Harvest Oil & Gas (HRST) 10-Q 11 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	1-May-15
Document Documentand Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	evep
Entity Registrant Name	EV Energy Partners, LP
Entity Central Index Key	1361937
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		48,871,399

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$10,268	$8,255
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	24,500	32,758
Related party	63	1,043
Other	4,657	4,570
Derivative asset	105,046	113,044
Other current assets	1,917	2,000
Assets held for sale	320,244	315,173
Total current assets	466,695	476,843
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; March 31, 2015, $862,738; December 31, 2014, $778,679	1,650,410	1,710,925
Other property, net of accumulated depreciation and amortization; March 31, 2015, $908; December 31, 2014, $898	1,119	1,141
Restricted cash	33,768	33,768
Long-term derivative asset	21,722	20,647
Other assets	8,568	5,879
Total assets	2,182,282	2,249,203
Current liabilities:
Accounts payable and accrued liabilities	51,611	47,878
Asset retirement obligations	105,201	103,832
Long-term debt	1,040,417	1,030,391
Other long-term liabilities	838	989
Commitments and contingencies
Owners' equity:
Common unitholders - 48,871,399 units and 48,572,019 units issued and outstanding as of March 31, 2015 and December 31, 2014, respectively	997,468	1,077,826
General partner interest	-13,253	-11,713
Total owners' equity	984,215	1,066,113
Total liabilities and owners' equity	$2,182,282	$2,249,203

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, except Share data, unless otherwise specified
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$862,738	$778,679
Other property, accumulated depreciation and amortization	$908	$898
Common unitholders, units outstanding	48,871,399	48,572,019
Limited Partner [Member]
Common unitholders, units issued	48,871,399	48,572,019

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Revenues:
Oil, natural gas and natural gas liquids revenues	$46,425		$94,074
Transportation and marketing-related revenues	817		1,265
Total revenues	47,242		95,339
Operating costs and expenses:
Lease operating expenses	23,524		25,395
Cost of purchased natural gas	574		970
Dry hole and exploration costs	414		318
Production taxes	1,748		3,523
Asset retirement obligations accretion expense	1,201		1,187
Depreciation, depletion and amortization	25,896		26,212
General and administrative expenses	12,415		12,298
Impairment of oil and natural gas properties	58,173		252
Gain on sales of oil and natural gas properties	-537		-1,484
Total operating costs and expenses	123,408		68,671
Operating (loss) income	-76,166		26,668
Other income (expense), net:
Gain (loss) on derivatives, net	23,610		-22,995
Interest expense	-14,135		-12,072
Other (expense) income, net	-196		174
Total other income (expense), net	9,279		-34,893
Loss from continuing operations before income taxes	-66,887		-8,225
Income taxes	150		255
Loss from continuing operations	-66,737		-7,970
Income from discontinued operations	5,070		1,717
Net loss	($61,667)		($6,253)
Basic and diluted earnings per limited partner unit:
Earnings per limited partner unit (basic and diluted), continuing	($1.35)		($0.17)
Earnings per limited partner unit (basic and diluted), discontinued	$0.10		$0.03
Net loss	($1.25)		($0.14)
Weighted average limited partner units outstanding:
Weighted average limited partner units outstanding - basic and diluted	48,795	[1]	48,537	[1]
Distributions declared per unit	$0.50		$0.77
[1]	As of March 31, 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 per limited partner unit for the three months ended March 31, 2014 because the effect would have been anti-dilutive.

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Changes in Owners' Equity (USD $)	Limited Partner [Member]	General Partner [Member]	Total
In Thousands
Beginning Balance at Dec. 31, 2013	$1,083,718	($11,785)	$1,071,933
Contributions from general partner		154	154
Distributions	-37,932	-764	-38,696
Other	-5		-5
Equity-based compensation	4,413	90	4,503
Net loss	-6,128	-125	-6,253
Ending Balance at Mar. 31, 2014	1,044,066	-12,430	1,031,636
Beginning Balance at Dec. 31, 2014	1,077,826	-11,713	1,066,113
Contributions from general partner		91	91
Distributions	-24,777	-497	-25,274
Equity-based compensation	4,853	99	4,952
Net loss	-60,434	-1,233	-61,667
Ending Balance at Mar. 31, 2015	$997,468	($13,253)	$984,215

