighted  Average Average Average  Hedged Fixed Floor Ceiling  Period Covered Volume Price Price Price  Oil (MBbls):  Swaps – July 2016 to September 2016 368.0 $ 53.75 $ $  Swaps – October 2016 to December 2016 92.0 90.14   Natural Gas (MmmBtus):  Swaps – July 2016 to December 2016 22,632.0 3.42  Swaps – 2017 32,850.0 3.07  Collars – 2017 10,950.0 2.75 3.27   Natural Gas Liquids (MBbls):  Swap – July 2016 to December 2016 1.8 9.14  As of June 30, 2016, we had entered into interest rate swaps with the following terms:       Period Covered Notional Amount Floating Rate Fixed Rate  January 2017 – December 2017 $ 100,000 1 Month LIBOR 1.039%  January 2018 – September 2020 100,000 1 Month LIBOR 1.795% The following table sets forth the fair values and classification of our outstanding derivatives:      Net Amounts  Gross Amounts of Assets  Offset in the Presented in the  Gross Unaudited Unaudited  Amounts of Condensed Condensed  Recognized Consolidated Consolidated  Assets Balance Sheet Balance Sheet  Derivatives:  As of June 30, 2016:  Derivative asset $ 19,014 $ (5,074) $ 13,940  Long–term derivative asset 1,345 (680) 665  Total $ 20,359 $ (5,754) $ 14,605   As of December 31, 2015:  Derivative asset $ 60,662 $ - $ 60,662  Long–term derivative asset 10,741 - 10,741  Total $ 71,403 $ - $ 71,403      Net Amounts  Gross Amounts of Liabilities  Offset in the Presented in the  Gross Unaudited Unaudited  Amounts of Condensed Condensed  Recognized Consolidated Consolidated  Liabilities Balance Sheet Balance Sheet  Derivatives:  As of June 30, 2016:  Derivative liability $ 8,339 $ (5,074) $ 3,265  Long–term derivative liability 5,373 (680) 4,693  Total $ 13,712 $ (5,754) $ 7,958  We have entered into master netting arrangements with our counterparties. The amounts above are presented on a net basis in our unaudited condensed consolidated balance sheets when such amounts are with the same counterparty. In addition, w e have recorded accounts payable and receivable balances related to our settled derivatives that are subject to our master netting agreements. These amounts are not included in the above table; however, under our master netting agreements, we have the right to offset these positions against our forward exposure related to outstanding derivatives.  Should our credit facility become due and payable because of an event of default, our derivatives that are in a net liability position could also become due and payable. We could also be required to post cash collateral related to these derivatives under certain circumstances. As of June 30, 2016 and December 31, 2015, we were not required to post any collateral nor did we hold any collateral associated with our derivatives.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2016
FAIR VALUE MEASUREMENTS [Abstract]
FAIR VALUE MEASUREMENTS	NOTE 5. 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 our own assumptions used to measure assets and liabilities at fair value.  Recurring Basis  The following table presents the fair value hierarchy for our 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  Markets Significant  for Other Significant  Identical Observable Unobservable  Assets Inputs Inputs  Fair Value (Level 1) (Level 2) (Level 3)  As of June 30, 2016:  Assets - Oil, natural gas and natural gas  liquids derivatives $ 20,359 $ – $ 20,359 $ –   Liabilities:  Oil, natural gas and natural gas  liquids derivatives $ 11,172 $ – $ 11,172 $ –  Interest rate swaps 2,540 – 2,540 –  $ 13,712 $ – $ 13,712 $ –   As of December 31, 2015:  Assets:  Oil, natural gas and natural gas  liquids derivatives $ 70,356 $ – $ 70,356 $ –  Interest rate swaps 1,047 – 1,047 –  $ 71,403 $ – $ 71,403 $ –  Our 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, we have categorized these derivatives as Level 2. We value 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. Our estimates of fair value have been determined at discrete points in time based on relevant market data. There were no changes in valuation techniques or related inputs in the three months ended June 30, 2016.  Nonrecurring Basis  In the six months ended June 30, 2015, as a result of a reduction in estimated future net cash flows primarily caused by the continuing decrease in prices, we recognized a $58. 2 million impairment charge to write down oil and natural gas properties to their fair value of $31.4 million.  The fair values were determined using the income approach and were based on the expected present value of the future net cash flows from proved reserves. Significant Level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis included estimates of future prices, production costs, development expenditures, anticipated production of our estimated reserves, appropriate risk–adjusted discount rates and other relevant data.  Financial Instruments The estimated fair values of our financial instruments have been determined at discrete points in time based on relevant market information. Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, derivatives and long–term debt. The carrying amounts of our financial instruments other than derivatives and 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 our credit facility approximates fair value because the credit facility’s variable interest rate resets frequently and approximates current market rates available to us. The estimated fair value of our senior notes due 2019 was $ 208.6 million and $211.9 million at June 30, 2016 and December 31, 2015, respectively, which differs from the carrying value of $341.7 million and $423.6 million at June 30, 2016 and December 31, 2015, respectively. T he fair value of the senior notes due 2019 was determined using Level 2 inputs .

