Harvest Oil & Gas (HRST) 10-Q 12 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013
Document Documentand Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Trading Symbol	'evep	'
Entity Registrant Name	'EV Energy Partners, LP	'
Entity Central Index Key	'0001361937	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	48,349,080

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$10,638	$7,486
Accounts receivable:	'	'
Oil, natural gas and natural gas liquids revenues	38,278	34,909
Related party	7,562	1,422
Other	214	11,263
Derivative asset	22,807	40,771
Other current assets	7,185	1,750
Total current assets	86,684	97,601
Oil and natural gas properties, net of accumulated depreciation, depletion and amortization; September 30, 2013, $475,543; December 31, 2012, $389,206	1,853,014	1,875,890
Other property, net of accumulated depreciation and amortization; September 30, 2013, $714; December 31, 2012, $598	1,266	1,325
Long-term derivative asset	37,680	45,839
Investments in unconsolidated affiliates	206,581	34,545
Other assets	8,465	10,214
Total assets	2,193,690	2,065,414
LIABILITIES AND OWNERS' EQUITY	'	'
Accounts payable and accrued expenses	60,745	40,171
Derivative liability	39	'
Total current liabilities	60,784	40,171
Asset retirement obligations	99,307	102,707
Long-term debt	1,084,276	859,218
Other long-term liabilities	1,589	3,494
Commitments and contingencies	'	'
Owners' equity:	'	'
Common unitholders - 42,599,080 units and 42,320,707 units issued and outstanding as of September 30, 2013 and December 31, 2012, respectively	962,017	1,072,175
General partner interest	-14,283	-12,351
Total owners' equity	947,734	1,059,824
Total liabilities and owners' equity	$2,193,690	$2,065,414

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified
Statement Of Financial Position [Abstract]	'	'
Oil and natural gas properties, accumulated depreciation, depletion and amortization	$475,543	$389,206
Other property, accumulated depreciation and amortization	$714	$598
Common unitholders, units issued	42,599,080	42,320,707
Common unitholders, units outstanding	42,599,080	42,320,707

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues:	'	'	'	'
Oil, natural gas and natural gas liquids revenues	$80,324	$67,747	$233,325	$207,341
Transportation and marketing-related revenues	1,090	954	3,393	2,643
Total revenues	81,414	68,701	236,718	209,984
Operating costs and expenses:	'	'	'	'
Lease operating expenses	26,185	24,821	78,496	78,271
Cost of purchased natural gas	792	662	2,486	1,808
Dry hole and exploration costs	1,150	1,809	2,469	5,664
Production taxes	2,911	2,587	8,751	8,394
Asset retirement obligations accretion expense	1,185	1,335	3,744	3,763
Depreciation, depletion and amortization	27,936	28,141	86,439	81,127
General and administrative expenses	8,928	10,296	30,671	32,562
Impairment of oil and natural gas properties	143	853	8,141	17,752
Total operating costs and expenses	69,230	70,504	221,197	229,341
Operating income (loss)	12,184	-1,803	15,521	-19,357
Other (expense) income, net:	'	'	'	'
Realized gains on derivatives, net	4,878	29,835	20,098	88,628
Unrealized losses on derivatives, net	-16,525	-65,870	-24,512	-38,672
Interest expense	-12,858	-12,808	-37,291	-36,487
Other (expense) income, net	-10	408	232	382
Total other (expense) income, net	-24,515	-48,435	-41,473	13,851
Loss before income taxes and equity in (losses) income of unconsolidated affiliates	-12,331	-50,238	-25,952	-5,506
Income taxes	67	193	-326	-904
Loss before equity in (losses) income of unconsolidated affiliates	-12,264	-50,045	-26,278	-6,410
Equity in (losses) income of unconsolidated affiliates	-50	26	237	-60
Net loss	($12,314)	($50,019)	($26,041)	($6,470)
Net loss per limited partner unit:	'	'	'	'
Basic	($0.29)	($1.15)	($0.63)	($0.15)
Diluted	($0.29)	($1.15)	($0.63)	($0.15)
Weighted average limited partner units outstanding:	'	'	'	'
Basic	42,599	42,452	42,578	41,784
Diluted	42,599	42,452	42,578	41,784
Distributions declared per unit	$0.77	$0.77	$2.31	$2.29

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Changes in Owners' Equity (USD $)	Common Unitholders [Member]	Class B Unitholders [Member]	General Partner [Member]	Total
In Thousands
Beginning Balance at Dec. 31, 2011	$935,425	$232	($15,618)	$920,039
Conversion vested phantom units	2,836	'	'	2,836
Proceeds from public equity offering, net of offering costs of $304	262,529	'	'	262,529
Contributions from general partner	'	'	5,714	5,714
Distributions	-85,050	-8,878	-1,917	-95,845
Equity-based compensation	10,374	'	'	10,374
Net loss	-5,873	-468	-129	-6,470
Ending Balance at Sep. 30, 2012	1,120,241	-9,114	-11,950	1,099,177
Beginning Balance at Dec. 31, 2012	1,072,175	'	-12,351	1,059,824
Conversion vested phantom units	2,365	'	'	2,365
Contributions from general partner	'	'	334	334
Distributions	-99,643	'	-2,003	-101,646
Equity-based compensation	12,640	'	258	12,898
Net loss	-25,520	'	-521	-26,041
Ending Balance at Sep. 30, 2013	$962,017	'	($14,283)	$947,734

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Changes in Owners' Equity (Parenthetical) (USD $)	9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Statement Of Partners Capital [Abstract]	'	'
Conversion of vested phantom units, units	40,264	41,075
Proceeds from public equity offerings, underwriters discount and offering costs	'	$304