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities:
Net loss	($61,667)	($6,253)
Adjustments to reconcile net loss to net cash flows provided by operating activities:
Income from discontinued operations	-5,070	-1,717
Asset retirement obligations accretion expense	1,201	1,187
Depreciation, depletion and amortization	25,896	26,212
Equity-based compensation cost	4,952	4,503
Impairment of oil and natural gas properties	58,173	252
Gain on sales of oil and natural gas properties	-537	-1,484
Loss on derivatives, net	-23,610	22,995
Cash settlements of matured derivatives contracts	30,533	-6,158
Other	355	56
Changes in operating assets and liabilities:
Accounts receivable	9,151	-15,064
Other current assets	82	-931
Accounts payable and accrued liabilities	5,799	9,154
Other, net		-120
Net cash flows provided by operating activities	45,258	32,632
Cash flows from investing activities:
Additions to oil and natural gas properties	-25,577	-23,145
Prepaid drilling costs		-2,032
Proceeds from sale of oil and natural gas properties	774	7,315
Distributions from unconsolidated affiliates	18	18
Net cash flows used in investing activities from continuing operations	-24,785	-17,844
Net cash flows used in investing activities from discontinued operations		-44,424
Net cash flows used in investing activities	-24,785	-62,268
Cash flows from financing activities:
Long-term debt borrowings	10,000	66,000
Loan costs incurred	-3,277
Contributions from general partner	91	154
Distributions paid	-25,274	-38,696
Other		-5
Net cash flows (used in) provided by financing activities	-18,460	27,453
Increase (decrease) in cash and cash equivalents	2,013	-2,183
Cash and cash equivalents - beginning of year	8,255	11,698
Cash and cash equivalents - end of period	$10,268	$9,515

ORGANIZATION_AND_NATURE_OF_BUS

ORGANIZATION AND NATURE OF BUSINESS	3 Months Ended
	Mar. 31, 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 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.
	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”), which is expected to close in July 2015, we no longer operate in the midstream segment, and we have reclassified our unaudited condensed consolidated financial statements for all periods presented to reflect the operations of our midstream segment as discontinued operations (see Note 9).  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.

EQUITYBASED_COMPENSATION

EQUITY-BASED COMPENSATION	3 Months Ended
	Mar. 31, 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 $4.7 million and $3.1 million in the three months ended March 31, 2015 and 2014, respectively.  These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.
	As of March 31, 2015, there was $19.4 million of total unrecognized compensation cost related to unvested phantom units which is expected to be recognized over a weighted average period of 2.6 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 and $1.4 million in the three months ended March 31, 2015 and 2014, respectively.  These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.

RISK_MANAGEMENT

RISK MANAGEMENT	3 Months Ended
	Mar. 31, 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, changes 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 March 31, 2015, we had entered into commodity contracts with the following terms:
	Period Covered	Hedged Volume	Weighted Average Fixed Price
	Oil (MBbls):
	Swaps – April 2015 to December 2015	962.5	$
			90.28
	Swaps – 2016	366.0	90.14
	Natural Gas (MmBtus):
	Swaps – April 2015 to December 2015	29,837.5	4.86
	Swaps – 2016	18,300.0	4.07
	Natural Gas Liquids (MBbls):
	Swaps – April 2015 to December 2015	357.5	24.98
	As of March 31, 2015, we had entered into interest rate swaps with the following terms:
		Notional	Floating	Fixed
	Period Covered	Amount	Rate	Rate
	April 2015 – July 2015	$	1 Month LIBOR	3.315%
		110,000
	The following table sets forth the fair values and classification of our outstanding derivatives:
				Net Amounts
				Am
			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 March 31, 2015:
	Derivative asset	$	$	$
		105,896	-850	105,046
	Long–term derivative asset	21,722	–	21,722
	Total	$	$	$
		127,618	-850	126,768
	As of December 31, 2014:
	Derivative asset	$	$	$
		114,754	-1,710	113,044
	Long–term derivative asset	20,647	–	20,647
	Total	$	$	$
		135,401	-1,710	133,691
				Net Amounts
				Am
			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 March 31, 2015:
	Derivative liability	$	$	$                 –
		850	-850
	Long–term derivative liability	–	–	–
	Total	$	$	$                 –
		850	-850
	As of December 31, 2014:
	Derivative liability	$	$	$                 –
		1,710	-1,710
	Long–term derivative liability	–	–	–
	Total	$	$	$                 –
		1,710	-1,710
	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, we 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 March 31, 2015 and December 31, 2014, we were not required to post any collateral nor did we hold any collateral associated with our derivatives.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	3 Months Ended
	Mar. 31, 2015
FAIR VALUE MEASUREMENTS [Abstract]
FAIR VALUE MEASUREMENTS	NOTE 4. 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
					significantUnobservable
			Identical	Observable	Unobservable
			Assets	Inputs	Inputs
		Fair Value	(Level 1)	(Level 2)	(Level 3)
	As of March 31, 2015:
	Assets – Oil, natural gas and natural gas
	liquids derivatives	$	$               –	$	$               –
		127,618		127,618
	Liabilities – interest rate swaps	$	$               –	$	$               –
		850		850
	As of December 31, 2014:
	Assets – Oil and natural gas derivatives	$	$               –	$	$               –
		135,401		135,401
	Liabilities – interest rate swaps	$	$               –	$	$               –
		1,710		1,710
	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 March 31, 2015.
	Nonrecurring Basis
	The following table presents the fair value hierarchy table for our net assets and liabilities that are required to be measured at fair value on a nonrecurring basis:
			Fair Value Measurements at the End of the Reporting Period
			Quoted Prices in Active Markets for Identical Assets
			(Level 1)
				Significant Other Observable Inputs
				(Level 2)	Significant Unobservable Inputs
					(Level 3)
						Total
		Fair Value				Losses
	Three months ending March 31, 2015:
	Long–lived assets held and used	$	$          –	$            –	$	$
		31,380			31,380	58,165
	In the three months ended March 31, 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 $456.3 million and $427.5 million at March 31, 2015 and December 31, 2014, respectively, which differs from the carrying value of $499.4 million at both March 31, 2015 and December 31, 2014.  The fair value of the senior notes due 2019 was determined using Level 2 inputs.