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	6 Months Ended
	Jun. 30, 2016
ASSET RETIREMENT OBLIGATIONS [Abstract]
ASSET RETIREMENT OBLIGATIONS	NOTE 6. ASSET RETIREMENT OBLIGATIONS We record an asset retirement obligation (“ARO”) and capitalize 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:       2016 2015  Balance as of January 1 $ 176,933 $ 105,773  Liabilities incurred 362 367  Revisions 82 (1)  Accretion expense 3,999 2,414  Settlements and divestitures (2,235) (955)  Balance as of June 30 $ 179,141 $ 107,598 As of both June 30, 2016 and December 31, 2015, $ 2.9 million of our ARO is classified as current and is included in “Accounts payable and accrued liabilities” in our unaudited condensed consolidated balance sheets.

LONG-TERM DEBT

LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2016
LONG-TERM DEBT [Abstract]
LONG-TERM DEBT	NOTE 7. LONG–TERM DEBT Long–term debt, net consisted of the following:      June 30, December 31,  2016 2015   Credit facility $ 280,000 $ 265,000  8.0% senior notes due 2019:  Principal outstanding 343,348 426,022  Unamortized discount and debt issuance costs (1) (3,546) (5,116)  Unaccreted premium (2) 1,850 2,708  341,652 423,614  Total $ 621,652 $ 688,614 _____________ (1) Imputed interest rate of 9.23 % and 8.87% for June 30, 2016 and December 31, 2015, respectively.  (2) Imputed interest rate of 6.86 % and 7.35% for June 30, 2016 and December 31, 2015, respectively.  Credit Facility As of June 30, 2016, we have a $ 1.0 billion credit facility that expires in February 2020 . Borrowings under the facility are secured by a first priority lien on substantially all of our oil and natural gas properties. The facility allows for up to $35.0 million in cash, reduced by the amount of any quarterly distributions for the remainder of 2016, to be used for the redemption of our senior notes due 2019 (see below) and limits cash held by us to the greater of 5% of the current borrowing base or $30.0 million. We also may use up to $ 100.0 million of available borrowing capacity for letters of credit. As of June 30, 2016, we have a $0.4 million letter of credit outstanding. The facility requires the maintenance of certain financial covenants, and, as of June 30, 2016, we were in compliance with these financial covenants.  The facility does not require any repayments of amounts outstanding until it expires in February 2020. Borrowings under the facility bear interest at a floating rate based on, at our election, a base rate or the London Inter–Bank Offered Rate plus applicable premiums based on the percent of the borrowing base that we have outstanding (weighted average effective interest rate of 4.58 % and 3.50% at June 30, 2016 and 2015, respectively). Borrowings under the facility may not exceed a “borrowing base” determined by the lenders under the facility based on our oil and natural gas reserves. As of June 30, 2016, the borrowing base under the facility was $ 450.0 million. The borrowing base is subject to scheduled redeterminations as of April 1 and October 1 of each year with an additional redetermination once per calendar year at our request or at the request of the lenders and with one calculation that may be made at our request during each calendar year in connection with material acquisitions or divestitures of properties.  8.0% Senior Notes due 2019 Our senior notes due 2019 are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis, by all of our existing subsidiaries other than EV Energy Finance Corp. (“Finance”), which is a co–issuer of the Notes. Neither EV Energy Partners, L.P. nor Finance have independent assets or operations apart from the assets and operations of our subsidiaries.  In the three months ended June 30, 2016, we redeemed $82.7 million of our senior notes due 2019 for $35.0 million, resulting in a gain on the early extinguishment of debt of $47.7 million.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2016
COMMITMENTS AND CONTINGENCIES [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 8. COMMITMENTS AND CONTINGENCIES  We are involved in disputes or legal actions arising in the ordinary course of business. We do not believe the outcome of such disputes or legal actions will have a material effect on our unaudited condensed consolidated financial statements and no amounts have been accrued at June 30, 2016 or December 31, 2015. 

OWNERS' EQUITY

OWNERS' EQUITY	6 Months Ended
	Jun. 30, 2016
OWNERS' EQUITY [Abstract]
OWNERS' EQUITY	NOTE 9. OWNERS’ EQUITY Units Outstanding At June 30, 2016, owners’ equity consists of 49,055,214 common units, representing a 98 % limited partnership interest in us, and a 2 % general partnership interest. Issuance of Units In January 2016, we issued 0.2 million common units related to the vesting of equity–based awards. Cash Distributions On January 25, 2016, the board of directors of EV Management declared a $ 0.075 per unit distribution for the fourth quarter of 2015 on all outstanding units. The distribution of $ 3.9 million was paid on February 12, 2016 to unitholders of record at the close of business on February 5, 2016 . In April 2016, the board of directors of EV Management announced that it had elected to suspend distributions for the first quarter of 2016. The board of directors also elected to suspend distributions for the second quarter of 2016.