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities:	'	'
Net loss	($26,041)	($6,470)
Adjustments to reconcile net loss to net cash flows provided by operating activities:	'	'
Asset retirement obligations accretion expense	3,744	3,763
Depreciation, depletion and amortization	86,439	81,127
Equity-based compensation cost	13,080	12,390
Impairment of oil and natural gas properties	8,141	17,752
Noncash derivative activity	26,162	39,395
Equity in (income) losses of unconsolidated affiliates	-237	60
Distribution from unconsolidated affiliates	171	'
Other	2,313	4,698
Changes in operating assets and liabilities:	'	'
Accounts receivable	-6,430	3,138
Other current assets	-5,435	656
Accounts payable and accrued liabilities	17,889	20,479
Other, net	-561	-1,955
Net cash flows provided by operating activities	119,235	175,033
Cash flows from investing activities:	'	'
Acquisitions of oil and natural gas properties	'	-118,925
Final settlement of purchase price of oil and natural gas properties	7,998	'
Additions to oil and natural gas properties	-75,799	-100,392
Proceeds from sale of oil and natural gas properties	'	5,522
Investments in unconsolidated affiliates	-172,003	-18,998
Distributions from unconsolidated affiliates	33	'
Settlements from acquired derivatives	'	4,166
Net cash flows used in investing activities	-239,771	-228,627
Cash flows from financing activities:	'	'
Long-term debt borrowings	225,000	120,000
Repayment of long-term debt borrowings	'	-460,000
Proceeds from debt offering	'	206,000
Loan costs incurred	'	-4,152
Proceeds from public equity offering	'	262,833
Offering costs	'	-304
Contributions from general partner	334	5,714
Distributions paid	-101,646	-95,845
Net cash flows provided by financing activities	123,688	34,246
Increase (decrease) in cash and cash equivalents	3,152	-19,348
Cash and cash equivalents - beginning of period	7,486	30,312
Cash and cash equivalents - end of period	$10,638	$10,964

ORGANIZATION_AND_NATURE_OF_BUS

ORGANIZATION AND NATURE OF BUSINESS	9 Months Ended
	Sep. 30, 2013
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. (the “Parent”) and its wholly owned subsidiaries (“we,” “our” or “us”) are a publicly held limited partnership that engages in the acquisition, development and production of oil and natural gas properties.  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.
	We operate in one reportable segment engaged in the exploration, 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, 2012.
	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	9 Months Ended
	Sep. 30, 2013
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 accounted for the phantom units issued prior to 2009 as liability awards, and the fair value of these phantom units was remeasured at the end of each reporting period based on the current market price of our common units until settlement.  Prior to settlement, compensation cost was recognized for these phantom units based on the proportionate amount of the requisite service period that has been rendered to date.  The last of these phantom units vested in January 2013.
	We account for the phantom units issued beginning in 2009 as equity awards, and we estimated the fair value of these phantom units using the Black–Scholes option pricing model.  We account for the performance units as equity awards, and we estimated the fair value of these market condition performance units using the Monte Carlo simulation model.
	The following table presents the compensation costs recognized in our unaudited condensed consolidated statements of operations:
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2013	2012	2013	2012
	Liability awards	$              –	$	$	$
			836	182	2,016
	Equity awards	4,297	3,458	12,898	10,374
	Total	$	$	$	$
		4,297	4,294	13,080	12,390
	These costs are included in “General and administrative expenses” in our unaudited condensed consolidated statements of operations.
	As of September 30, 2013, there was $31.0 million of unrecognized compensation costs related to our unvested phantom units and performance units which are expected to be recognized over a weighted average period of 2.3 years.

INVESTMENTS_IN_UNCONSOLIDATED_

INVESTMENTS IN UNCONSOLIDATED AFFILIATES	9 Months Ended
	Sep. 30, 2013
INVESTMENTS IN UNCONSOLIDATED AFFILIATES [Abstract]	'
INVESTMENTS IN UNCONSOLIDATED AFFILIATES	'
	NOTE 3. INVESTMENTS IN UNCONSOLIDATED AFFILIATES
	The most significant of our investments in unconsolidated affiliates are Cardinal Gas Services, LLC (“Cardinal”) and Utica East Ohio Midstream LLC (“UEO”).  We own 9% of Cardinal and 21% of UEO, which are constructing and operating natural gas processing, natural gas liquids fractionation and connecting pipeline facilities to serve production in the Utica Shale in Ohio.

RISK_MANAGEMENT

RISK MANAGEMENT	9 Months Ended
	Sep. 30, 2013
RISK MANAGEMENT [Abstract]	'
RISK MANAGEMENT	'
	NOTE 4. RISK MANAGEMENT
	Our business activities expose us to risks associated with changes in the market price of oil, natural gas and natural gas liquids.  In addition, our floating rate credit facility exposes us to risks associated with changes in interest rates.  As such, future earnings are subject to fluctuation due to changes in the market prices of oil, natural gas and natural gas liquids and interest rates.  We use derivatives to reduce our risk of volatility in the prices of oil, natural gas and natural gas liquids and interest rates.  Our policies do not permit the use of derivatives for speculative purposes.
	We have elected not to designate any of our derivatives as hedging instruments.  Accordingly, changes in the fair value of our derivatives are recorded immediately to operations as “Unrealized losses on derivatives, net” in our unaudited condensed consolidated statements of operations.
	As of September 30, 2013, we had entered into commodity contracts with the following terms:
	Period Covered	Hedged Volume	Weighted Average Fixed Price
	Oil (MBbls):
	Swaps – October 2013 to December 2013	379.5	$
			88.94
	Swaps – 2014	1,517.7	91.19
	Swaps – 2015	730.0	90.09
	Natural Gas (MmmBtus):
	Swaps – October 2013 to December 2013	9,319.6	4.93
	Swaps – 2014	31,609.0	4.88
	Swaps – 2015	31,572.5	5.07
	As of September 30, 2013, we had entered into interest rate swaps with the following terms:
		Notional	Floating	Fixed
	Period Covered	Amount	Rate	Rate
	October 2013 – 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 Sheets	Balance Sheets
	Derivatives:
	As of September 30, 2013:
	Derivative asset	$	$	$
		37,913	-15,106	22,807
	Long–term derivative asset	40,374	-2,694	37,680
	Total	$	$	$
		78,287	-17,800	60,487
	As of December 31, 2012:
	Derivative asset	$	$	$
		44,173	-3,402	40,771
	Long–term derivative asset	50,692	-4,853	45,839
	Total	$	$	$
		94,865	-8,255	86,610
				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 Sheets	Balance Sheets
	Derivatives:
	As of September 30, 2013:
	Derivative liability	$	$	$
		15,145	-15,106	39
	Long–term derivative liability	2,694	-2,694	–
	Total	$	$	$
		17,839	-17,800	39
	As of December 31, 2012:
	Derivative liability	$	$	$                   –
		3,402	-3,402
	Long–term derivative liability	4,853	-4,853	–
	Total	$	$	$                   –
		8,255	-8,255
	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 September 30, 2013 and December 31, 2012, we were not required to post any collateral nor did we hold any collateral associated with our derivatives.
The following table presents the impact of derivatives and their location within the unaudited condensed consolidated statements of operations:
	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2013	2012	2013	2012
Realized gains on derivatives, net:
Commodity contracts	$	$	$	$
	6,231	31,571	24,351	92,523
Interest rate swaps	-1,353	-1,736	-4,253	-3,895
Total	$	$	$	$
	4,878	29,835	20,098	88,628
Unrealized losses on derivatives, net:
Commodity contracts	$	$	$	$
	-17,577	-66,783	-28,654	-40,321
Interest rate swaps	1,052	913	4,142	1,649
Total	$	$	$	$
	-16,525	-65,870	-24,512	-38,672

