Harvest Oil & Gas (HRST) 10-Q 9 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 30, 2015
Document Documentand Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
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		48,871,399

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 39,861	$ 8,255
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	19,488	32,758
Related party		1,043
Other	5,019	4,570
Derivative asset	71,406	113,044
Other current assets	1,108	2,000
Assets held for sale		315,173
Total current assets	136,882	476,843
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; September 30, 2015, $926,744; December 31, 2014, $778,679	1,552,097	1,710,925
Other property, net of accumulated depreciation and amortization; September 30, 2015, $926; December 31, 2014, $898	1,087	1,141
Restricted cash		33,768
Long-term derivative asset	15,323	20,647
Other assets	32,839	5,879
Total assets	1,738,228	2,249,203
Current liabilities:
Accounts payable and accrued liabilities	45,106	47,878
Related party	2,226
Total current liabilities	47,332	47,878
Asset retirement obligations	98,249	103,832
Long-term debt	499,472	1,030,391
Other long-term liabilities	$ 477	$ 989
Commitments and contingencies
Owners' equity:
Common unitholders - 48,871,399 units and 48,572,019 units issued and outstanding as of September 30, 2015 and December 31, 2014, respectively	$ 1,103,771	$ 1,077,826
General partner interest	(11,073)	(11,713)
Total owners' equity	1,092,698	1,066,113
Total liabilities and owners' equity	$ 1,738,228	$ 2,249,203

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Statement Of Financial Position [Abstract]
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$ 926,744	$ 778,679
Other property, accumulated depreciation and amortization	$ 926	$ 898
Common unitholders, units issued	48,871,399	48,572,019
Common unitholders, units outstanding	48,871,399	48,572,019

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues:
Oil, natural gas and natural gas liquids revenues	$ 37,587	$ 83,440	$ 127,734	$ 265,639
Transportation and marketing-related revenues	734	1,091	2,285	3,591
Total revenues	38,321	84,531	130,019	269,230
Operating costs and expenses:
Lease operating expenses	22,509	26,579	69,833	78,002
Cost of purchased natural gas	510	813	1,588	2,725
Dry hole and exploration costs	1,034	3,972	1,720	5,943
Production taxes	1,357	3,034	4,708	9,514
Asset retirement obligations accretion expense	1,134	1,244	3,548	3,634
Depreciation, depletion and amortization	23,485	25,723	74,718	76,961
General and administrative expenses	8,609	9,688	28,968	34,735
Impairment of oil and natural gas properties	15,787	946	122,244	2,267
Gain on sales of oil and natural gas properties			(531)	(1,484)
Total operating costs and expenses	74,425	71,999	306,796	212,297
Operating (loss) income	(36,104)	12,532	(176,777)	56,933
Other income (expense), net:
Gain (loss) on derivatives, net	37,042	37,548	51,406	(3,264)
Interest expense	(11,043)	(13,676)	(38,279)	(38,193)
Other income, net	206	76	51	456
Total other income (expense), net	26,205	23,948	13,178	(41,001)
(Loss) income from continuing operations before income taxes	(9,899)	36,480	(163,599)	15,932
Income taxes	61	(157)	684	176
(Loss) income from continuing operations	(9,838)	36,323	(162,915)	16,108
Income from discontinued operations		6,297	255,512	11,236
Net (loss) income	$ (9,838)	$ 42,620	$ 92,597	$ 27,344
Basic and diluted earnings per limited partner unit:
Earnings per limited partner unit (basic and diluted) (loss) income, continuing	$ (0.20)	$ 0.72	$ (3.29)	$ 0.29
Earnings per limited partner unit (basic and diluted) income, discontinued		0.13	5.12	0.23
Net (loss) income	$ (0.20)	$ 0.85	$ 1.83	$ 0.52
Weighted average limited partner units outstanding:
Weighted average limited partner units outstanding - basic and diluted	48,871	48,572	48,846	48,561
Distributions declared per unit	$ 0.50	$ 0.774	$ 1.50	$ 2.319

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Changes in Owners' Equity - USD ($) $ in Thousands	Common Unitholders [Member]	General Partner Interest [Member]	Total
Beginning Balance at Dec. 31, 2013	$ 1,083,718	$ (11,785)	$ 1,071,933
Contributions from general partner		154	154
Distributions	(113,877)	(2,295)	(116,172)
Other	(5)		(5)
Equity-based compensation	15,038	307	15,345
Net income	26,797	547	27,344
Ending Balance at Sep. 30, 2014	1,011,671	(13,072)	998,599
Beginning Balance at Dec. 31, 2014	1,077,826	(11,713)	1,066,113
Contributions from general partner		91	91
Distributions	(74,242)	(1,496)	(75,738)
Equity-based compensation	9,442	193	9,635
Net income	90,745	1,852	92,597
Ending Balance at Sep. 30, 2015	$ 1,103,771	$ (11,073)	$ 1,092,698