DISCONTINUTED OPERATIONS

DISCONTINUTED OPERATIONS	6 Months Ended
	Jun. 30, 2016
DISCONTINUED OPERATIONS [Abstract]
DISCONTINUTED OPERATIONS	NOTE 10. DISCONTINUED OPERATIONS  In 2015, we reclassified our unaudited condensed consolidated financial statements to reflect the operations of our midstream segment as discontinued operations due to the sales of our interest in Cardinal Gas Services, LLC in October 2014 and our interest in Utica East Ohio Midstream LLC in June 2015. Summarized financial information for our midstream segment is as follows:       Three Months Ended Six Months Ended  June 30, June 30,  2015 2015   Revenues $ 45,183 $ 93,726  Operating income 24,697 49,171  Net income 24,781 49,525 

EARNINGS PER LIMITED PARTNER UN

EARNINGS PER LIMITED PARTNER UNIT	6 Months Ended
	Jun. 30, 2016
EARNINGS PER LIMITED PARTNER UNIT [Abstract]
EARNINGS PER LIMITED PARTNER UNIT	NOTE 11. EARNINGS PER LIMITED PARTNER UNIT The following sets forth the calculation of earnings per limited partner unit:     Three Months Ended Six Months Ended  June 30, June 30,  2016 2015 2016 2015  Loss from continuing operations $ (28,993) $ (86,340) $ (57,993) $ (153,077)  General partner's 2% interest in loss from  continuing operations 580 1,727 1,160 3,061  Earnings attributable to unvested phantom units - (315) - (657)  Limited partners' interest in loss from  continuing operations $ (28,413) $ (84,928) $ (56,833) $ (150,673)   Earnings per limited partner unit (basic and  diluted) $ (0.58) $ (1.74) $ (1.16) $ (3.08)   Income from discontinued operations $ - $ 250,442 $ - $ 255,512  General partner's 2% interest in income  from discontinued operations - (5,009) - (5,110)  Earnings attributable to unvested phantom units - (1,732) - (675)  Limited partners' interest in income from discontinued operations  discontinued operations $ - $ 243,701 $ - $ 249,727   Earnings per limited partner unit (basic and  diluted) $ - $ 4.99 $ - $ 5.11   Net (loss) income $ (28,993) $ 164,102 $ (57,993) $ 102,435  General partner’s 2% interest in net (loss)  income 580 (3,282) 1,160 (2,049)  Earnings attributable to unvested phantom units - (2,047) - (1,332)  Limited partners’ interest in net (loss) income $ (28,413) $ 158,773 $ (56,833) $ 99,054   Earnings per limited partner unit (basic and  diluted) $ (0.58) $ 3.25 $ (1.16) $ 2.03   Weighted average limited partner units outstanding (basic and diluted) 49,055 48,871 49,041 48,833 

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Jun. 30, 2016
RELATED PARTY TRANSACTIONS [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 12. RELATED PARTY TRANSACTIONS Pursuant to an omnibus agreement, we paid EnerVest $ 4.0 million and $ 3. 3 million in the three months ended June 30, 2016 and 2015, respectively, and $8.0 million and $6.6 million in the six months ended June 30, 2016 and 2015, respectively, in monthly administrative fees for providing us general and administrative services. These fees are based on an allocation of charges between EnerVest and us based on the estimated use of such services by each party, and we believe that the allocation method employed by EnerVest is reasonable and reflective of the estimated level of costs we would have incurred on a standalone basis. These fees are included in general and administrative expenses in our unaudited condensed consolidated statements of operations. W e have entered into operating agreements with EnerVest whereby a wholly owned subsidiary of EnerVest acts as contract operator of the oil and natural gas wells and related gathering systems and production facilities in which we own an interest. We reimbursed EnerVest approximately $ 4.6 million and $ 3. 7 million in the three months ended June 30, 2016 and 2015, respectively, and $10.8 million and $7.8 million in the six months ended June 30, 2016 and 2015, respectively, for direct expenses incurred in the operation of our wells and related gathering systems and production facilities and for the allocable share of the costs of EnerVest employees who performed services on our properties. As the vast majority of such expenses are charged to us on an actual basis (i.e., no mark–up or subsidy is charged or received by EnerVest), we believe that the aforementioned services were provided to us at fair and reasonable rates relative to the prevailing market and are representative of the costs that would have been incurred on a standalone basis. These costs are included in lease operating expenses in our unaudited condensed consolidated statements of operations. Additionally, in its role as contract operator, this EnerVest subsidiary also collects proceeds from oil and natural gas sales and distributes them to us and other working interest owners.

OTHER SUPPLEMENTAL INFORMATION

OTHER SUPPLEMENTAL INFORMATION	6 Months Ended
	Jun. 30, 2016
OTHER SUPPLEMENTAL INFORMATION [Abstract]
OTHER SUPPLEMENTAL INFORMATION	NOTE 13. OTHER SUPPLEMENTAL INFORMATION Supplemental cash flows and noncash transactions were as follows:      Six Months Ended  June 30,  2016 2015  Supplemental cash flows information:  Cash paid for interest $ 20,984 $ 26,460  Cash paid for income taxes 11,657 (155)        As of June 30,  2016 2015   Noncash transaction - costs for additions to oil and natural gas properties in  accounts payable and accrued liabilities $ 2,497 $ 9,970  Accounts payable and accrued liabilities consisted of the following:      June 30, December 31,  2016 2015  Costs for additions to oil and natural gas properties $ 2,497 $ 5,212  Lease operating expenses 10,842 10,576  Interest 6,124 7,298  Production and ad valorem taxes 5,929 6,763  VPP 2,031 3,984  General and administrative expenses 2,097 2,864  Current portion of ARO 2,930 2,930  Other 2,053 3,508  Total $ 34,503 $ 43,135 