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2013
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
					significantUnobservable
			Identical	Observable	Unobservable
			Assets	Inputs	Inputs
		Fair Value	(Level 1)	(Level 2)	(Level 3)
	As of September 30, 2013:
	Assets – Commodity contracts	$	$               –	$	$               –
		78,287		78,287
	Liabilities:
	Commodity contracts	$	$               –	$	$               –
		12,071		12,701
	Interest rate swaps	5,768	–	5,768	–
	Total	$	$               –	17,839	$               –
		17,839
	As of December 31, 2012:
	Assets – Commodity contracts	$	$               –	$	$               –
		94,865		94,865
	Liabilities – Interest rate swaps	$	$               –	$	$               –
		8,255		8,255
	Our derivatives consist of over–the–counter (“OTC”) 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 based on observable market data for similar instruments.  This observable data includes 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, 2013.
	Nonrecurring Basis
	In March 2012 and August 2012, in conjunction with the sale of assets held for sale at December 31, 2011, we incurred $0.5 million of additional impairment charges to write down these assets to their fair value of $6.0 million.  The impairment charge was included in earnings for the nine months ended September 30, 2012.  The fair value was determined using Level 2 inputs consisting of the mutually agreed upon selling price we received upon the sale of these oil and natural gas properties.
	In June 2012, oil and natural gas properties with a carrying amount of $29.3 million were written down to their fair value of $13.1 million, resulting in an impairment charge of $16.2 million.  The impairment charge was included in earnings for the nine months ended September 30, 2012.  Significant Level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis included estimates of future oil and natural gas prices, production costs, development expenditures, anticipated production of proved reserves, appropriate risk–adjusted discount rates and other relevant data.
	Leasehold Impairments
	We incurred leasehold impairment charges of $0.1 million and $0.9 million in the three months ended September 30, 2013 and 2012, respectively, and $8.1 million and $1.1 million in the nine months ended September 30, 2013 and 2012, respectively.
	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.  As of September 30, 2013 and December 31, 2012, the estimated fair value of our senior notes due 2019 was $501.3 million and $531.2 million, respectively, which differs from the carrying value of $499.3 million and $499.2 million, respectively.  The 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, 2013
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:
		2013	2012
	Balance as of January 1	$	$
		104,684	93,225
	Liabilities incurred	727	4,902
	Accretion expense	3,744	3,763
	Revisions in estimated cash flows	-6,961	6,893
	Settlements and divestitures	-910	-846
	Balance as of September  30	$	$
		101,284	107,937
	As of both September 30, 2013 and December 31, 2012, $2.0 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	9 Months Ended
	Sep. 30, 2013
LONG-TERM DEBT [Abstract]	'
LONG-TERM DEBT	'
	NOTE 7. LONG–TERM DEBT
	Credit Facility
	As of September 30, 2013, we have a $1.0 billion credit facility that expires in April 2016.  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 of no greater than 3.5 to 1.0.  As of September 30, 2013, we were in compliance with these financial covenants.
	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 3.1% at September 30, 2013).
	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, 2013, the borrowing base under the facility was $710.0 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.
	We had $585.0 million and $360.0 million outstanding under the facility at September 30, 2013 and December 31, 2012, 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 the Parent nor Finance has independent assets or operations apart from the assets and operations of its subsidiaries.
	The aggregate carrying amount of our senior notes due 2019 was $499.3 million and $499.2 million at September 30, 2013 and December 31, 2012, respectively.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2013
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, 2013 or December 31, 2012.

OWNERS_EQUITY

OWNERS' EQUITY	9 Months Ended
	Sep. 30, 2013
OWNERS' EQUITY [Abstract]	'
OWNERS' EQUITY	'
	NOTE 9. OWNERS’ EQUITY
	Units Outstanding
	At September 30, 2013, owners’ equity consists of 42,599,080 common units, representing a 98% limited partnership interest in us, and a 2% general partnership interest.
	Issuance of Units
	In January 2013, we issued 0.3 million common units related to the vesting of equity–based awards.  Of this amount, 0.04 million were phantom units accounted for as liability awards, and these phantom units vested at a fair value of $2.4 million.  In conjunction with the vesting of these units, we received a contribution of $0.3 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, 2013:
			Distribution per Unit	Total Distribution
	Date Paid	Period Covered
	14-Feb-13	October 1, 2012 – December 31, 2012	$	$
			0.767	33,838
	15-May-13	January 1, 2013 – March 31, 2013	0.768	33,883
	14-Aug-13	April 1, 2013 – June 30, 2013	0.769	33,925
				$
				101,646
	On October 28, 2013, the board of directors of EV Management declared a $0.77 per unit distribution for the third quarter of 2013 on all common units.  The distribution of $38.5 million is to be paid on November 14, 2013 to unitholders of record at the close of business on November 7, 2013.