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities:
Net income	$ 92,597	$ 27,344
Adjustments to reconcile net income to net cash flows provided by operating activities:
Income from discontinued operations	(255,512)	(11,236)
Asset retirement obligations accretion expense	3,548	3,634
Depreciation, depletion and amortization	74,718	76,961
Equity-based compensation cost	9,635	15,345
Impairment of oil and natural gas properties	122,244	2,267
Gain on sales of oil and natural gas properties	(531)	(1,484)
(Gain) loss on derivatives, net	(51,406)	3,264
Cash settlements of matured derivatives contracts	98,368	(8,170)
Other	288	5,527
Changes in operating assets and liabilities:
Accounts receivable	13,864	(7,077)
Other current assets	894	(833)
Accounts payable and accrued liabilities	10,610	12,360
Other, net	(120)	(733)
Net cash flows provided by operating activities from continuing operations	119,197	117,169
Net cash flows used in operating activities from discontinued operations	(372)
Net cash flows provided by operating activities	118,825	117,169
Cash flows from investing activities:
Additions to oil and natural gas properties	(58,687)	(73,356)
Deposit on acquisition of oil and natural gas properties	(25,900)
Prepaid drilling costs		(2,501)
Proceeds from sale of oil and natural gas properties	1,439	7,365
Restricted cash	33,768
Other	48	52
Net cash flows used in investing activities from continuing operations	(49,332)	(68,440)
Net cash flows provided by (used in) investing activities from discontinued operations	572,160	(105,200)
Net cash flows provided by (used in) investing activities	522,828	(173,640)
Cash flows from financing activities:
Repayment of long-term debt borrowings	(561,000)
Long-term debt borrowings	30,000	172,000
Loan costs incurred	(3,400)
Contributions from general partner	91	154
Distributions paid	(75,738)	(116,172)
Other		(5)
Net cash flows (used in) provided by financing activities	(610,047)	55,977
Increase (decrease) in cash and cash equivalents	31,606	(494)
Cash and cash equivalents - beginning of year	8,255	11,698
Cash and cash equivalents - end of period	$ 39,861	$ 11,204

ORGANIZATION AND NATURE OF BUSI

ORGANIZATION AND NATURE OF BUSINESS	9 Months Ended
	Sep. 30, 2015
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 indirect 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 an indirect 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. With the sale of our interest in Cardinal Gas Services, LLC (“Cardinal”) in October 2014 and the sale of our interest in Utica East Ohio Midstream LLC (“UEO”) in June 2015, we no longer operate in the midstream segment, and we have reclassified our condensed consolidated financial statements for all periods presented to reflect the operations of our midstream segment as discontinued operations (see Note 10). We now operate in one reportable segment engaged in the acquisition, development and production of oil and natural gas properties and all of our operations are located in the United States. 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 our Annual Report on Form 10–K for the year ended December 31, 2014. 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 .

EQUITY-BASED COMPENSATION

EQUITY-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2015
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 primarily 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 $2.3 million and $2.8 million in the three months ended September 30, 2015 and 2014, respectively, and $9.4 million and $10.9 million in the nine months ended September 30, 2015 and 2014, respectively. These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations. As of September 30, 2015, there was $14.7 million of total unrecognized compensation cost related to unvested phantom units which is expected to be recognized over a weighted average period of 2.4 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. We recognized compensation cost related to these performance units of $0.2 million in the nine months ended September 30, 2015 and $1.5 million and $4.4 million in the three months and nine months ended September 30, 2014, respectively. These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.

RISK MANAGEMENT

RISK MANAGEMENT	9 Months Ended
	Sep. 30, 2015
RISK MANAGEMENT [Abstract]
RISK MANAGEMENT	NOTE 3. 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 “Gain (loss) on derivatives, net” in our unaudited condensed consolidated statements of operations. As of September 30, 2015, we had entered into commodity contracts with the following terms: Period Covered Hedged Volume Weighted Average Fixed Price Oil (MBbls): Swaps – October 2015 to December 2015 $ Swaps – 2016 Natural Gas (MmmBtus): Swaps – October 2015 to December 2015 Swaps – 2016 Swaps – 2017 Natural Gas Liquids (MBbls): Swaps – October 2015 to December 2015 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 September 30, 2015: Derivative asset $ $ - $ Long–term derivative asset - Total $ $ - $ As of December 31, 2014: Derivative asset $ $ $ Long–term derivative asset - Total $ $ $ 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 December 31, 2014: Derivative liability $ $ $ - Long–term derivative liability - - - Total $ $ $ - 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 September 30, 2015 and December 31, 2014, we were not required to post any collateral nor did we hold any collateral associated with our derivatives.

IMPAIRMENT OF OIL AND NATURAL G

IMPAIRMENT OF OIL AND NATURAL GAS PROPERTIES	9 Months Ended
	Sep. 30, 2015
IMPAIRMENT OF OIL AND NATURAL GAS PROPERTIES [Abstract]
IMPAIRMENT OF OIL AND NATURUAL GAS PROPERTIES	NOTE 4. IMPAIRMENT OF OIL AND NATURAL GAS PROPERTIES We evaluate our proved oil and natural gas properties and related equipment and facilities for impairment whenever events or changes in circumstances indicate that the carrying amounts of such properties may not be recoverable. The determination of recoverability is made based upon estimated undiscounted future net cash flows. The amount of impairment loss, if any, is determined by comparing the fair value, as determined by a discounted cash flow analysis, with the carrying value of the related asset. We recorded impairment charges of $15.2 million and $73.3 million in the three months and nine months ended September 30, 2015, respectively, related to proved oil and natural gas properties (see Note 5). Unproved oil and natural gas properties are assessed periodically on a property–by–property basis, and any impairment in value is recognized. We recorded impairment charges of $ 0.6 million and $48.9 million in the three months and nine months ended September 30, 2015 related to unproved oil and natural gas properties, of which $0.6 million and $48.4 million in the three months and nine months ended September 30, 2015, respectively, related to a change in our development plans for acreage in the Utica Shale.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2015
FAIR VALUE MEASUREMENTS [Abstract]
FAIR VALUE MEASUREMENTS	NOTE 5. FAIR VALUE MEASUREMENTS 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 September 30, 2015: Assets - Oil, natural gas and natural gas liquids derivatives $ $ - $ $ - As of December 31, 2014: Assets - Oil and natural gas derivatives $ $ - $ $ - Liabilities - Interest rate swaps $ $ - $ $ - 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 nine months ended September 30, 2015. Nonrecurring Basis In the three months and nine months ended September 30, 2015, as a result of a reduction in estimated future net cash flows primarily caused by lower oil, natural gas and natural gas liquids prices, we recognized $15.2 million and $73.3 million, respectively, of impairment charges to write down oil and natural gas properties to their fair value of $10.4 million and $31.4 million in the three months and nine months ended September 30, 2015 , respectively. 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 proved 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 $ 352.5 million and $ 427.5 million at September 30, 2015 and December 31, 2014, respectively, which differs from the carrying value of $499.5 million and $ 499.4 million at September 30, 2015 and December 31, 2014, respectively. T he fair value of the senior notes due 2019 was determined using Level 2 inputs .