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	6 Months Ended
	Jun. 30, 2016
NEW ACCOUNTING STANDARDS [Abstract]
NEW ACCOUNTING STANDARDS	NOTE 14. NEW ACCOUNTING STANDARDS  In August 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014–15, Presentation of Financial Statements – Going Concern. This ASU amends the accounting guidance for the presentation and disclosure of uncertainties about an entity’s ability to continue as a going concern. It requires management to evaluate and disclose whether there is substantial doubt about its ability to continue as a going concern. Management should consider relevant conditions or events that are known or reasonably known on the date the financial statements are issued. The provisions of ASU 2014–15 are applicable to the annual reporting period ending after December 15, 2016 and for annual periods and interim periods thereafter. We do not expect that adopting this ASU will have a material impact on our unaudited condensed consolidated financial statements.  In March 2016, the FASB issued ASU No. 2016–09, Compensation – Stock Compensation . This ASU simplifies several aspects of the accounting for employee share–based payment transactions, including the accounting for income taxes, forfeitures and statutory withholding requirements, as well as classification in the statement of cash flows. The provisions of ASU 2016–09 are applicable to annual reporting periods beginning after December 15, 2016 and interim periods within those annual periods. Early adoption is permitted for financial statements that have not yet been previously issued. We do not expect that adopting this ASU will have a material impact on our unaudited condensed consolidated financial statements.  No other new accounting pronouncements issued or effective during the six months ended June 30 , 2016 have had or are expected to have a material impact on our unaudited condensed consolidated financial statements.

ORGANIZATION AND NATURE OF BU21

ORGANIZATION AND NATURE OF BUSINESS (Policy)	6 Months Ended
	Jun. 30, 2016
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Nature of Operations	Nature of Operations EV Energy Partners, L.P. together with its wholly owned subsidiaries (“we,” “our” or “us”) is a publicly held limited partnership. Our general partner is EV Energy GP, L.P. (“EV Energy GP”), a Delaware limited partnership, and the general partner of our general partner is EV Management, LLC (“EV Management”), a Delaware limited liability company. EV Management is a wholly owned subsidiary of EnerVest, Ltd. (“EnerVest”), a Texas limited partnership. EnerVest and its affiliates also have a significant interest in us through their 71.25 % ownership of EV Energy GP which, in turn, owns a 2 % general partner interest in us and all of our incentive distribution rights.
Basis of Presentation	Basis of Presentation Our 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 have been condensed or omitted. We believe 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 included in Item 8 of our Annual Report on Form 10–K for the year ended December 31, 2015. All intercompany accounts and transactions have been eliminated in consolidation. In the Notes to Unaudited Condensed Consolidated Financial Statements, all dollar and unit amounts in tabulations are in thousands of dollars and units, respectively, unless otherwise indicated. 
Subsequent Events	Subsequent Events  We evaluated subsequent events for appropriate accounting and disclosure through the date these unaudited condensed consolidated financial statements were issued.

ACQUISITIONS (Tables)

ACQUISITIONS (Tables)	6 Months Ended
	Jun. 30, 2016
ACQUISITIONS [Abstract]
Pro Forma Revenues, Net Income And Net Income Per Limited Partner Unit	   Three Months Six Months  Ended Ended  June 30, June 30,  2015 2015  Revenues:  Historical $ 44,456 $ 91,698  Belden 7,919 16,031  Austin Chalk 3,414 6,626  Appalachian and San Juan Basins 8,245 16,210  Pro forma revenues $ 64,034 $ 130,565   Net income:  Historical $ 164,102 $ 102,435  Belden (59,079) (59,702)  Austin Chalk 985 1,558  Appalachian and San Juan Basins 696 654  Pro forma net income $ 106,704 $ 44,945 

RISK MANAGEMENT (Tables)

RISK MANAGEMENT (Tables)	6 Months Ended
	Jun. 30, 2016
RISK MANAGEMENT [Abstract]
Commodity Contracts	As of June 30, 2016, we had entered into commodity contracts with the following terms:          Weighted Weighted Weighted  Average Average Average  Hedged Fixed Floor Ceiling  Period Covered Volume Price Price Price  Oil (MBbls):  Swaps – July 2016 to September 2016 368.0 $ 53.75 $ $  Swaps – October 2016 to December 2016 92.0 90.14   Natural Gas (MmmBtus):  Swaps – July 2016 to December 2016 22,632.0 3.42  Swaps – 2017 32,850.0 3.07  Collars – 2017 10,950.0 2.75 3.27   Natural Gas Liquids (MBbls):  Swap – July 2016 to December 2016 1.8 9.14  
Interest Rate Swaps	As of June 30, 2016, we had entered into interest rate swaps with the following terms:       Period Covered Notional Amount Floating Rate Fixed Rate  January 2017 – December 2017 $ 100,000 1 Month LIBOR 1.039%  January 2018 – September 2020 100,000 1 Month LIBOR 1.795% 
Fair Value of Derivatives	The following table sets forth the fair values and classification of our outstanding derivatives:      Net Amounts  Gross Amounts of Assets  Offset in the Presented in the  Gross Unaudited Unaudited  Amounts of Condensed Condensed  Recognized Consolidated Consolidated  Assets Balance Sheet Balance Sheet  Derivatives:  As of June 30, 2016:  Derivative asset $ 19,014 $ (5,074) $ 13,940  Long–term derivative asset 1,345 (680) 665  Total $ 20,359 $ (5,754) $ 14,605   As of December 31, 2015:  Derivative asset $ 60,662 $ - $ 60,662  Long–term derivative asset 10,741 - 10,741  Total $ 71,403 $ - $ 71,403      Net Amounts  Gross Amounts of Liabilities  Offset in the Presented in the  Gross Unaudited Unaudited  Amounts of Condensed Condensed  Recognized Consolidated Consolidated  Liabilities Balance Sheet Balance Sheet  Derivatives:  As of June 30, 2016:  Derivative liability $ 8,339 $ (5,074) $ 3,265  Long–term derivative liability 5,373 (680) 4,693  Total $ 13,712 $ (5,754) $ 7,958 