NET_LOSS_PER_LIMITED_PARTNER_U

NET LOSS PER LIMITED PARTNER UNIT	9 Months Ended
	Sep. 30, 2013
NET LOSS PER LIMITED PARTNER UNIT [Abstract]	'
NET LOSS PER LIMITED PARTNER UNIT	'
	NOTE 10. NET LOSS PER LIMITED PARTNER UNIT
	The following sets forth the calculation of net loss per limited partner unit:
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2013	2012	2013	2012
	Net loss	$	$    (50,019)       (50,019)	$	$
		-12,314		-26,041	-6,470
	General partners’ 2% interest in net loss	246	1,000	521	129
	Net loss attributable to participating
	securities	-497	–	-1,498	–
	Limited partners’ interest in net loss	$	$	$	$
		-12,565	-49,019	-27,018	-6,341
	Weighted average limited partner units outstanding:
	Common units	42,599	38,447	42,578	37,775
	Class B units	–	3,873	–	3,873
	Performance units	–	132	–	136
	Denominator for basic net loss per
	limited partner unit	42,599	42,452	42,578	41,784
	Dilutive units (1)	–	–	–	–
	Denominator for diluted net loss per
	limited partner unit	42,599	42,452	42,578	41,784
	Net loss per limited partner unit:
	Basic	$	$	$	$
		-0.29	-1.15	-0.63	-0.15
	Diluted	$	$	$	$
		-0.29	-1.15	-0.63	-0.15
	_____________
	(1)Units totaling 0.2 million and 0.6 million were not included in the computation of diluted net loss per limited partner unit for the three months and nine months ended September 30, 2013 and three months and nine months ended September 30, 2012, respectively, because the effect would have been anti–dilutive.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2013
RELATED PARTY TRANSACTIONS [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	NOTE 11. RELATED PARTY TRANSACTIONS
	Pursuant to an omnibus agreement, we paid EnerVest $2.5 million and $3.2 million in the three months ended September 30, 2013 and 2012, respectively, and $7.5 million and $9.8 million in the nine months ended September 30, 2013 and 2012, 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 $4.2 million and $4.0 million in the three months ended September 30, 2013 and 2012, respectively, and $12.0 million and $12.1 million in the nine months ended September 30, 2013 and 2012, 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, 2013
OTHER SUPPLEMENTAL INFORMATION [Abstract]	'
OTHER SUPPLEMENTAL INFORMATION	'
	NOTE 12. OTHER SUPPLEMENTAL INFORMATION
	Supplemental cash flows and noncash transactions were as follows:
		Nine Months Ended
		September 30,
		2013	2012
	Supplemental cash flows information:
	Cash paid for interest, net of capitalized interest of $4,970 and $–, respectively	$	$
		24,347	26,778
	Cash paid for income taxes	325	340
		As of September 30,
		2013	2012
	Noncash transaction – costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$	$
		16,636	7,153
	Accounts payable and accrued liabilities consisted of the following:
	March
		September 30,	December 31,
		2013	2012
	Costs for additions to oil and natural gas properties	$	$
		16,636	13,951
	Lease operating expenses	9,254	7,309
	Interest	18,831	8,566
	Production and ad valorem taxes	6,011	4,379
	General and administrative expenses	2,069	2,596
	Current portion of ARO	1,977	1,977
	Deposit on sale of oil and natural gas properties	2,079	–
	Derivative settlements	2,494	364
	Other	1,394	1,029
	Total	$	$
		60,745	40,171

NEW_ACCOUNTING_STANDARDS

NEW ACCOUNTING STANDARDS	9 Months Ended
	Sep. 30, 2013
NEW ACCOUNTING STANDARDS [Abstract]	'
NEW ACCOUNTING STANDARDS	'
	NOTE 13. NEW ACCOUNTING STANDARDS
	In December 2011, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) No. 2011–11, Disclosures about Offsetting Assets and Liabilities.  This ASU affects all entities that have financial instruments and derivative instruments that are either offset or subject to an enforceable master netting arrangement or similar agreement.  ASU 2011–11 requires an entity to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position.  In January 2013, the FASB issued ASU 2013–01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, to clarify the scope of ASU 2011–11.  The provisions of both ASU 2011–11 and ASU 2013–01 are applicable to annual reporting periods beginning on or after January 1, 2013 and interim periods within those annual periods.  We adopted ASU 2011–11 and 2013–01 on January 1, 2013, and the adoption did not impact our operating results, financial position or cash flows, but did impact our disclosures on offsetting arrangements (see Note 4).
	No other new accounting pronouncements issued or effective during the nine months ended September 30, 2013 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, 2013
SUBSEQUENT EVENTS [Abstract]	'
SUBSEQUENT EVENTs	'
	NOTE 14. SUBSEQUENT EVENTS
	In August 2013, we, along with certain institutional partnerships managed by EnerVest, signed an agreement to divest certain Utica shale acreage in Ohio for $56 million, net to us, subject to customary purchase price adjustments.  In October 2013, we closed on the sale of $41.2 million of these acres, and we expect additional closings on the remaining acreage prior to year end.
	In October 2013, we closed a public offering of 5.75 million common units at an offering price of $36.86 per common unit.  We received proceeds of $208.7 million, including a contribution of $4.2 million by our general partner to maintain its 2% interest in us, and we expect to incur offering expenses of approximately $0.3 million.  We used the proceeds to repay indebtedness outstanding under our credit facility.  As of October 31, 2013, we had $442.0 million outstanding under our credit facility.
	In October 2013, the borrowing base under the facility was increased to $730.0 million.
	In November 2013, we, along with certain institutional partnerships managed by EnerVest, acquired natural gas properties in the Barnett Shale.  We acquired a 31% proportional interest in these assets for $58.6 million, subject to customary purchase price adjustments.