ASSET_RETIREMENT_OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	3 Months Ended
	Mar. 31, 2015
ASSET RETIREMENT OBLIGATIONS [Abstract]
ASSET RETIREMENT OBLIGATIONS	NOTE 5. 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	$	$
		105,773	103,173
	Liabilities incurred	288	159
	Revisions	-1	–
	Accretion expense	1,201	1,187
	Settlements and divestitures	-120	-1,573
	Balance as of March 31	$	$
		107,141	102,946
	As of both March 31, 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.

LONGTERM_DEBT

LONG-TERM DEBT	3 Months Ended
	Mar. 31, 2015
LONG-TERM DEBT [Abstract]
LONG-TERM DEBT	NOTE 6. LONG–TERM DEBT
	Credit Facility
	As of March 31, 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 March 31, 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 2.94% and 2.93% at March 31, 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 March 31, 2015, the borrowing base under the facility was $650.0 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.  There will be no redetermination in April 2015 since the borrowing base was redetermined in February 2015 in conjunction with the amendment to our credit facility.
	We had $541.0 million and $531.0 million outstanding under the facility at March 31, 2015 and December 31, 2014, respectively.
	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 $499.4 million at both March 31, 2015 and December 31, 2014, respectively.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2015
COMMITMENTS AND CONTINGENCIES [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 7. 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 March 31, 2015 or December 31, 2014.

OWNERS_EQUITY

OWNERS' EQUITY	3 Months Ended
	Mar. 31, 2015
OWNERS' EQUITY [Abstract]
OWNERS' EQUITY	NOTE 8. OWNERS’ EQUITY
	Units Outstanding
	At March 31, 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 three months ended March 31, 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 contributions of $0.1 million by our general partner to maintain its 2% interest in us.
	Cash Distributions
	On February 2, 2015, the board of directors of EV Management declared a $0.50 per unit distribution for the fourth quarter of 2014 on all common units.  The distribution of $25.3 million was paid on February 13, 2015 to unitholders of record at the close of business on February 9, 2015.
	On April 30, 2015, the board of directors of EV Management declared a $0.50 per unit distribution for the first quarter of 2015 on all common units.  The distribution of $25.3 million is to be paid on May 15, 2015 to unitholders of record at the close of business on May 11, 2015.

DISCONTINUTED_OPERATIONS

DISCONTINUTED OPERATIONS	3 Months Ended
	Mar. 31, 2015
DISCONTINUED OPERATIONS [Abstract]
DISCONTINUTED OPERATIONS	NOTE 9. 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.  We sold our interest in Cardinal in October 2014 and, in April 2015, we signed a definitive agreement to divest our 21% interest in UEO for $575.0 million.  The agreement is subject to customary purchase price adjustments and closing conditions.  We expect the transaction to close in July 2015 and will use the net proceeds from the disposition to repay all amounts outstanding under our credit facility and to fund future activities, including acquisitions of oil and natural gas properties.
	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:
		March 31,	December 31,
		2015 (1)	2014 (1)
	Current assets	$	$
		100,591	98,061
	Noncurrent assets	1,393,644	1,381,773
	Total assets	$	$
		1,494,235	1,479,834
	Current liabilities	$	$
		28,523	37,967
	Owner’s equity	1,465,712	1,441,867
	Total liabilities and owner’s equity	$	$
		1,494,235	1,479,834
		Three Months Ended
		March 31,
		2015 (1)	2014 (2)
	Revenues	$	$
		48,543	42,189
	Operating income	24,474	13,897
	Net income	24,744	13,934
	_____________
	(1)Information is for UEO on a stand–alone basis.
	(2)Information is for UEO and Cardinal on a combined basis.