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2015
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: 2015 2014 Balance as of January 1 $ $ Liabilities incurred Revisions Accretion expense Settlements and divestitures Balance as of September 30 $ $ As of both September 30, 2015 and December 31, 2014, $ 1.9 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	9 Months Ended
	Sep. 30, 2015
LONG-TERM DEBT [Abstract]
LONG-TERM DEBT	NOTE 7. LONG–TERM DEBT Credit Facility As of September 30, 2015, 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. We may use borrowings under the facility for acquiring and developing oil and natural gas properties, for working capital purposes, for general corporate purposes and for funding distributions to partners. We also may use up to $ 100.0 million of available borrowing capacity for letters of credit. The facility requires the maintenance of a current ratio (as defined in the facility) of greater than 1.0 and a ratio of senior secured debt to earnings plus interest expense, taxes, depreciation, depletion and amortization expense and exploration expense (“EBITDAX”) of no greater than 3. 5 to 1.0. As of September 30, 2015, 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 3.86 % and 2.99% at September 30, 2015 and 2014, 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 September 30, 2015, the borrowing base under the facility was $ 500.0 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. As of September 30, 2015, we had no amounts outstanding under the facility. As of December 31, 2014, we had $ 531.0 million outstanding under the facility. 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. The aggregate carrying amount of our senior notes due 2019 was $499.5 million and $ 499.4 million at September 30, 2015 and December 31, 2014, respectively.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2015
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 September 30, 2015 or December 31, 2014.

OWNERS' EQUITY

OWNERS' EQUITY	9 Months Ended
	Sep. 30, 2015
OWNERS' EQUITY [Abstract]
OWNERS' EQUITY	NOTE 9. OWNERS’ EQUITY Units Outstanding At September 30, 2015, owners’ equity consists of 48,871,399 common units, representing a 98 % limited partnership interest in us, and a 2 % general partnership interest. Issuance of Units In the nine months ended September 30, 2015, we issued 0.3 million common units related to the vesting of equity–based awards. In conjunction with the vesting of these units, we received a contribution of $ 0.1 million by our general partner to maintain its 2% interest in us. Cash Distributions The following sets forth the distributions we paid during the nine months ended September 30, 2014: Date Paid Period Covered Distribution per Unit Total Distribution February 13, 2015 October 1, 2014 – December 31, 2014 $ $ May 15, 2015 January 1, 2015 – March 31, 2015 August 14, 2015 April 1, 2015 – June 30, 2015 $ On October 29, 2015, the board of directors of EV Management declared a $ 0.50 per unit distribution for the third quarter of 2015 on all outstanding units. The distribution of $ 25.2 million is to be paid on November 13, 2015 to unitholders of record at the close of business on November 9, 2015.

DISCONTINUTED OPERATIONS

DISCONTINUTED OPERATIONS	9 Months Ended
	Sep. 30, 2015
DISCONTINUED OPERATIONS [Abstract]
DISCONTINUTED OPERATIONS	NOTE 10. DISCONTINUED OPERATIONS Our midstream segment, which consisted of our investments in UEO and Cardinal, was engaged in the construction and operation of natural gas processing, natural gas liquids fractionation, connecting pipeline infrastructure and gathering systems to serve production in the Utica Shale area in Ohio. In October 2014, we sold our interest in Cardinal. In June 2015, we sold our interest in UEO and received net proceeds of $572.2 million and recognized a gain of $246.7 million. This gain is included in “Income from discontinued operations” for the nine months ended September 30, 2015. As a result of the reduction in the borrowing base under our facility upon the sale of our interest in UEO, we were required to repay $25.0 million of outstanding borrowings. Accordingly, $1.5 million of interest related to this $25.0 million and the write off of deferred financing costs related to the reduction in the borrowing base have been allocated to “Income from discontinued operations.” We have reclassified our unaudited condensed consolidated financial statements for all periods presented to reflect the operations of our midstream segment as discontinued operations. Accordingly, in our unaudited condensed consolidated balance sheets, amounts previously included in “Investments in unconsolidated affiliates” have been reclassified to ”Assets held for sale” and, in our unaudited condensed consolidated statement of operations, amounts previously included in “Equity in income of unconsolidated affiliates” have been reclassified to “Income from discontinued operations.” Summarized financial information for our midstream segment is as follows: December 31, 2014 (1) Current assets $ Noncurrent assets Total assets $ Current liabilities $ Owner’s equity Total liabilities and owner’s equity $ Three Months Ended Nine Months Ended September 30, September 30, 2015 (1) 2014 (2) 2015 (1) 2014 (2) Revenues $ - $ $ $ Operating income - Net income - _____________ (1) Information is for UEO on a stand–alone basis through the date of divestiture . (2) Information is for UEO and Cardinal on a combined basis.