ORGANIZATION_AND_NATURE_OF_BUS1

ORGANIZATION AND NATURE OF BUSINESS (Policy)	9 Months Ended
	Sep. 30, 2013
ORGANIZATION AND NATURE OF BUSINESS [Abstract]	'
Nature of Operations	'
	Nature of Operations
	EV Energy Partners, L.P. (the “Parent”) and its wholly owned subsidiaries (“we,” “our” or “us”) are a publicly held limited partnership that engages in the acquisition, development and production of oil and natural gas properties.  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.
	We operate in one reportable segment engaged in the exploration, 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, 2012.
	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_Table

EQUITY-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2013
EQUITY-BASED COMPENSATION [Abstract]	'
Compensation Costs Recognized in Unaudited Condensed Consolidated Statements of Operations	'
	The following table presents the compensation costs recognized in our unaudited condensed consolidated statements of operations:
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2013	2012	2013	2012
	Liability awards	$              –	$	$	$
			836	182	2,016
	Equity awards	4,297	3,458	12,898	10,374
	Total	$	$	$	$
		4,297	4,294	13,080	12,390

RISK_MANAGEMENT_Tables

RISK MANAGEMENT (Tables)	9 Months Ended
	Sep. 30, 2013
RISK MANAGEMENT [Abstract]	'
Commodity Contracts	'
	As of September 30, 2013, we had entered into commodity contracts with the following terms:
	Period Covered	Hedged Volume	Weighted Average Fixed Price
	Oil (MBbls):
	Swaps – October 2013 to December 2013	379.5	$
			88.94
	Swaps – 2014	1,517.7	91.19
	Swaps – 2015	730.0	90.09
	Natural Gas (MmmBtus):
	Swaps – October 2013 to December 2013	9,319.6	4.93
	Swaps – 2014	31,609.0	4.88
	Swaps – 2015	31,572.5	5.07
Interest Rate Swaps	'
	As of September 30, 2013, we had entered into interest rate swaps with the following terms:
		Notional	Floating	Fixed
	Period Covered	Amount	Rate	Rate
	October 2013 – 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 Sheets	Balance Sheets
	Derivatives:
	As of September 30, 2013:
	Derivative asset	$	$	$
		37,913	-15,106	22,807
	Long–term derivative asset	40,374	-2,694	37,680
	Total	$	$	$
		78,287	-17,800	60,487
	As of December 31, 2012:
	Derivative asset	$	$	$
		44,173	-3,402	40,771
	Long–term derivative asset	50,692	-4,853	45,839
	Total	$	$	$
		94,865	-8,255	86,610
				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 Sheets	Balance Sheets
	Derivatives:
	As of September 30, 2013:
	Derivative liability	$	$	$
		15,145	-15,106	39
	Long–term derivative liability	2,694	-2,694	–
	Total	$	$	$
		17,839	-17,800	39
	As of December 31, 2012:
	Derivative liability	$	$	$                   –
		3,402	-3,402
	Long–term derivative liability	4,853	-4,853	–
	Total	$	$	$                   –
		8,255	-8,255
Impact of Derivatives and their Location Within Consolidated Statements of Operations	'
	The following table presents the impact of derivatives and their location within the unaudited condensed consolidated statements of operations:
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2013	2012	2013	2012
	Realized gains on derivatives, net:
	Commodity contracts	$	$	$	$
		6,231	31,571	24,351	92,523
	Interest rate swaps	-1,353	-1,736	-4,253	-3,895
	Total	$	$	$	$
		4,878	29,835	20,098	88,628
	Unrealized losses on derivatives, net:
	Commodity contracts	$	$	$	$
		-17,577	-66,783	-28,654	-40,321
	Interest rate swaps	1,052	913	4,142	1,649
	Total	$	$	$	$
		-16,525	-65,870	-24,512	-38,672

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2013
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
					significantUnobservable
			Identical	Observable	Unobservable
			Assets	Inputs	Inputs
		Fair Value	(Level 1)	(Level 2)	(Level 3)
	As of September 30, 2013:
	Assets – Commodity contracts	$	$               –	$	$               –
		78,287		78,287
	Liabilities:
	Commodity contracts	$	$               –	$	$               –
		12,071		12,701
	Interest rate swaps	5,768	–	5,768	–
	Total	$	$               –	17,839	$               –
		17,839
	As of December 31, 2012:
	Assets – Commodity contracts	$	$               –	$	$               –
		94,865		94,865
	Liabilities – Interest rate swaps	$	$               –	$	$               –
		8,255		8,255

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2013
ASSET RETIREMENT OBLIGATIONS [Abstract]	'
Changes in Aggregate Asset Retirement Obligation	'
	The changes in the aggregate ARO are as follows:
		2013	2012
	Balance as of January 1	$	$
		104,684	93,225
	Liabilities incurred	727	4,902
	Accretion expense	3,744	3,763
	Revisions in estimated cash flows	-6,961	6,893
	Settlements and divestitures	-910	-846
	Balance as of September  30	$	$
		101,284	107,937

OWNERS_EQUITY_Tables

OWNERS EQUITY (Tables)	9 Months Ended
	Sep. 30, 2013
OWNERS' EQUITY [Abstract]	'
Schedule of Cash Distributions	'
	The following sets forth the distributions we paid during the nine months ended September 30, 2013:
			Distribution per Unit	Total Distribution
	Date Paid	Period Covered
	14-Feb-13	October 1, 2012 – December 31, 2012	$	$
			0.767	33,838
	15-May-13	January 1, 2013 – March 31, 2013	0.768	33,883
	14-Aug-13	April 1, 2013 – June 30, 2013	0.769	33,925
				$
				101,646