EARNINGS_PER_LIMITED_PARTNER_U

EARNINGS PER LIMITED PARTNER UNIT	3 Months Ended
	Mar. 31, 2015
EARNINGS PER LIMITED PARTNER UNIT [Abstract]
EARNINGS PER LIMITED PARTNER UNIT	NOTE 10. EARNINGS PER LIMITED PARTNER UNIT
	The following sets forth the calculation of earnings per limited partner unit:
		Three Months Ended
		March 31,
		2015	2014
	Loss from continuing operations	$	$
		-66,737	-7,970
	General partner’s 2% interest in loss from continuing operations	1,334	159
	Loss from continuing operations attributable to unvested phantom units	-342	-483
	Limited partners’ interest in loss from continuing operations	$	$
		-65,745	-8,294
	Earnings per limited partner unit (basic and diluted)	$	$
		-1.35	-0.17
	Income from discontinued operations	$	$
		5,070	1,717
	General partner’s 2% interest in income from discontinued operations	-101	-34
	Limited partners’ interest in income from discontinued operations	$	$
		4,969	1,683
	Earnings per limited partner unit (basic and diluted)	$	$
		0.10	0.03
	Net loss	$	$
		-61,667	-6,253
	General partner’s 2% interest in net loss	1,233	125
	Net loss attributable to unvested phantom units	-342	-483
	Limited partners’ interest in net loss	$	$
		-60,776	-6,611
	Earnings per limited partner unit (basic and diluted)	$	$
		-1.25	-0.14
	Weighted average limited partner units outstanding – basic and diluted (1)	48,795	48,537
	_____________
	(1)As of March 31, 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 per limited partner unit for the three months ended March 31, 2014 because the effect would have been anti–dilutive.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	3 Months Ended
	Mar. 31, 2015
RELATED PARTY TRANSACTIONS [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 11. RELATED PARTY TRANSACTIONS
	Pursuant to an omnibus agreement, we paid EnerVest $3.3 million and $3.0 million in the three months ended March 31, 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.
	We 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 $4.1 million and $4.5 million in the three months ended March 31, 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	3 Months Ended
	Mar. 31, 2015
OTHER SUPPLEMENTAL INFORMATION [Abstract]
OTHER SUPPLEMENTAL INFORMATION	NOTE 12. OTHER SUPPLEMENTAL INFORMATION
	Supplemental cash flows and noncash transactions were as follows:
		Three Months Ended
		March 31,
		2015	2014
	Supplemental cash flows information – cash paid for interest, net of capitalized
	interest of $1,939 at March 31, 2014	$	$
		3,303	1,105
		As of March 31,
		2015	2014
	Noncash transaction – costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$	$
		15,964	13,100
	Accounts payable and accrued liabilities consisted of the following:
		March 31,	December 31,
		2015	2014
	Costs for additions to oil and natural gas properties	$	$
		15,964	18,028
	Lease operating expenses	8,701	9,701
	Interest	18,717	8,649
	Production and ad valorem taxes	2,649	5,683
	General and administrative expenses	1,970	2,317
	Current portion of ARO	1,941	1,941
	Derivative settlements	297	280
	Other	1,372	1,279
	Total	$	$
		51,611	47,878

NEW_ACCOUNTING_STANDARDS

NEW ACCOUNTING STANDARDS	3 Months Ended
	Mar. 31, 2015
NEW ACCOUNTING STANDARDS [Abstract]
NEW ACCOUNTING STANDARDS	NOTE 13. 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.
	No other new accounting pronouncements issued or effective during the three months ended March 31, 2015 have had or are expected to have a material impact on our unaudited condensed consolidated financial statements.