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
	Jun. 30, 2016
FAIR VALUE MEASUREMENTS [Abstract]
Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis	The following table presents the fair value hierarchy for our 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  Markets Significant  for Other Significant  Identical Observable Unobservable  Assets Inputs Inputs  Fair Value (Level 1) (Level 2) (Level 3)  As of June 30, 2016:  Assets - Oil, natural gas and natural gas  liquids derivatives $ 20,359 $ – $ 20,359 $ –   Liabilities:  Oil, natural gas and natural gas  liquids derivatives $ 11,172 $ – $ 11,172 $ –  Interest rate swaps 2,540 – 2,540 –  $ 13,712 $ – $ 13,712 $ –   As of December 31, 2015:  Assets:  Oil, natural gas and natural gas  liquids derivatives $ 70,356 $ – $ 70,356 $ –  Interest rate swaps 1,047 – 1,047 –  $ 71,403 $ – $ 71,403 $ –  

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	6 Months Ended
	Jun. 30, 2016
ASSET RETIREMENT OBLIGATIONS [Abstract]
Changes in Aggregate Asset Retirement Obligation	The changes in the aggregate ARO are as follows:       2016 2015  Balance as of January 1 $ 176,933 $ 105,773  Liabilities incurred 362 367  Revisions 82 (1)  Accretion expense 3,999 2,414  Settlements and divestitures (2,235) (955)  Balance as of June 30 $ 179,141 $ 107,598 

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	6 Months Ended
	Jun. 30, 2016
LONG-TERM DEBT [Abstract]
Long Term Debt	Long–term debt, net consisted of the following:      June 30, December 31,  2016 2015   Credit facility $ 280,000 $ 265,000  8.0% senior notes due 2019:  Principal outstanding 343,348 426,022  Unamortized discount and debt issuance costs (1) (3,546) (5,116)  Unaccreted premium (2) 1,850 2,708  341,652 423,614  Total $ 621,652 $ 688,614 _____________ (1) Imputed interest rate of 9.23 % and 8.87% for June 30, 2016 and December 31, 2015, respectively.  (2) Imputed interest rate of 6.86 % and 7.35% for June 30, 2016 and December 31, 2015, respectively.

DISCONTINUED OPERATIONS (Tables

DISCONTINUED OPERATIONS (Tables)	6 Months Ended
	Jun. 30, 2016
DISCONTINUED OPERATIONS [Abstract]
Discontinued Operation Financial Information	Summarized financial information for our midstream segment is as follows:       Three Months Ended Six Months Ended  June 30, June 30,  2015 2015   Revenues $ 45,183 $ 93,726  Operating income 24,697 49,171  Net income 24,781 49,525 

EARNINGS PER LIMITED PARTNER 28

EARNINGS PER LIMITED PARTNER UNIT (Tables)	6 Months Ended
	Jun. 30, 2016
EARNINGS PER LIMITED PARTNER UNIT [Abstract]
Calculation of Earnings Per Limited Partner Unit	The following sets forth the calculation of earnings per limited partner unit:     Three Months Ended Six Months Ended  June 30, June 30,  2016 2015 2016 2015  Loss from continuing operations $ (28,993) $ (86,340) $ (57,993) $ (153,077)  General partner's 2% interest in loss from  continuing operations 580 1,727 1,160 3,061  Earnings attributable to unvested phantom units - (315) - (657)  Limited partners' interest in loss from  continuing operations $ (28,413) $ (84,928) $ (56,833) $ (150,673)   Earnings per limited partner unit (basic and  diluted) $ (0.58) $ (1.74) $ (1.16) $ (3.08)   Income from discontinued operations $ - $ 250,442 $ - $ 255,512  General partner's 2% interest in income  from discontinued operations - (5,009) - (5,110)  Earnings attributable to unvested phantom units - (1,732) - (675)  Limited partners' interest in income from discontinued operations  discontinued operations $ - $ 243,701 $ - $ 249,727   Earnings per limited partner unit (basic and  diluted) $ - $ 4.99 $ - $ 5.11   Net (loss) income $ (28,993) $ 164,102 $ (57,993) $ 102,435  General partner’s 2% interest in net (loss)  income 580 (3,282) 1,160 (2,049)  Earnings attributable to unvested phantom units - (2,047) - (1,332)  Limited partners’ interest in net (loss) income $ (28,413) $ 158,773 $ (56,833) $ 99,054   Earnings per limited partner unit (basic and  diluted) $ (0.58) $ 3.25 $ (1.16) $ 2.03   Weighted average limited partner units outstanding (basic and diluted) 49,055 48,871 49,041 48,833 