NET INCOME (LOSS) PER LIMITED P

NET INCOME (LOSS) PER LIMITED PARTNER UNIT	9 Months Ended
	Sep. 30, 2015
NET INCOME (LOSS) PER LIMITED PARTNER UNIT [Abstract]
NET INCOME (LOSS) PER LIMITED PARTNER UNIT	NOTE 11. NET (LOSS) INCOME PER LIMITED PARTNER UNIT The following sets forth the calculation of net (loss) income per limited partner unit: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 (Loss) income from continuing operations $ $ $ $ General partner’s 2% interest in (loss) income from continuing operations (Loss) income from continuing operations attributable to unvested phantom units Limited partners’ interest in (loss) income from continuing operations $ $ $ $ Earnings per limited partner unit (basic and diluted) $ $ $ $ Income from discontinued operations $ - $ $ $ General partner’s 2% interest in income from discontinued operations - Income from discontinued operations attributable to unvested phantom units - - Limited partners’ interest in income from discontinued operations $ - $ $ $ Earnings per limited partner unit (basic and diluted) $ - $ $ $ Net (loss) income $ $ $ $ General partner’s 2% interest in net (loss) income Net (loss) income attributable to unvested phantom units Limited partners’ interest in net (loss) income $ $ $ $ Earnings per limited partner unit (basic and diluted) $ $ $ $ Weighted average limited partner units outstanding (basic and diluted) As of September 30, 2015, there are no unearned performance units outstanding. Unearned performance units totaling 0.2 million units were not included in the computation of diluted net (loss) income per limited partner unit for the three months and nine months ended September 30, 2014 because the effect would have been anti–dilutive.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2015
RELATED PARTY TRANSACTIONS [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 12. RELATED PARTY TRANSACTIONS Pursuant to an omnibus agreement, we paid EnerVest $ 3.3 million and $ 3. 1 million in the three months ended September 30, 2015 and 2014, respectively, and $9.9 million and $9.1 million in the nine months ended September 30, 2015 and 2014, 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 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 $ 3.5 million and $3.9 million in the three months ended September 30, 2015 and 2014, respectively, and $ 11.3 million and $12.2 million in the nine months ended September 30, 2015 and 2014, 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	9 Months Ended
	Sep. 30, 2015
OTHER SUPPLEMENTAL INFORMATION [Abstract]
OTHER SUPPLEMENTAL INFORMATION	NOTE 13. OTHER SUPPLEMENTAL INFORMATION Supplemental cash flows and noncash transactions were as follows: Nine Months Ended September 30, 2015 2014 Supplemental cash flows information - cash paid for interest, net of capitalized interest of $5,741 at September 30, 2014 $ $ Cash (refunded) paid for income taxes, net $ $ As of September 30, 2015 2014 Noncash transaction - costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ $ Accounts payable and accrued liabilities consisted of the following: September 30, December 31, 2015 2014 Costs for additions to oil and natural gas properties $ $ Lease operating expenses Interest Production and ad valorem taxes General and administrative expenses Current portion of ARO Derivative settlements - Other Total $ $

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	9 Months Ended
	Sep. 30, 2015
NEW ACCOUNTING STANDARDS [Abstract]
NEW ACCOUNTING STANDARDS	NOTE 14. NEW ACCOUNTING STANDARDS In April 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2015–03, Interest – Imputation of Interest . This ASU changes the presentation of debt issuance costs in financial statements. Under ASU 2015–03, an entity presents such costs in the balance sheet as a direct deduction from the related debt liability rather than as an asset. The provisions of ASU 2015–03 are applicable to annual reporting periods beginning after December 15, 2015 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. In April 2015, the FASB issued ASU No. 2015–06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions . ASU 2015–06 specifies that for purposes of calculating historical earnings per unit under the two class method, the earnings (losses) of a transferred business before the date of a dropdown transaction should be allocated entirely to the general partner. In addition, qualitative disclosures about how the rights to the earnings (losses) differ before and after the dropdown transaction occurs for purposes of computing earnings per unit under the two class method are also required. The provisions of ASU 2015–06 are applicable to annual reporting periods beginning after December 15, 2015 and interim periods within those annual periods. We will adopt this ASU should we enter into a dropdown transaction. In August 2015, the FASB issued ASU No. 2015–14, Deferral of the Effective Date, to defer the effective date of ASU 2014–09, Revenue from Contracts with Customers , for one year. The provisions of ASU 2014–09 are now applicable to annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. We have not yet determined the effect that adopting this ASU will have on our unaudited condensed consolidated financial statements. In September 2015, the FASB issued ASU 2015–16, Simplifying the Accounting for Measurement Period Adjustments. To simplify the accounting for adjustments made to provisional amounts, ASU 2015–16 requires that the acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amount is determined. The acquirer is required to also record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. In addition an entity is required to present separately on the face of the income statement or disclose in the notes to the financial statements the portion of the amount recorded in current period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. The provisions of ASU 2015–16 are effective for fiscal years beginning after December 15, 2015 and interim periods within those fiscal years. We will adopt this ASU should we report provisional amounts for items in a business combination. No other new accounting pronouncements issued or effective during the nine months ended September 30, 2015 have had or are expected to have a material impact on our unaudited condensed consolidated financial statements.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2015
SUBSEQUENT EVENTS [Abstract]
SUBSEQUENT EVENTs	NOTE 15. SUBSEQUENT EVENTS In October 2015, we acquired oil and natural gas properties in the Appalachian Basin, San Juan Basin, Michigan and Austin Chalk from certain institutional partnerships managed by EnerVest for a combined cash consideration of $259.4 million, less the $25.9 million deposit that we made in September 2015. The deposit is included in “Other assets” in our unaudited condensed consolidated balance sheets. The purchase price is subject to customary purchase price adjustments. In October 2015, we amended our credit facility to, among other things, increase the borrowing base to $625.0 million and amend our debt to EBITDAX ratio covenants as follows: · ratio of senior secured debt to EBITDAX of no greater than 3.0 to 1.0 through the quarter ending December 31, 2016; · ratio of total debt to EBITDAX of no greater than 5.50 to 1 .0 through the quarters ending March 31, 2017 and June 30, 2017; · ratio of total debt to EBITDAX of no greater than 5.25 to 1 .0 through the quarters ending September 30, 2017 and December 31, 2017; and · ratio of total debt to EBITDAX of no greater than 4.25 to 1.0 for the quarter ending March 31, 2018 and thereafter. We evaluated subsequent events for appropriate accounting and disclosure through the date these unaudited condensed consolidated financial statements were issued.