ORGANIZATION_AND_NATURE_OF_BUS1

ORGANIZATION AND NATURE OF BUSINESS (Policy)	3 Months Ended
	Mar. 31, 2015
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.
	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”), which is expected to close in July 2015, we no longer operate in the midstream segment, and we have reclassified our unaudited condensed consolidated financial statements for all periods presented to reflect the operations of our midstream segment as discontinued operations (see Note 9).  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)	3 Months Ended
	Mar. 31, 2015
RISK MANAGEMENT [Abstract]
Commodity Contracts	As of March 31, 2015, we had entered into commodity contracts with the following terms:
	Period Covered	Hedged Volume	Weighted Average Fixed Price
	Oil (MBbls):
	Swaps – April 2015 to December 2015	962.5	$
			90.28
	Swaps – 2016	366.0	90.14
	Natural Gas (MmBtus):
	Swaps – April 2015 to December 2015	29,837.5	4.86
	Swaps – 2016	18,300.0	4.07
	Natural Gas Liquids (MBbls):
	Swaps – April 2015 to December 2015	357.5	24.98
Interest Rate Swaps	As of March 31, 2015, we had entered into interest rate swaps with the following terms:
		Notional	Floating	Fixed
	Period Covered	Amount	Rate	Rate
	April 2015 – July 2015	$	1 Month LIBOR	3.315%
		110,000
Fair Value of Derivatives	The following table sets forth the fair values and classification of our outstanding derivatives:
				Net Amounts
				Am
			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 March 31, 2015:
	Derivative asset	$	$	$
		105,896	-850	105,046
	Long–term derivative asset	21,722	–	21,722
	Total	$	$	$
		127,618	-850	126,768
	As of December 31, 2014:
	Derivative asset	$	$	$
		114,754	-1,710	113,044
	Long–term derivative asset	20,647	–	20,647
	Total	$	$	$
		135,401	-1,710	133,691
				Net Amounts
				Am
			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 March 31, 2015:
	Derivative liability	$	$	$                 –
		850	-850
	Long–term derivative liability	–	–	–
	Total	$	$	$                 –
		850	-850
	As of December 31, 2014:
	Derivative liability	$	$	$                 –
		1,710	-1,710
	Long–term derivative liability	–	–	–
	Total	$	$	$                 –
		1,710	-1,710

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	3 Months Ended
	Mar. 31, 2015
FAIR VALUE MEASUREMENTS [Abstract]
Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis	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
					significantUnobservable
			Identical	Observable	Unobservable
			Assets	Inputs	Inputs
		Fair Value	(Level 1)	(Level 2)	(Level 3)
	As of March 31, 2015:
	Assets – Oil, natural gas and natural gas
	liquids derivatives	$	$               –	$	$               –
		127,618		127,618
	Liabilities – interest rate swaps	$	$               –	$	$               –
		850		850
	As of December 31, 2014:
	Assets – Oil and natural gas derivatives	$	$               –	$	$               –
		135,401		135,401
	Liabilities – interest rate swaps	$	$               –	$	$               –
		1,710		1,710
Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Nonrecurring Basis	Nonrecurring Basis
	The following table presents the fair value hierarchy table for our net assets and liabilities that are required to be measured at fair value on a nonrecurring basis:
			Fair Value Measurements at the End of the Reporting Period
			Quoted Prices in Active Markets for Identical Assets
			(Level 1)
				Significant Other Observable Inputs
				(Level 2)	Significant Unobservable Inputs
					(Level 3)
						Total
		Fair Value				Losses
	Three months ending March 31, 2015:
	Long–lived assets held and used	$	$          –	$            –	$	$
		31,380			31,380	58,165

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	3 Months Ended
	Mar. 31, 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	$	$
		105,773	103,173
	Liabilities incurred	288	159
	Revisions	-1	–
	Accretion expense	1,201	1,187
	Settlements and divestitures	-120	-1,573
	Balance as of March 31	$	$
		107,141	102,946

DISCONTINUED_OPERATIONS_Tables

DISCONTINUED OPERATIONS (Tables)	3 Months Ended
	Mar. 31, 2015
DISCONTINUED OPERATIONS [Abstract]
Discontinued Operation Financial Information	Summarized financial information for our midstream segment is as follows:
		March 31,	December 31,
		2015 (1)	2014 (1)
	Current assets	$	$
		100,591	98,061
	Noncurrent assets	1,393,644	1,381,773
	Total assets	$	$
		1,494,235	1,479,834
	Current liabilities	$	$
		28,523	37,967
	Owner’s equity	1,465,712	1,441,867
	Total liabilities and owner’s equity	$	$
		1,494,235	1,479,834
		Three Months Ended
		March 31,
		2015 (1)	2014 (2)
	Revenues	$	$
		48,543	42,189
	Operating income	24,474	13,897
	Net income	24,744	13,934
	_____________
	(1)Information is for UEO on a stand–alone basis.
	(2)Information is for UEO and Cardinal on a combined basis.