OTHER SUPPLEMENTAL INFORMATION

OTHER SUPPLEMENTAL INFORMATION (Tables)	6 Months Ended
	Jun. 30, 2016
OTHER SUPPLEMENTAL INFORMATION [Abstract]
Supplemental Cash Flows and Non-Cash Transactions	Supplemental cash flows and noncash transactions were as follows:      Six Months Ended  June 30,  2016 2015  Supplemental cash flows information:  Cash paid for interest $ 20,984 $ 26,460  Cash paid for income taxes 11,657 (155)        As of June 30,  2016 2015   Noncash transaction - costs for additions to oil and natural gas properties in  accounts payable and accrued liabilities $ 2,497 $ 9,970 
Schedule of Accounts Payable and Accrued Liabilities- Third Party	Accounts payable and accrued liabilities consisted of the following:      June 30, December 31,  2016 2015  Costs for additions to oil and natural gas properties $ 2,497 $ 5,212  Lease operating expenses 10,842 10,576  Interest 6,124 7,298  Production and ad valorem taxes 5,929 6,763  VPP 2,031 3,984  General and administrative expenses 2,097 2,864  Current portion of ARO 2,930 2,930  Other 2,053 3,508  Total $ 34,503 $ 43,135 

ORGANIZATION AND NATURE OF BU30

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Percentage of general partnership interest	2.00%
EnerVest, Ltd.
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Percentage of ownership interest in EV Energy GP, L.P. (EV Energy GP)	71.25%
8.0% Senior Notes due 2019
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Senior notes, maturity year	2,019	2,019
Senior unsecured notes, stated interest rate	8.00%

EQUITY-BASED COMPENSATION (Deta

EQUITY-BASED COMPENSATION (Details) - USD ($) $ in Thousands, shares in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Sep. 30, 2011	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost				$ 2,964	$ 7,294
Unvested Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period				4 years
Equity-based compensation cost		$ 1,400	$ 2,300	$ 3,000	7,100
Unrecognized compensation expense		$ 10,900		$ 10,900
Weighted average period				2 years 2 months 12 days
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost					$ 200
Shares issued	0.3

ACQUISITIONS (Narrative) (Detai

ACQUISITIONS (Narrative) (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016USD ($)MMcf	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)MMcf	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)MMcf	Oct. 31, 2015USD ($)MMcf
Business Acquisition [Line Items]
Oil, natural gas and natural gas liquids revenues	$ 42,365	$ 43,722	$ 80,104	$ 90,147
Volume obligation to deliver, billion cubic feet (Bcf) of natural gas | MMcf						2,400
Volume obligation to deliver, remaining, (Bcf) of natrual gas | MMcf	900		900		1,900
Liability related to volumetric production payment (VPP)	$ 2,031		$ 2,031		$ 3,984
Accretion expense	$ 40		$ 100
Belden [Member]
Business Acquisition [Line Items]
Oil and natural gas properties acquired, purchase price						$ 111,100
Austin Chalk [Member]
Business Acquisition [Line Items]
Oil and natural gas properties acquired, purchase price						25,900
Appalachian Basin and San Juan Basin [Member]
Business Acquisition [Line Items]
Oil and natural gas properties acquired, purchase price						$ 122,000

ACQUISITIONS (Pro Forma Revenue

ACQUISITIONS (Pro Forma Revenues, Net Income and Net Income Per Limited Partner Unit) (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2015
Business Acquisition [Line Items]
Revenues	$ 64,034	$ 130,565
Net income	106,704	44,945
Historical [Member]
Business Acquisition [Line Items]
Revenues	44,456	91,698
Net income	164,102	102,435
Belden [Member]
Business Acquisition [Line Items]
Revenues	7,919	16,031
Net income	(59,079)	(59,702)
Austin Chalk [Member]
Business Acquisition [Line Items]
Revenues	3,414	6,626
Net income	985	1,558
Appalachian Basin and San Juan Basin [Member]
Business Acquisition [Line Items]
Revenues	8,245	16,210
Net income	$ 696	$ 654

RISK MANAGEMENT (Commodity Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	Jun. 30, 2016MMBTU$ / MBbls$ / MMBTUMMBbls
Oil [Member] | Swaps - July 2016 to September 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls) | MMBbls	368
Weighted Average Fixed Price | $ / MBbls	53.75
Oil [Member] | Swaps - October 2016 to December 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls) | MMBbls	92
Weighted Average Fixed Price | $ / MBbls	90.14
Natural Gas [Member] | Swaps - July 2016 to December 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	22,632
Weighted Average Fixed Price	3.42
Natural Gas [Member] | Swaps - 2017 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	32,850
Weighted Average Fixed Price	3.07
Natural Gas [Member] | Collars - 2017 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	10,950
Weighted Average Floor Price	2.75
Weighted Average Ceiling Price	3.27
Natural Gas Liquids [Member] | Swaps - July 2016 to December 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls) | MMBbls	1.8
Weighted Average Fixed Price | $ / MBbls	9.14