ORGANIZATION AND NATURE OF BU22

ORGANIZATION AND NATURE OF BUSINESS (Policy)	9 Months Ended
	Sep. 30, 2015
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Nature of Operations	Nature of Operations EV Energy Partners, L.P. together with its indirect 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 an indirect 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. With the sale of our interest in Cardinal Gas Services, LLC (“Cardinal”) in October 2014 and the sale of our interest in Utica East Ohio Midstream LLC (“UEO”) in June 2015, we no longer operate in the midstream segment, and we have reclassified our condensed consolidated financial statements for all periods presented to reflect the operations of our midstream segment as discontinued operations (see Note 10). We now operate in one reportable segment engaged in the acquisition, development and production of oil and natural gas properties and all of our operations are located in the United States.
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 our Annual Report on Form 10–K for the year ended December 31, 2014. 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

RISK MANAGEMENT (Tables)

RISK MANAGEMENT (Tables)	9 Months Ended
	Sep. 30, 2015
RISK MANAGEMENT [Abstract]
Commodity Contracts	As of September 30, 2015, we had entered into commodity contracts with the following terms: Period Covered Hedged Volume Weighted Average Fixed Price Oil (MBbls): Swaps – October 2015 to December 2015 $ Swaps – 2016 Natural Gas (MmmBtus): Swaps – October 2015 to December 2015 Swaps – 2016 Swaps – 2017 Natural Gas Liquids (MBbls): Swaps – October 2015 to December 2015
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 September 30, 2015: Derivative asset $ $ - $ Long–term derivative asset - Total $ $ - $ As of December 31, 2014: Derivative asset $ $ $ Long–term derivative asset - Total $ $ $ 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 December 31, 2014: Derivative liability $ $ $ - Long–term derivative liability - - - Total $ $ $ -

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2015
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 September 30, 2015: Assets - Oil, natural gas and natural gas liquids derivatives $ $ - $ $ - As of December 31, 2014: Assets - Oil and natural gas derivatives $ $ - $ $ - Liabilities - Interest rate swaps $ $ - $ $ -

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2015
ASSET RETIREMENT OBLIGATIONS [Abstract]
Changes in Aggregate Asset Retirement Obligation	The changes in the aggregate ARO are as follows: 2015 2014 Balance as of January 1 $ $ Liabilities incurred Revisions Accretion expense Settlements and divestitures Balance as of September 30 $ $

OWNERS EQUITY (Tables)

OWNERS EQUITY (Tables)	9 Months Ended
	Sep. 30, 2015
OWNERS' EQUITY [Abstract]
Schedule of Cash Distributions	The following sets forth the distributions we paid during the nine months ended September 30, 2014: Date Paid Period Covered Distribution per Unit Total Distribution February 13, 2015 October 1, 2014 – December 31, 2014 $ $ May 15, 2015 January 1, 2015 – March 31, 2015 August 14, 2015 April 1, 2015 – June 30, 2015 $

DISCONTINUED OPERATIONS (Tables

DISCONTINUED OPERATIONS (Tables)	9 Months Ended
	Sep. 30, 2015
DISCONTINUED OPERATIONS [Abstract]
Discontinued Operation Financial Information	Summarized financial information for our midstream segment is as follows: December 31, 2014 (1) Current assets $ Noncurrent assets Total assets $ Current liabilities $ Owner’s equity Total liabilities and owner’s equity $ Three Months Ended Nine Months Ended September 30, September 30, 2015 (1) 2014 (2) 2015 (1) 2014 (2) Revenues $ - $ $ $ Operating income - Net income - _____________ (1) Information is for UEO on a stand–alone basis through the date of divestiture . (2) Information is for UEO and Cardinal on a combined basis.