EARNINGS_PER_LIMITED_PARTNER_U1

EARNINGS PER LIMITED PARTNER UNIT (Tables)	3 Months Ended
	Mar. 31, 2015
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
		March 31,
		2015	2014
	Loss from continuing operations	$	$
		-66,737	-7,970
	General partner’s 2% interest in loss from continuing operations	1,334	159
	Loss from continuing operations attributable to unvested phantom units	-342	-483
	Limited partners’ interest in loss from continuing operations	$	$
		-65,745	-8,294
	Earnings per limited partner unit (basic and diluted)	$	$
		-1.35	-0.17
	Income from discontinued operations	$	$
		5,070	1,717
	General partner’s 2% interest in income from discontinued operations	-101	-34
	Limited partners’ interest in income from discontinued operations	$	$
		4,969	1,683
	Earnings per limited partner unit (basic and diluted)	$	$
		0.10	0.03
	Net loss	$	$
		-61,667	-6,253
	General partner’s 2% interest in net loss	1,233	125
	Net loss attributable to unvested phantom units	-342	-483
	Limited partners’ interest in net loss	$	$
		-60,776	-6,611
	Earnings per limited partner unit (basic and diluted)	$	$
		-1.25	-0.14
	Weighted average limited partner units outstanding – basic and diluted (1)	48,795	48,537
	_____________
	(1)As of March 31, 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 per limited partner unit for the three months ended March 31, 2014 because the effect would have been anti–dilutive.

OTHER_SUPPLEMENTAL_INFORMATION1

OTHER SUPPLEMENTAL INFORMATION (Tables)	3 Months Ended
	Mar. 31, 2015
OTHER SUPPLEMENTAL INFORMATION [Abstract]
Supplemental Cash Flows and Non-Cash Transactions	Supplemental cash flows and noncash transactions were as follows:
		Three Months Ended
		March 31,
		2015	2014
	Supplemental cash flows information – cash paid for interest, net of capitalized
	interest of $1,939 at March 31, 2014	$	$
		3,303	1,105
		As of March 31,
		2015	2014
	Noncash transaction – costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$	$
		15,964	13,100
Schedule of Accounts Payable and Accrued Liabilities- Third Party	Accounts payable and accrued liabilities consisted of the following:
		March 31,	December 31,
		2015	2014
	Costs for additions to oil and natural gas properties	$	$
		15,964	18,028
	Lease operating expenses	8,701	9,701
	Interest	18,717	8,649
	Production and ad valorem taxes	2,649	5,683
	General and administrative expenses	1,970	2,317
	Current portion of ARO	1,941	1,941
	Derivative settlements	297	280
	Other	1,372	1,279
	Total	$	$
		51,611	47,878

ORGANIZATION_AND_NATURE_OF_BUS2

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	3 Months Ended
	Mar. 31, 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%

EQUITYBASED_COMPENSATION_Detai

EQUITY-BASED COMPENSATION (Details) (USD $)	1 Months Ended	3 Months Ended
Share data in Millions, unless otherwise specified	Sep. 30, 2011	Mar. 31, 2015	Mar. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost		$4,952,000	$4,503,000
Unvested Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		4 years
Equity-based compensation cost		4,700,000	3,100,000
Unrecognized compensation expense		19,400,000
Weighted average period		2 years 7 months 6 days
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation cost		$200,000	$1,400,000
Shares issued	0.3

RISK_MANAGEMENT_Commodity_Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	Mar. 31, 2015
	MBbls
Oil [Member] | Swaps - April 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls)	962.5
Weighted Average Fixed Price	90.28
Oil [Member] | Swaps - 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MBbls)	366
Weighted Average Fixed Price	90.14
Natural Gas [Member] | Swaps - April 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus)	29,837.50
Weighted Average Fixed Price	4.86
Natural Gas [Member] | Swaps - 2016 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedged Volume (MmmBtus)	18,300
Weighted Average Fixed Price	4.07
Natural Gas Liquids [Member] | Swaps - April 2015 to December 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Hedge Volume (MBbls)	357.5
Weighted Average Fixed Price	24.98

RISK_MANAGEMENT_Interest_Rate_

RISK MANAGEMENT (Interest Rate Swaps) (Details) (Interest Rate Swaps Covering April 2015 - July 2015 [Member], USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Interest Rate Swaps Covering April 2015 - July 2015 [Member]
Derivative Instruments Related to Oil and Gas Production [Line Items]
Notional amount	$110,000
Floating rate	1 Month LIBOR
Fixed rate	3.32%