RISK MANAGEMENT (Interest Rate

RISK MANAGEMENT (Interest Rate Swaps) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)
Interest Rate Swaps Covering January 2017 - December 2017
Derivative Instruments Related to Oil and Gas Production [Line Items]
Notional amount	$ 100,000
Floating rate	1 Month LIBOR
Fixed rate	1.039%
Interest Rate Swap January 2018 - September 2020 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Notional amount	$ 100,000
Floating rate	1 Month LIBOR
Fixed rate	1.795%

RISK MANAGEMENT (Fair Value of

RISK MANAGEMENT (Fair Value of Derivatives) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Derivative Assets [Abstract]
Derivative asset, fair value	$ 20,359	$ 71,403
Derivative asset, liability	(5,754)
Derivative asset	13,940	60,662
Long-term derivative asset	665	10,741
Net recorded fair value	14,605	71,403
Derivative Liabilities [Abstract]
Derivative liability, fair value	13,712
Derivative liability, asset	(5,754)
Derivative liability	3,265
Long-term derivative liability	4,693
Net recorded fair value	7,958
Current Assets [Member]
Derivative Assets [Abstract]
Derivative asset, fair value	19,014	60,662
Derivative asset, liability	(5,074)
Derivative asset	13,940	60,662
Long-term Derivative Asset [Member]
Derivative Assets [Abstract]
Derivative asset, fair value	1,345	10,741
Derivative asset, liability	(680)
Long-term derivative asset	665	10,741
Derivative Liability [Member]
Derivative Liabilities [Abstract]
Derivative liability, fair value	8,339
Derivative liability, asset	(5,074)
Derivative liability	3,265
Long-term Derivative Liability [Member]
Derivative Liabilities [Abstract]
Derivative liability, fair value	5,373
Derivative liability, asset	(680)
Long-term derivative liability	4,693
Commodity contracts
Derivative Assets [Abstract]
Derivative asset, fair value	20,359	70,356
Derivative Liabilities [Abstract]
Derivative liability, fair value	11,172
Interest rate swaps
Derivative Assets [Abstract]
Derivative asset, fair value		$ 1,047
Derivative Liabilities [Abstract]
Derivative liability, fair value	$ 2,540

FAIR VALUE MEASUREMENTS (Narrat

FAIR VALUE MEASUREMENTS (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Fair Value Measurements [Line Items]
Impairment of oil and gas properties	$ 1,997	$ 48,284	$ 2,684	$ 106,457
Oil and natural gas properties, fair value		$ 31,400		$ 31,400
Long-term Debt	621,652		$ 621,652		$ 688,614
8.0% Senior Notes due 2019
Fair Value Measurements [Line Items]
Senior notes, maturity year			2,019	2,019
Senior notes, fair value	208,600		$ 208,600		211,900
Long-term Debt	$ 341,652		$ 341,652		$ 423,614

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, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	$ 20,359	$ 71,403
Derivative liability, fair value	13,712
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	20,359	70,356
Derivative liability, fair value	11,172
Interest rate swaps
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value		1,047
Derivative liability, fair value	2,540
Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value		71,403
Derivative liability, fair value	13,712
Significant Other Observable Inputs (Level 2) | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	20,359	70,356
Derivative liability, fair value	11,172
Significant Other Observable Inputs (Level 2) | Interest rate swaps
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value		$ 1,047
Derivative liability, fair value	$ 2,540

ASSET RETIREMENT OBLIGATIONS (N

ASSET RETIREMENT OBLIGATIONS (Narrative) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
ASSET RETIREMENT OBLIGATIONS [Abstract]
Asset retirement obligation, current	$ 2,930	$ 2,930

ASSET RETIREMENT OBLIGATIONS (C

ASSET RETIREMENT OBLIGATIONS (Changes in Aggregate Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
ASSET RETIREMENT OBLIGATIONS [Abstract]
Balance at beginning of period	$ 176,933	$ 105,773
Liabilities incurred	362	367
Revisions	82	(1)
Accretion expense	3,999	2,414
Settlements and divestitures	(2,235)	(955)
Balance at end of period	$ 179,141	$ 107,598

LONG-TERM DEBT (Narrative) (Det

LONG-TERM DEBT (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016	Jun. 30, 2015
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 1,000,000	$ 1,000,000
Senior secured credit facility, expiration date		Feb. 29, 2020
Weighted average effective interest rate		4.58%	3.50%
Line of credit, borrowing base	450,000	$ 450,000
Line of credit, borrowing base redetermination period		The borrowing base is subject to scheduled redeterminations as of April 1 and October 1 of each year with an additional redetermination once per calendar year at our request or at the request of the lenders and with one calculation that may be made at our request during each calendar year in connection with material acquisitions or divestitures of properties.
Letters of credit outstanding, amount	$ 400	$ 400
Early repayment of senior debt		34,978
8.0% Senior Notes due 2019
Debt Instrument [Line Items]
Cash amount available per credit facility amendement for redemption		$ 35,000
Percentage of cash, per current borrowing base		5.00%
Amount of cash, equivalent to percentage		$ 30,000
Senior unsecured notes, stated interest rate	8.00%	8.00%
Senior notes, maturity year		2,019	2,019
Amount of debt redeemed	$ 82,700
Early repayment of senior debt	35,000
Gain (loss) on debt redemption amount	47,700
Borrowing Base Determination, Period One
Debt Instrument [Line Items]
Borrowing base scheduled redetermination date		--04-01
Borrowing Base Determination, Period Two
Debt Instrument [Line Items]
Borrowing base scheduled redetermination date		--10-01
Letter of Credit
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 100,000	$ 100,000