NET INCOME (LOSS) PER LIMITED28

NET INCOME (LOSS) PER LIMITED PARTNER UNIT (Tables)	9 Months Ended
	Sep. 30, 2015
NET INCOME (LOSS) PER LIMITED PARTNER UNIT [Abstract]
Calculation of Earnings Per Limited Partner Unit	The following sets forth the calculation of net (loss) income per limited partner unit: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 (Loss) income from continuing operations $ $ $ $ General partner’s 2% interest in (loss) income from continuing operations (Loss) income from continuing operations attributable to unvested phantom units Limited partners’ interest in (loss) income from continuing operations $ $ $ $ Earnings per limited partner unit (basic and diluted) $ $ $ $ Income from discontinued operations $ - $ $ $ General partner’s 2% interest in income from discontinued operations - Income from discontinued operations attributable to unvested phantom units - - Limited partners’ interest in income from discontinued operations $ - $ $ $ Earnings per limited partner unit (basic and diluted) $ - $ $ $ Net (loss) income $ $ $ $ General partner’s 2% interest in net (loss) income Net (loss) income attributable to unvested phantom units Limited partners’ interest in net (loss) income $ $ $ $ Earnings per limited partner unit (basic and diluted) $ $ $ $ Weighted average limited partner units outstanding (basic and diluted)

OTHER SUPPLEMENTAL INFORMATION

OTHER SUPPLEMENTAL INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2015
OTHER SUPPLEMENTAL INFORMATION [Abstract]
Supplemental Cash Flows and Non-Cash Transactions	Supplemental cash flows and noncash transactions were as follows: Nine Months Ended September 30, 2015 2014 Supplemental cash flows information - cash paid for interest, net of capitalized interest of $5,741 at September 30, 2014 $ $ Cash (refunded) paid for income taxes, net $ $ As of September 30, 2015 2014 Noncash transaction - costs for additions to oil and natural gas properties in accounts payable and accrued liabilities $ $
Schedule of Accounts Payable and Accrued Liabilities- Third Party	Accounts payable and accrued liabilities consisted of the following: September 30, December 31, 2015 2014 Costs for additions to oil and natural gas properties $ $ Lease operating expenses Interest Production and ad valorem taxes General and administrative expenses Current portion of ARO Derivative settlements - Other Total $ $

ORGANIZATION AND NATURE OF BU30

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	9 Months Ended
	Sep. 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%

EQUITY-BASED COMPENSATION (Deta

EQUITY-BASED COMPENSATION (Details) - USD ($) $ in Thousands, shares in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost				$ 9,635	$ 15,345
Unvested Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		4 years	4 years	4 years	4 years
Equity-based compensation cost		$ 2,300	$ 2,800	$ 9,400	$ 10,900
Unrecognized compensation expense		$ 14,700		$ 14,700
Weighted average period				2 years 4 months 24 days
Performance units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost			$ 1,500	$ 200	$ 4,400
Shares issued	0.3

RISK MANAGEMENT (Commodity Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	Sep. 30, 2015MMBTU$ / MBbls$ / MMBTUMMBbls
Swaps - 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	36,600
Weighted Average Fixed Price	3.60
Oil [Member] | Swaps - October 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls) | MMBbls	322
Weighted Average Fixed Price | $ / MBbls	90.28
Natural Gas [Member] | Swaps - October 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	9,982
Weighted Average Fixed Price	4.86
Natural Gas [Member] | Swaps - 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls) | MMBbls	366
Weighted Average Fixed Price | $ / MBbls	90.14
Natural Gas [Member] | Swaps - 2017 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus) | MMBTU	21,900
Weighted Average Fixed Price	3.24
Natural Gas Liquids [Member] | Swaps - October 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedge Volume (MBbls) | MMBbls	119.6
Weighted Average Fixed Price | $ / MBbls	24.98

RISK MANAGEMENT (Fair Value of

RISK MANAGEMENT (Fair Value of Derivatives) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Derivative Assets:
Derivative asset, fair value	$ 86,729	$ 135,401
Derivative asset, liability		(1,710)
Derivative asset	71,406	113,044
Long-term derivative asset	15,323	20,647
Net recorded fair value	86,729	133,691
Derivative Liabilities:
Derivative liability, fair value		1,710
Derivative liability, asset		$ (1,710)
Net recorded fair value
Commodity contracts
Derivative Assets:
Derivative asset, fair value	86,729	$ 135,401
Interest rate swaps
Derivative Liabilities:
Derivative liability, fair value		1,710
Derivative Asset [Member]
Derivative Assets:
Derivative asset, fair value	71,406	114,754
Derivative asset, liability		(1,710)
Derivative asset	71,406	113,044
Long-term Derivative Asset [Member]
Derivative Assets:
Derivative asset, fair value	15,323	20,647
Derivative asset	$ 15,323	20,647
Derivative Liability [Member]
Derivative Liabilities:
Derivative liability, fair value		1,710
Derivative liability, asset		$ (1,710)
Derivative liability
Long-term Derivative Liability [Member]
Derivative Liabilities:
Derivative liability

IMPAIRMENT OF OIL AND NATURAL34

IMPAIRMENT OF OIL AND NATURAL GAS PROPERTIES (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Property, Plant and Equipment [Line Items]
Impairment of oil and gas properties	$ 15,787	$ 946	$ 122,244	$ 2,267
Proved Properties [Member]
Property, Plant and Equipment [Line Items]
Impairment of oil and gas properties	15,200		73,300
Unproved Properties [Member]
Property, Plant and Equipment [Line Items]
Impairment of oil and gas properties	600		48,900
Change in Development Plans [Member] | Unproved Properties [Member]
Property, Plant and Equipment [Line Items]
Impairment of oil and gas properties	$ 600		$ 48,400