RISK_MANAGEMENT_Fair_Value_of_

RISK MANAGEMENT (Fair Value of Derivatives) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivative Assets:
Derivative asset, fair value	$127,618	$135,401
Derivative asset, liability	-850	-1,710
Derivative asset	105,046	113,044
Long-term derivative asset	21,722	20,647
Net recorded fair value	126,768	133,691
Derivative Liabilities:
Derivative liability, fair value	850	1,710
Derivative liability, asset	-850	-1,710
Net recorded fair value
Commodity Contracts [Member]
Derivative Assets:
Derivative asset, fair value	127,618	135,401
Interest Rate Swaps [Member]
Derivative Liabilities:
Derivative liability, fair value	850	1,710
Derivative Asset [Member]
Derivative Assets:
Derivative asset, fair value	105,896	114,754
Derivative asset, liability	-850	-1,710
Derivative asset	105,046	113,044
Long-term Derivative Asset [Member]
Derivative Assets:
Derivative asset, fair value	21,722	20,647
Long-term derivative asset	21,722	20,647
Derivative Liability [Member]
Derivative Liabilities:
Derivative liability, fair value	850	1,710
Derivative liability, asset	-850	-1,710
Derivative liability
Long-term Derivative Liability [Member]
Derivative Liabilities:
Derivative liability

FAIR_VALUE_MEASUREMENTS_Narrat

FAIR VALUE MEASUREMENTS (Narrative) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Fair Value Measurements [Line Items]
Impairment of oil and gas properties	$58,173,000	$252,000
Total losses	58,165,000
8.0% Senior Notes due 2019 [Member]
Fair Value Measurements [Line Items]
Senior notes, maturity year	2019
Senior notes, fair value	456,300,000		427,500,000
Senior notes, carrying value	499,400,000		499,400,000
Long Lived Assets Held And Used [Member]
Fair Value Measurements [Line Items]
Long-lived assets	$31,380,000

FAIR_VALUE_MEASUREMENTS_Fair_V

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	$127,618	$135,401
Derivative liability, fair value	850	1,710
Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	127,618	135,401
Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value	850	1,710
Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value
Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value
Significant Other Observable Inputs (Level 2) [Member] | Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value	127,618	135,401
Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value	850	1,710
Significant Unobservable Inputs (Level 3) [Member] | Commodity Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative asset, fair value
Significant Unobservable Inputs (Level 3) [Member] | Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative liability, fair value

FAIR_VALUE_MEASUREMENTS_Fair_V1

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Nonrecurring Basis) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Fair Value Assets And Liabilities Measured On Nonrecurring Basis [Line Items]
Total losses	$58,165
Long Lived Assets Held And Used [Member]
Fair Value Assets And Liabilities Measured On Nonrecurring Basis [Line Items]
Long-lived assets	31,380
Significant Unobservable Inputs (Level 3) [Member] | Long Lived Assets Held And Used [Member]
Fair Value Assets And Liabilities Measured On Nonrecurring Basis [Line Items]
Long-lived assets	$31,380

ASSET_RETIREMENT_OBLIGATIONS_N

ASSET RETIREMENT OBLIGATIONS (Narrative) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
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 $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
ASSET RETIREMENT OBLIGATIONS [Abstract]
Balance at beginning of period	$105,773	$103,173
Liabilities incurred	288	159
Accretion expense	1,201	1,187
Revisions	-1
Settlements and divestitures	-120	-1,573
Balance at end of period	$107,141	$102,946

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
	item
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	1
Maximum total debt to earnings ratio required under credit facility	3.5
Weighted average effective interest rate	2.94%	2.93%
Line of credit, borrowing base	650
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. There will be no redetermination in April 2015 since the borrowing base was redetermined in February 2015 in conjunction with the amendment to our credit facility.
Line of credit facility amount outstanding	541		531
8.0% Senior Notes due 2019 [Member]
Debt Instrument [Line Items]
Senior notes, maturity year	2019
Senior notes, carrying amount	499.4		499.4
Borrowing Base Determination, Period One
Debt Instrument [Line Items]
Borrowing base scheduled redetermination date	3
Borrowing Base Determination, Period Two
Debt Instrument [Line Items]
Borrowing base scheduled redetermination date	9
Letter of Credit
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$100

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
COMMITMENTS AND CONTINGENCIES [Abstract]
Loss contingency accrual	$0	$0

OWNERS_EQUITY_Narrative_Detail

OWNERS' EQUITY (Narrative) (Details) (USD $)	0 Months Ended	3 Months Ended		0 Months Ended
	Feb. 02, 2015	Mar. 31, 2015	Mar. 31, 2014	Apr. 29, 2014	Dec. 31, 2014
Stockholders Equity Note [Line Items]
Common units outstanding		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		$91,000	$154,000
Distributions paid		25,274,000	38,696,000
Distribution to unitholders declared per unit	$0.50	$0.50	$0.77
Distribution to unitholders, amount declared	25,300,000
Distribution to unitholders, record date	9-Feb-15
Distribution to unitholders, payment date	13-Feb-15
Dividend Declared
Stockholders Equity Note [Line Items]
Distribution to unitholders declared per unit				$0.50
Distribution to unitholders, amount declared				$25,300,000
Distribution to unitholders, record date				11-May-15
Distribution to unitholders, payment date				15-May-15
Common Unitholders [Member]
Stockholders Equity Note [Line Items]
Common units outstanding		48,871,399