NET_LOSS_PER_LIMITED_PARTNER_U1

NET LOSS PER LIMITED PARTNER UNIT (Tables)	9 Months Ended
	Sep. 30, 2013
NET LOSS PER LIMITED PARTNER UNIT [Abstract]	'
Calculation of Net Income Per Limited Partner Unit	'
	The following sets forth the calculation of net loss per limited partner unit:
		Three Months Ended		Nine Months Ended
		September 30,		September 30,
		2013	2012	2013	2012
	Net loss	$	$    (50,019)       (50,019)	$	$
		-12,314		-26,041	-6,470
	General partners’ 2% interest in net loss	246	1,000	521	129
	Net loss attributable to participating
	securities	-497	–	-1,498	–
	Limited partners’ interest in net loss	$	$	$	$
		-12,565	-49,019	-27,018	-6,341
	Weighted average limited partner units outstanding:
	Common units	42,599	38,447	42,578	37,775
	Class B units	–	3,873	–	3,873
	Performance units	–	132	–	136
	Denominator for basic net loss per
	limited partner unit	42,599	42,452	42,578	41,784
	Dilutive units (1)	–	–	–	–
	Denominator for diluted net loss per
	limited partner unit	42,599	42,452	42,578	41,784
	Net loss per limited partner unit:
	Basic	$	$	$	$
		-0.29	-1.15	-0.63	-0.15
	Diluted	$	$	$	$
		-0.29	-1.15	-0.63	-0.15
	_____________
	(1)Units totaling 0.2 million and 0.6 million were not included in the computation of diluted net loss per limited partner unit for the three months and nine months ended September 30, 2013 and three months and nine months ended September 30, 2012, respectively, because the effect would have been anti–dilutive.

OTHER_SUPPLEMENTAL_INFORMATION1

OTHER SUPPLEMENTAL INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2013
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,
		2013	2012
	Supplemental cash flows information:
	Cash paid for interest, net of capitalized interest of $4,970 and $–, respectively	$	$
		24,347	26,778
	Cash paid for income taxes	325	340
		As of September 30,
		2013	2012
	Noncash transaction – costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	$	$
		16,636	7,153
Schedule of Accounts Payable and Accrued Liabilities- Third Party	'
	Accounts payable and accrued liabilities consisted of the following:
	March
		September 30,	December 31,
		2013	2012
	Costs for additions to oil and natural gas properties	$	$
		16,636	13,951
	Lease operating expenses	9,254	7,309
	Interest	18,831	8,566
	Production and ad valorem taxes	6,011	4,379
	General and administrative expenses	2,069	2,596
	Current portion of ARO	1,977	1,977
	Deposit on sale of oil and natural gas properties	2,079	–
	Derivative settlements	2,494	364
	Other	1,394	1,029
	Total	$	$
		60,745	40,171

ORGANIZATION_AND_NATURE_OF_BUS2

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	1 Months Ended	9 Months Ended
	Oct. 31, 2013	Sep. 30, 2013
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]	'	'
Percentage of general partnership interest	2.00%	2.00%
EnerVest, Ltd. [Member]	'	'
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%
Percentage of general partnership interest	'	2.00%

EQUITYBASED_COMPENSATION_Detai

EQUITY-BASED COMPENSATION (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity-based compensation cost	$4,297,000	$4,294,000	$13,080,000	$12,390,000
Unrecognized compensation expense	31,000,000	'	31,000,000	'
Weighted average period	'	'	'2 years 3 months 18 days	'
Liability Awards [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity-based compensation cost	'	836,000	182,000	2,016,000
Equity Awards [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity-based compensation cost	$4,297,000	$3,458,000	$12,898,000	$10,374,000

INVESTMENTS_IN_UNCONSOLIDATED_1

INVESTMENTS IN UNCONSOLIDATED AFFILIATES (Details)	Sep. 30, 2013
Cardinal Gas Services, LLC [Member]	'
Schedule of Equity Method Investments [Line Items]	'
Equity investment, ownership percentage	9.00%
Utica East Ohio Midstream LLC [Member]	'
Schedule of Equity Method Investments [Line Items]	'
Equity investment, ownership percentage	21.00%

RISK_MANAGEMENT_Commodity_Cont

RISK MANAGEMENT (Commodity Contracts) (Details)	Sep. 30, 2013
	MMBbls
Oil [Member] | Swaps - October 2013 to December 2013 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MBbls)	379.5
Weighted Average Fixed Price	88.94
Oil [Member] | Swaps - 2014 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MBbls)	1,517.70
Weighted Average Fixed Price	91.19
Oil [Member] | Swaps - 2015 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MBbls)	730
Weighted Average Fixed Price	90.09
Natural Gas [Member] | Swaps - October 2013 to December 2013 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MmBtus)	9,319.60
Weighted Average Fixed Price	4.93
Natural Gas [Member] | Swaps - 2014 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MmBtus)	31,609
Weighted Average Fixed Price	4.88
Natural Gas [Member] | Swaps - 2015 [Member]	'
Derivative Instruments Related to Oil and Gas Production [Line Items]	'
Hedged Volume (MmBtus)	31,572.50
Weighted Average Fixed Price	5.07

RISK_MANAGEMENT_Interest_Rate_

RISK MANAGEMENT (Interest Rate Swaps) (Details) (Interest Rate Swaps Covering October 2013 - July 2015 [Member], USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Interest Rate Swaps Covering October 2013 - 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 $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivative Assets:	'	'
Derivative asset, fair value	$78,287	$94,865
Derivative asset, liability	-17,800	-8,255
Derivative asset	22,807	40,771
Long-term derivative asset	37,680	45,839
Net recorded fair value	60,487	86,610
Derivative Liabilities:	'	'
Derivative liability, fair value	17,839	8,255
Derivative liability, asset	-17,800	-8,255
Derivative liability	39	'
Net recorded fair value	39	'
Commodity Contracts [Member]	'	'
Derivative Assets:	'	'
Derivative asset, fair value	78,287	'
Derivative Liabilities:	'	'
Derivative liability, fair value	12,071	'
Interest Rate Swaps [Member]	'	'
Derivative Liabilities:	'	'
Derivative liability, fair value	5,768	'
Derivative Asset [Member]	'	'
Derivative Assets:	'	'
Derivative asset, fair value	37,913	44,173
Derivative asset, liability	-15,106	-3,402
Long-term Derivative Asset [Member]	'	'
Derivative Assets:	'	'
Derivative asset, fair value	40,374	50,692
Derivative asset, liability	-2,694	-4,853
Derivative Liability [Member]	'	'
Derivative Liabilities:	'	'
Derivative liability, fair value	15,145	3,402
Derivative liability, asset	-15,106	-3,402
Long-term Derivative Liability [Member]	'	'
Derivative Liabilities:	'	'
Derivative liability, fair value	2,694	4,853
Derivative liability, asset	($2,694)	($4,853)