FAIR VALUE MEASUREMENTS (Narrat

FAIR VALUE MEASUREMENTS (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Fair Value Measurements [Line Items]
Impairment of oil and gas properties	$ 15,787	$ 946	$ 122,244	$ 2,267
Fair value of future expected cash flow	10,400		$ 31,400
8.0% Senior Notes due 2019
Fair Value Measurements [Line Items]
Senior notes, maturity year			2,019	2,019
Senior notes, fair value	352,500		$ 352,500		$ 427,500
Senior notes, carrying value	499,500		499,500		$ 499,400
Proved Properties [Member]
Fair Value Measurements [Line Items]
Impairment of oil and gas properties	15,200		73,300
Unproved Properties [Member]
Fair Value Measurements [Line Items]
Impairment of oil and gas properties	$ 600		$ 48,900

FAIR VALUE MEASUREMENTS (Fair V

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	$ 86,729	$ 135,401
Derivative liability, fair value		1,710
Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	86,729	135,401
Interest rate swaps
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value		1,710
Significant Other Observable Inputs (Level 2) | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	$ 86,729	135,401
Significant Other Observable Inputs (Level 2) | Interest rate swaps
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value		$ 1,710

ASSET RETIREMENT OBLIGATIONS (N

ASSET RETIREMENT OBLIGATIONS (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
ASSET RETIREMENT OBLIGATIONS [Abstract]
Asset retirement obligation, current	$ 1,941	$ 1,941

ASSET RETIREMENT OBLIGATIONS (C

ASSET RETIREMENT OBLIGATIONS (Changes in Aggregate Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
ASSET RETIREMENT OBLIGATIONS [Abstract]
Balance at beginning of period			$ 105,773	$ 103,173
Liabilities incurred			394	560
Revisions			(4,963)	2,419
Accretion expense	$ 1,134	$ 1,244	3,548	3,634
Settlements and divestitures			(4,563)	(2,730)
Balance at end of period	$ 100,189	$ 107,056	$ 100,189	$ 107,056

LONG-TERM DEBT (Narrative) (Det

LONG-TERM DEBT (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)item	Sep. 30, 2014	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 1,000
Senior secured credit facility, expiration date	2020-02
Minimum current ratio required under credit facility | item	1
Maximum total debt to earnings ratio required under credit facility | item	3.5
Weighted average effective interest rate	3.86%	2.99%
Line of credit, borrowing base	$ 500
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.
Line of credit facility amount outstanding	$ 0		$ 531
8.0% Senior Notes due 2019
Debt Instrument [Line Items]
Senior notes, maturity year	2,019	2,019
Senior notes, carrying amount	$ 499.5		$ 499.4
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

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
COMMITMENTS AND CONTINGENCIES [Abstract]
Loss contingency accrual	$ 0	$ 0

OWNERS' EQUITY (Narrative) (Det

OWNERS' EQUITY (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 29, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Stockholders Equity Note [Line Items]
Common units outstanding		48,871,399		48,871,399		48,572,019
Percentage of limited partnership interest				98.00%
Percentage of general partnership interest				2.00%
Units vested				300,000
Contribution from general partner				$ 91	$ 154
Distributions paid				$ 75,738	$ 116,172
Distribution to unitholders declared per unit		$ 0.50	$ 0.774	$ 1.50	$ 2.319
Subsequent Event [Member] | Dividends Declared [Member]
Stockholders Equity Note [Line Items]
Distribution to unitholders declared per unit	$ 0.50
Distribution to unitholders, amount declared	$ 25,200
Distribution to unitholders, record date	Nov. 9, 2015
Distribution to unitholders, payment date	Nov. 13, 2015
Common Unitholders [Member]
Stockholders Equity Note [Line Items]
Common units outstanding		48,871,399		48,871,399

OWNERS' EQUITY (Cash Distributi

OWNERS' EQUITY (Cash Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended			9 Months Ended
	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2015
Total Distribution				$ 75,738
October 1, 2014 - December 31, 2014 [Member]
Date Paid			Feb. 13, 2015
Distribution per Unit			$ 0.50
Total Distribution			$ 25,274
January 1, 2015 - March 31, 2015 [Member]
Date Paid		May 15, 2015
Distribution per Unit		$ 0.50
Total Distribution		$ 25,221
April 1, 2015 - June 30, 2015 [Member]
Date Paid	Aug. 14, 2015
Distribution per Unit	$ 0.50
Total Distribution	$ 25,243

DISCONTINUED OPERATIONS (Narrat

DISCONTINUED OPERATIONS (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Jun. 30, 2015	Sep. 30, 2015	Sep. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties		$ 1,439	$ 7,365
Payment on lines of credit		561,000
Utica East Ohio Midstream LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of equity method investments	$ 572,200
Equity method investment, realized gain (loss) on disposal		$ 246,700
Payment on lines of credit	25,000
Interest paid, discontinued operations	$ 1,500