LONG-TERM DEBT (Long Term Debt)

LONG-TERM DEBT (Long Term Debt) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Credit facility outstanding	$ 280,000	$ 265,000
Long-term debt, Total	621,652	688,614
8.0% Senior Notes due 2019
Senior notes, outstanding	343,348	426,022
Unamortized discount and debt issuance costs	(3,546)	(5,116)
Unaccreted premium	1,850	2,708
Long-term debt, Total	$ 341,652	$ 423,614
Debt instrument, unamortized discount, imputed interest	9.23%	8.87%
Debt instrument, unaccreted expense, imputed interest	6.86%	7.35%

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
COMMITMENTS AND CONTINGENCIES [Abstract]
Loss contingency accrual	$ 0	$ 0

OWNERS' EQUITY (Narrative) (Det

OWNERS' EQUITY (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Feb. 12, 2016	Jan. 25, 2016	Jan. 31, 2016	Jun. 30, 2016	Jun. 30, 2015
Stockholders Equity Note [Line Items]
Percentage of limited partnership interest				98.00%
Percentage of general partnership interest				2.00%
Units vested			200,000
Contribution from general partner					$ 91
Distributions paid				$ 3,868	50,495
Distribution to unitholders declared per unit		$ 0.075
Distribution to unitholders, amount	$ 3,900
Distribution to unitholders, record date	Feb. 5, 2016
Distribution to unitholders, payment date	Feb. 12, 2016
Common Unitholders
Stockholders Equity Note [Line Items]
Common units outstanding				49,055,214
Distributions paid				$ 3,793	49,498
General Partner Interest
Stockholders Equity Note [Line Items]
Contribution from general partner					91
Distributions paid				$ 75	$ 997

DISCONTINUED OPERATIONS (Summar

DISCONTINUED OPERATIONS (Summarized Financial Information Discontinued Operations) (Details) - Utica East Ohio Midstream LLC and Cardinal Gas Services LLC [Member] - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2015
Schedule Of Equity Method Investments [Line Items]
Revenues	$ 45,183	$ 93,726
Operating income	24,697	49,171
Net income	$ 24,781	$ 49,525

EARNINGS PER LIMITED PARTNER 46

EARNINGS PER LIMITED PARTNER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
EARNINGS PER LIMITED PARTNER UNIT [Abstract]
Loss from continuing operations	$ (28,993)	$ (86,340)	$ (57,993)	$ (153,077)
General partner's 2% interest in loss from continuing operations	580	1,727	1,160	3,061
Earnings attributable to unvested phantom units, continuing operations		(315)		(657)
Limited partners' interest in loss from continuing operations	$ (28,413)	$ (84,928)	$ (56,833)	$ (150,673)
Loss per limited partner unit (basic and diluted), continuing	$ (0.58)	$ (1.74)	$ (1.16)	$ (3.08)
Income from discontinued operations		$ 250,442		$ 255,512
General partner's 2% interest in income from discontinued operations		(5,009)		(5,110)
Earnings attributable to unvested phantom units, discontinuted operations		(1,732)		(675)
Limited partners' interest in income from discontinued operations		$ 243,701		$ 249,727
Earnings per limited partner unit (basic and diluted), discontinued		$ 4.99		$ 5.11
Net loss	$ (28,993)	$ 164,102	$ (57,993)	$ 102,435
General partner's 2% interest in net loss	580	(3,282)	1,160	(2,049)
Earnings attributable to unvested phantom units		(2,047)		(1,332)
Limited partners' interest in net (loss) income	$ (28,413)	$ 158,773	$ (56,833)	$ 99,054
Earnings per share, basic and diluted	$ (0.58)	$ 3.25	$ (1.16)	$ 2.03
Weighted average limited partner units outstanding (basic and diluted)	49,055	48,871	49,041	48,833
Percentage of general partnership interest			2.00%

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - EnerVest, Ltd. - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Related Party Transaction [Line Items]
Administrative fees paid to related party	$ 4	$ 3.3	$ 8	$ 6.6
Direct expenses incurred and reimbursed to related party	$ 4.6	$ 3.7	$ 10.8	$ 7.8

OTHER SUPPLEMENTAL INFORMATIO48

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Supplemental cash flows information:
Cash paid for interest	$ 20,984	$ 26,460
Cash paid for income taxes	11,657
Proceeds from income tax refunds		(155)
Non-cash transactions:
Noncash transaction - costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$ 2,497	$ 9,970

OTHER SUPPLEMENTAL INFORMATIO49

OTHER SUPPLEMENTAL INFORMATION (Schedule of Accounts Payable and Accrued Liabilities- Third Party) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Other Supplemental Information Disclosure [Abstract]
Costs for additions to oil and natural gas properties	$ 2,497	$ 5,212
Lease operating expenses	10,842	10,576
Interest	6,124	7,298
Production and ad valorem taxes	5,929	6,763
VPP	2,031	3,984
General and administrative expenses	2,097	2,864
Current portion of ARO	2,930	2,930
Other	2,053	3,508
Total	$ 34,503	$ 43,135