RISK_MANAGEMENT_Impact_of_Deri

RISK MANAGEMENT (Impact of Derivatives and their Location Within Consolidated Statements of Operations) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Realized gains on derivatives, net	$4,878	$29,835	$20,098	$88,628
Unrealized losses on derivatives, net	-16,525	-65,870	-24,512	-38,672
Commodity Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Realized gains on derivatives, net	6,231	31,571	24,351	92,523
Unrealized losses on derivatives, net	-17,577	-66,783	-28,654	-40,321
Interest Rate Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Realized gains on derivatives, net	-1,353	-1,736	-4,253	-3,895
Unrealized losses on derivatives, net	$1,052	$913	$4,142	$1,649

FAIR_VALUE_MEASUREMENTS_Narrat

FAIR VALUE MEASUREMENTS (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended	9 Months Ended					9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Aug. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Jun. 30, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012
							8.0% Senior Notes due 2019 [Member]	8.0% Senior Notes due 2019 [Member]	Nonrecurring Basis [Member]
Fair Value Measurements [Line Items]	'	'	'	'	'	'	'	'	'
Asset held for sale, impairment charges	'	'	$500,000	'	'	'	'	'	'
Asset held for sale, fair value nonrecurring basis	6,000,000	'	'	6,000,000	'	'	'	'	'
Oil and natural gas properties, carrying amount	'	'	'	'	'	29,300,000	'	'	'
Impairment of oil and natural gas properties	143,000	853,000	'	8,141,000	17,752,000	'	'	'	16,200,000
Oil and natural gas properties , fair value	'	'	'	'	'	13,100,000	'	'	'
Impairment of oil and natural gas properties, leaseholds	100,000	900,000	'	8,100,000	1,100,000	'	'	'	'
Senior notes, fair value	'	'	'	'	'	'	501,300,000	531,200,000	'
Senior notes, carrying value	'	'	'	'	'	'	$499,300,000	$499,200,000	'
Senior notes, maturity year	'	'	'	'	'	'	'2019	'2019	'

FAIR_VALUE_MEASUREMENTS_Fair_V

FAIR VALUE MEASUREMENTS (Fair Value Hierarchy for Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	$78,287	$94,865
Derivative liability, fair value	17,839	8,255
Commodity Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	78,287	'
Derivative liability, fair value	12,071	'
Interest Rate Swaps [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative liability, fair value	5,768	'
Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	'	'
Derivative liability, fair value	'	'
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	'	'
Derivative liability, 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]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	'	94,865
Derivative liability, fair value	17,839	8,255
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	78,287	'
Derivative liability, fair value	12,701	'
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	5,768	'
Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	'	'
Derivative liability, fair value	'	'
Significant Unobservable Inputs (Level 3) [Member] | Commodity Contracts [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'	'
Derivative asset, fair value	'	'
Derivative liability, 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	'	'

ASSET_RETIREMENT_OBLIGATIONS_D

ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
ASSET RETIREMENT OBLIGATIONS [Abstract]	'	'	'	'	'
Balance at beginning of period	'	'	$104,684	$93,225	'
Liabilities incurred	'	'	727	4,902	'
Accretion expense	1,185	1,335	3,744	3,763	'
Revisions in estimated cash flows	'	'	-6,961	6,893	'
Settlements and divestitures	'	'	-910	-846	'
Balance at end of period	101,284	107,937	101,284	107,937	'
Asset retirement obligation, current	$1,977	'	$1,977	'	$1,977

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Oct. 31, 2013
	item		8.0% Senior Notes due 2019 [Member]	8.0% Senior Notes due 2019 [Member]	Borrowing Base Determination, Period One [Member]	Borrowing Base Determination, Period Two [Member]	Letter of Credit [Member]	Subsequent Event [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'
Senior secured credit facility, maximum borrowing capacity	$1,000	'	'	'	'	'	$100	$730
Senior secured credit facility, expiration date	'2016-04	'	'	'	'	'	'	'
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	3.10%	'	'	'	'	'	'	'
Line of credit, borrowing base	710	'	'	'	'	'	'	'
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.	'	'	'	'	'	'	'
Borrowing base scheduled redetermination date	'	'	'	'	'--04-01	'--10-01	'	'
Line of credit facility amount outstanding	585	360	'	'	'	'	'	442
Senior notes, maturity year	'	'	'2019	'2019	'	'	'	'
Senior notes, carrying amount	'	'	$499.30	$499.20	'	'	'	'

OWNERS_EQUITY_Narrative_Detail

OWNERS' EQUITY (Narrative) (Details) (USD $)	1 Months Ended		3 Months Ended		9 Months Ended			0 Months Ended		1 Months Ended	3 Months Ended
	Oct. 31, 2013	Jan. 31, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Oct. 28, 2013	Sep. 30, 2013	Jan. 31, 2013	Mar. 31, 2013
								Dividend Declared [Member]	Common Unitholders [Member]	Phantom Units [Member]	Phantom Units [Member]
Stockholders Equity Note [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Common units outstanding	'	'	42,599,080	'	42,599,080	'	42,320,707	'	42,599,080	'	'
Percentage of limited partnership interest	'	'	'	'	98.00%	'	'	'	'	'	'
Percentage of general partnership interest	2.00%	'	'	'	2.00%	'	'	'	'	'	'
Units vested	'	300,000	'	'	'	'	'	'	'	40,000	'
Units vested, fair value	'	'	'	'	'	'	'	'	'	'	$2,400,000
Contribution from general partner	'	300,000	'	'	334,000	5,714,000	'	'	'	'	'
Distribution to unitholders declared per unit	'	'	$0.77	$0.77	$2.31	$2.29	'	$0.77	'	'	'
Distribution to unitholders, amount	'	'	'	'	'	'	'	$38,500,000	'	'	'
Distribution to unitholders, record date	'	'	'	'	'	'	'	7-Nov-13	'	'	'
Distribution to unitholders, payment date	'	'	'	'	'	'	'	14-Nov-13	'	'	'