DISCONTINUED OPERATIONS (Summar

DISCONTINUED OPERATIONS (Summarized Financial Information Discontinued Operations) (Details) - USD ($) $ in Thousands		3 Months Ended	9 Months Ended
		Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Utica East Ohio Midstream LLC and Cardinal Gas Services LLC [Member]
Schedule Of Equity Method Investments [Line Items]
Revenues	[1]	$ 80,509		$ 182,304
Operating income	[1]	46,007		83,408
Net income	[1]	$ 46,074		$ 83,542
Utica East Ohio Midstream LLC
Schedule Of Equity Method Investments [Line Items]
Current assets	[2]				$ 98,061
Noncurrent assets	[2]				1,381,773
Total assets	[2]				1,479,834
Current liabilities	[2]				37,967
Owner's equity	[2]				1,441,867
Total liabilities and owner's equity	[2]				$ 1,479,834
Revenues	[2]		$ 93,726
Operating income	[2]		49,171
Net income	[2]		$ 49,525
[1]	Information is for UEO and Cardinal on a combined basis.
[2]	Information is for UEO on a stand-alone basis through the date of divestiture

NET INCOME (LOSS) PER LIMITED45

NET INCOME (LOSS) PER LIMITED PARTNER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Earnings Per Share Disclosure [Line Items]
Loss from continuing operations	$ (9,838)	$ 36,323	$ (162,915)	$ 16,108
General partner 2% interest in loss from continuing operations	197	(726)	3,257	(322)
Net loss attributable to participating securities, continued operations	(315)	(448)	(972)	(1,385)
Limited partners' interest in loss from continuing operations	$ (9,956)	$ 35,149	$ (160,630)	$ 14,401
Earnings per limited partner unit (basic and diluted) (loss) income, continuing	$ (0.20)	$ 0.72	$ (3.29)	$ 0.29
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		$ 6,297	$ 255,512	$ 11,236
General partner's 2% interest in income from discontinued oeprations		(126)	(5,110)	(225)
Net loss attributable to participating securities, discontinued opreations		(44)	(216)
Limited partners' interest in income from discontinued operations		$ 6,127	$ 250,186	$ 11,011
Earnings per limited partner unit (basic and diluted) income, discontinued		$ 0.13	$ 5.12	$ 0.23
Net income (loss)	$ (9,838)	$ 42,620	$ 92,597	$ 27,344
General partners 2% interest in net income (loss)	197	(852)	(1,852)	(547)
Net loss attributable to participating securities	(315)	(492)	(1,188)	(1,385)
Limited partners' interest in net income (loss)	$ (9,956)	$ 41,276	$ 89,557	$ 25,412
Earnings per share, basic and diluted	$ (0.20)	$ 0.85	$ 1.83	$ 0.52
Weighted average limited partner units outstanding - basic and diluted	48,871	48,572	48,846	48,561
Percentage of general partnership interest			2.00%
Common Unitholders [Member]
Earnings Per Share Disclosure [Line Items]
Earnings per limited partner unit (basic and diluted) (loss) income, continuing	$ (0.20)	$ 0.72	$ (3.29)	$ 0.29
Performance units
Earnings Per Share Disclosure [Line Items]
Equity awards not included in computation of diluted net income (loss) per limited partner unit			200

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - EnerVest, Ltd. - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Related Party Transaction [Line Items]
Administrative fees paid to related party	$ 3.3	$ 3.1	$ 9.9	$ 9.1
Direct expenses incurred and reimbursed to related party	$ 3.5	$ 3.9	$ 11.3	$ 12.2

OTHER SUPPLEMENTAL INFORMATIO47

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Supplemental cash flows information:
Cash paid for interest	$ 26,460	$ 25,783
Cash paid for income taxes		155
Cash (refunded) for income taxes	(115)
Non-cash transactions:
Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$ 6,872	20,973
Capitalized interest		$ 5,741

OTHER SUPPLEMENTAL INFORMATIO48

OTHER SUPPLEMENTAL INFORMATION (Schedule of Accounts Payable and Accrued Liabilities- Third Party) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Other Supplemental Information Disclosure [Abstract]
Costs for additions to oil and natural gas properties	$ 6,872	$ 18,028
Lease operating expenses	8,698	9,701
Interest	18,333	8,649
Production and ad valorem taxes	5,033	5,683
General and administrative expenses	2,375	2,317
Current portion of ARO	1,941	1,941
Derivative settlements		280
Other	1,854	1,279
Total	$ 45,106	$ 47,878

SUBSEQUENT EVENTS - (Narrative)

SUBSEQUENT EVENTS - (Narrative) (Details) $ in Thousands	1 Months Ended		9 Months Ended
	Oct. 31, 2015USD ($)	Sep. 30, 2015USD ($)item	Sep. 30, 2015USD ($)item	Mar. 31, 2018item	Dec. 31, 2017item	Jun. 30, 2017item	Dec. 31, 2016item
Subsequent Event [Line Items]
Deposit on acquisition of oil and natural gas properties		$ 25,900	$ 25,900
Line of credit, maximum borrowing base		$ 1,000,000	$ 1,000,000
Maximum total debt to earnings ratio required under credit facility | item		3.5	3.5
Scenario, Plan [Member]
Subsequent Event [Line Items]
Maximum total debt to earnings ratio required under credit facility | item				4.25	5.25	5.50
Subsequent Event [Member]
Subsequent Event [Line Items]
Business acquisition cost of acquired entity purchase price	$ 259,400
Line of credit, maximum borrowing base	$ 625,000
Secured Debt [Member] | Scenario, Plan [Member]
Subsequent Event [Line Items]
Maximum total debt to earnings ratio required under credit facility | item							3