DISCONTINUED_OPERATIONS_Narrat

DISCONTINUED OPERATIONS (Narrative) (Details) (USD $)	3 Months Ended		1 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Apr. 30, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties	$774	$7,315
Utica East Ohio Midstream LLC [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity investment, ownership percentage			21.00%
Utica East Ohio Midstream LLC [Member] | Subsequent Event [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and natural gas properties			$575,000

DISCONTINUED_OPERATIONS_Summar

DISCONTINUED OPERATIONS (Summarized Financial Information Discontinued Operations) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2015		Dec. 31, 2014
Utica East Ohio Midstream LLC and Cardinal Gas Services LLC [Member]
Schedule Of Equity Method Investments [Line Items]
Revenues	$42,189	[1]
Operating income	13,897	[1]
Net income	13,934	[1]
Utica East Ohio Midstream LLC [Member]
Schedule Of Equity Method Investments [Line Items]
Current assets			100,591	[2]	98,061	[2]
Noncurrent assets			1,393,644	[2]	1,381,773	[2]
Total assets			1,494,235	[2]	1,479,834	[2]
Current liabilities			28,523	[2]	37,967	[2]
Owner's equity			1,465,712	[2]	1,441,867	[2]
Total liabilities and owner's equity			1,494,235	[2]	1,479,834	[2]
Revenues			48,543	[2]
Operating income			24,474	[2]
Net income			$24,744	[2]
[1]	Information is for UEO and Cardinal on a combined basis.
[2]	Information is for UEO on a stand-alone basis.

EARNINGS_PER_LIMITED_PARTNER_U2

EARNINGS PER LIMITED PARTNER UNIT (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Earnings Per Share Disclosure [Line Items]
Loss from continuing operations	($66,737)		($7,970)
General partner 2% interest in loss from continuing operations	1,334		159
Limited partners' interest in loss from continuing operations	-65,745		-8,294
Earnings per limited partner unit (basic and diluted), continuing	($1.35)		($0.17)
Income from discontinued operations	5,070		1,717
General partner's 2% interest in income from discontinued oeprations	-101		-34
Limited partners' interest in income from discontinued operations	4,969		1,683
Earnings per limited partner unit (basic and diluted), discontinued	$0.10		$0.03
Net loss	-61,667		-6,253
General partners 2% interest in net loss	1,233		125
Net loss attributable to participating securities	-342		-483
Limited partners' interest in net income	($60,776)		($6,611)
Earnings per share, basic and diluted	($1.25)		($0.14)
Weighted average limited partner units outstanding - basic and diluted	48,795,000	[1]	48,537,000	[1]
Percentage of general partnership interest	2.00%
Limited Partner [Member]
Earnings Per Share Disclosure [Line Items]
Earnings per limited partner unit (basic and diluted), continuing	($1.35)		($0.17)
Earnings per limited partner unit (basic and diluted), discontinued	$0.10		$0.03
Performance Units [Member]
Earnings Per Share Disclosure [Line Items]
Equity awards not included in computation of diluted net income (loss) per limited partner unit	200,000
[1]	As of March 31, 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 per limited partner unit for the three months ended March 31, 2014 because the effect would have been anti-dilutive.

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (EnerVest, Ltd., USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
EnerVest, Ltd.
Related Party Transaction [Line Items]
Administrative fees paid to related party	$3.30	$3
Direct expenses incurred and reimbursed to related party	$4.10	$4.50

OTHER_SUPPLEMENTAL_INFORMATION2

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Supplemental cash flows information:
Cash paid for interest	$3,303	$1,105
Non-cash transactions:
Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	15,964	13,100
Capitalized interest		$1,939

OTHER_SUPPLEMENTAL_INFORMATION3

OTHER SUPPLEMENTAL INFORMATION (Schedule of Accounts Payable and Accrued Liabilities- Third Party) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Other Supplemental Information Disclosure [Abstract]
Costs for additions to oil and natural gas properties	$15,964	$18,028
Lease operating expenses	8,701	9,701
Interest	18,717	8,649
Production and ad valorem taxes	2,649	5,683
General and administrative expenses	1,970	2,317
Current portion of ARO	1,941	1,941
Derivative settlements	297	280
Other	1,372	1,279
Total	$51,611	$47,878