OWNERS_EQUITY_Cash_Distributio

OWNERS EQUITY (Cash Distributions) (Details) (USD $)	9 Months Ended	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Mar. 31, 2013	Jun. 30, 2013
		October 1, 2012 - December 31, 2012 [Member]	January 1, 2013 - March 31, 2013 [Member]	April 1, 2012 - June 30, 2012 [Member]
Date Paid	'	14-Feb-13	15-May-13	14-Aug-13
Distribution per Unit	'	$0.77	$0.77	$0.77
Total Distribution	$101,646	$33,838	$33,883	$33,925

NET_LOSS_PER_LIMITED_PARTNER_U2

NET LOSS PER LIMITED PARTNER UNIT (Details) (USD $)	1 Months Ended	3 Months Ended				9 Months Ended
In Thousands, except Share data, unless otherwise specified	Oct. 31, 2013	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Earnings Per Share Disclosure [Line Items]	'	'		'		'		'
Net loss	'	($12,314)		($50,019)		($26,041)		($6,470)
Net loss attributable to participating securities	'	-497		'		-1,498		'
Limited partners' interest in net loss	'	-12,565		-49,019		-27,018		-6,341
Percentage of general partnership interest	2.00%	'		'		2.00%		'
Weighted average limited partner units outstanding:	'	'		'		'		'
Denominator for basic net loss per limited partner unit	'	42,599,000		42,452,000		42,578,000		41,784,000
Dilutive units	'	'	[1]	'	[1]	'	[1]	'	[1]
Total	'	42,599,000		42,452,000		42,578,000		41,784,000
Net loss per limited partner unit:	'	'		'		'		'
Basic	'	($0.29)		($1.15)		($0.63)		($0.15)
Diluted	'	($0.29)		($1.15)		($0.63)		($0.15)
Equity awards not included in computation of diluted net income (loss) per limited partner unit	'	'		600,000		200,000		600,000
General Partner Interests [Member]	'	'		'		'		'
Earnings Per Share Disclosure [Line Items]	'	'		'		'		'
General partners 2% interest in net loss	'	246		1,000		521		129
Common units [Member]	'	'		'		'		'
Weighted average limited partner units outstanding:	'	'		'		'		'
Denominator for basic net loss per limited partner unit	'	42,599,000		38,447,000		42,578,000		37,775,000
Class B Unitholders [Member]	'	'		'		'		'
Earnings Per Share Disclosure [Line Items]	'	'		'		'		'
Net loss	'	'		'		'		($468)
Weighted average limited partner units outstanding:	'	'		'		'		'
Denominator for basic net loss per limited partner unit	'	'		3,873,000		'		3,873,000
Performance Units [Member]	'	'		'		'		'
Weighted average limited partner units outstanding:	'	'		'		'		'
Denominator for basic net loss per limited partner unit	'	'		132,000		'		136,000
[1]	Units totaling 0.2 million and 0.6 million were not included in the computation of diluted net loss per limited partner unit for the three months and nine months ended September 30, 2013 and three months and nine months ended September 30, 2012, respectively, because the effect would have been anti-dilutive.

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (EnerVest, Ltd. [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
EnerVest, Ltd. [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Administrative fees paid to related party	$2.50	$3.20	$7.50	$9.80
Direct expenses incurred and reimbursed to related party	$4.20	$4	$12	$12.10

OTHER_SUPPLEMENTAL_INFORMATION2

OTHER SUPPLEMENTAL INFORMATION (Supplemental Cash Flows and Non-Cash Transactions) (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Supplemental cash flows information:	'	'
Cash paid for interest	$24,347	$26,778
Cash paid for income taxes	325	340
Non-cash transactions:	'	'
Costs for additions to oil and natural gas properties in accounts payable and accrued liabilities	16,636	7,153
Capitalized interest	$4,970	'

OTHER_SUPPLEMENTAL_INFORMATION3

OTHER SUPPLEMENTAL INFORMATION (Schedule of Accounts Payable and Accrued Liabilities- Third Party) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Other Supplemental Information Disclosure [Abstract]	'	'
Costs for additions to oil and natural gas properties	$16,636	$13,951
Lease operating expenses	9,254	7,309
Interest	18,831	8,566
Production and ad valorem taxes	6,011	4,379
General and administrative expenses	2,069	2,596
Current portion of ARO	1,977	1,977
Deposit on sale of oil and natural properties	2,079	'
Derivative settlements	2,494	364
Other	1,394	1,029
Total	$60,745	$40,171

SUBSEQUENT_EVENTS_Narrative_De

SUBSEQUENT EVENTS - (Narrative) (Details) (USD $)	1 Months Ended	9 Months Ended			1 Months Ended		0 Months Ended	1 Months Ended
Share data in Millions, except Per Share data, unless otherwise specified	Oct. 31, 2013	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Aug. 31, 2013	Oct. 31, 2013	Nov. 08, 2013	Oct. 31, 2013	Oct. 31, 2013
					Land [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	General Partner Interests [Member]
					Guemsey, Harrison and Noble Counties [Member]		Barnett Shale [Member]	Land [Member]	Subsequent Event [Member]
								Guemsey, Harrison and Noble Counties [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'	'
Land sales	'	'	'	'	$56,000,000	'	'	$41,200,000	'
Common units issued in public offering	'	'	'	'	'	5.75	'	'	'
Shares issued, price per share	'	'	'	'	'	$36.86	'	'	'
Proceeds from public equity offering	'	'	262,529,000	'	'	208,700,000	'	'	'
Contributions from general partner	'	334,000	5,714,000	'	'	'	'	'	4,200,000
Percentage of general partnership interest	2.00%	2.00%	'	'	'	'	'	'	'
Oil and natural gas properties acquired interest, percentage	'	'	'	'	'	'	31.00%	'	'
Acquisition of natural gas property	'	'	118,925,000	'	'	'	58,600,000	'	'
Senior secured credit facility, maximum borrowing capacity	'	1,000,000,000	'	'	'	730,000,000	'	'	'
Expected issuance costs	'	'	'	'	'	300,000	'	'	'
Line of credit facility amount outstanding	'	$585,000,000	'	$360,000,000	'	$442,000,000	'	'	'