LRR Energy 10-Q 6 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014
		Common Units [Member]	Subordinated Units Affiliated [Member]	General Partner Units [Member]
Entity Registrant Name	'LRR Energy, L.P.	'	'	'
Entity Central Index Key	'0001519632	'	'	'
Document Type	'10-Q	'	'	'
Document Period End Date	30-Jun-14	'	'	'
Amendment Flag	'false	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'
Entity Current Reporting Status	'Yes	'	'	'
Entity Filer Category	'Accelerated Filer	'	'	'
Entity Common Stock, Shares Outstanding	'	22,969,599	4,480,000	22,400
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q2	'	'	'

Consolidated_Condensed_Balance

Consolidated Condensed Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$2,871	$4,417
Accounts receivable	9,792	9,867
Commodity derivative instruments	8,022	9,726
Due from affiliates	5,737	'
Prepaid expenses	1,717	1,603
Total current assets	28,139	25,613
Property and equipment (successful efforts method)	895,352	876,674
Accumulated depletion, depreciation and impairment	-449,054	-431,837
Total property and equipment, net	446,298	444,837
Commodity derivative instruments	5,569	16,746
Deferred financing costs, net of accumulated amortization	1,039	1,154
TOTAL ASSETS	481,045	488,350
Current liabilities:	'	'
Accrued liabilities	4,797	2,300
Accrued capital cost	4,115	2,574
Due to affiliates	'	255
Commodity derivative instruments	5,783	2,217
Interest rate derivative instruments	1,304	648
Asset retirement obligations	503	488
Total current liabilities	16,502	8,482
Long-term liabilities:	'	'
Commodity derivative instruments	3,643	174
Interest rate derivative instruments	1,915	1,554
Term loan	50,000	50,000
Revolving credit facility	195,000	200,000
Asset retirement obligations	36,933	35,838
Deferred tax liabilities	83	44
Total long-term liabilities	287,574	287,610
Total liabilities	304,076	296,092
Unitholders' equity:	'	'
General partner (22,400 units issued and outstanding as of June 30, 2014 and December 31, 2013)	277	303
Total unitholders' equity	176,969	192,258
TOTAL LIABILITIES AND UNITHOLDERS' EQUITY	481,045	488,350
Common Units Public [Member]	'	'
Unitholders' equity:	'	'
Limited partner	175,920	181,290
Common Units Affiliated [Member]	'	'
Unitholders' equity:	'	'
Limited partner	216	2,093
Subordinated Units Affiliated [Member]	'	'
Unitholders' equity:	'	'
Limited partner	$556	$8,572

Consolidated_Condensed_Balance1

Consolidated Condensed Balance Sheets (Parenthetical)	Jun. 30, 2014	Dec. 31, 2013
General partner, units issued (in units)	22,400	22,400
General partner, units outstanding (in units)	22,400	22,400
Common Units Public [Member]	'	'
Limited partner, units issued (in units)	18,584,790	17,710,334
Limited partner, units outstanding (in units)	18,584,790	17,710,334
Common Units Affiliated [Member]	'	'
Limited partner, units issued (in units)	4,089,600	1,849,600
Limited partner, units outstanding (in units)	4,089,600	1,849,600
Subordinated Units Affiliated [Member]	'	'
Limited partner, units issued (in units)	4,480,000	6,720,000
Limited partner, units outstanding (in units)	4,480,000	6,720,000

Consolidated_Condensed_Stateme

Consolidated Condensed Statements of Operations (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Oil sales	$20,354	$19,012	$40,510	$34,475
Natural gas sales	7,565	7,720	15,664	13,800
Natural gas liquids sales	2,760	2,275	6,124	4,510
Gain (loss) on commodity derivative instruments, net	-13,328	12,354	-18,950	6,287
Other income	40	18	71	87
Total revenues	17,391	41,379	43,419	59,159
Operating expenses:	'	'	'	'
Lease operating expense	6,829	5,270	12,664	12,067
Production and ad valorem taxes	2,248	2,198	4,648	4,044
Depletion and depreciation	8,680	10,129	17,145	20,239
Accretion expense	510	477	1,013	947
Loss (gain) on settlement of asset retirement obligations	21	360	61	335
General and administrative expense	2,699	2,768	5,881	6,197
Total operating expenses	20,987	21,202	41,412	43,829
Operating income (loss)	-3,596	20,177	2,007	15,330
Other income (expense), net	'	'	'	'
Interest expense	-2,575	-2,249	-5,116	-4,514
Gain (loss) on interest rate derivative instruments, net	-1,128	2,657	-1,422	2,772
Other income (expense), net	-3,703	408	-6,538	-1,742
Income (loss) before taxes	-7,299	20,585	-4,531	13,588
Income tax expense	-38	-62	-112	-67
Net income (loss)	-7,337	20,523	-4,643	13,521
Net income attributable to predecessor operations	'	'	'	-448
Net income (loss) available to unitholders	-7,337	20,523	-4,643	13,073
Computation of net income (loss) per limited partner unit:	'	'	'	'
General partners' interest in net income (loss)	-7	21	-4	13
Limited partners' interest in net income (loss)	($7,330)	$20,502	($4,639)	$13,060
Net income (loss) per limited partner unit (basic and diluted) (in dollars per unit)	($0.27)	$0.78	($0.17)	$0.53
Weighted average number of limited partner units outstanding (in units)	26,733	26,169	26,539	24,555

Consolidated_Condensed_Stateme1

Consolidated Condensed Statement of Changes in Unitholders' Equity (USD $)	General Partner [Member]	Limited Partner [Member]	Limited Partner [Member]	Limited Partner [Member]	Total
In Thousands, unless otherwise specified		Common Units Public [Member]	Common Units Affiliated [Member]	Subordinated Units Affiliated [Member]
Balance at Dec. 31, 2013	$303	$181,290	$2,093	$8,572	$192,258
Increase (Decrease) in Unitholders' Equity	'	'	'	'	'
Equity offering, net of expenses	'	14,810	'	'	14,810
Amortization of equity awards	'	534	'	'	534
Conversion of subordinated units	'	'	623	-623	'
Distribution	-22	-17,548	-1,832	-6,588	-25,990
Net income	-4	-3,166	-668	-805	-4,643
Balance at Jun. 30, 2014	$277	$175,920	$216	$556	$176,969

Consolidated_Condensed_Stateme2

Consolidated Condensed Statements of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
CASH FLOWS FROM OPERATING ACTIVITIES	'	'
Net income	($4,643)	$13,521
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depletion and depreciation	17,145	20,239
Accretion expense	1,013	947
Amortization of equity awards	534	253
Amortization of derivative contracts	330	508
Amortization of deferred financing costs and other	208	187
Loss (gain) on settlement of asset retirement obligations	61	335
Changes in operating assets and liabilities:	'	'
Change in receivables	75	-2,568
Change in prepaid expenses	-209	-279
Change in derivative assets and liabilities	20,605	-3,163
Change in amounts due to/from affiliates	-5,992	-5,446
Change in accrued liabilities and deferred tax liabilities	2,536	2,581
Net cash provided by operating activities	31,663	27,115
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Development of oil and natural gas properties	-17,094	-14,375
Disposition of oil and natural gas properties	65	'
Net cash used in investing activities	-17,029	-14,375
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Borrowings under revolving credit facility	20,000	38,000
Principal payments on revolving credit facility	-25,000	-24,000
Equity offering, net of expenses	14,810	59,513
Distributions	-25,990	-23,422
Distribution to Lime Rock Resources	'	-60,672
Contribution to Lime Rock Resources	'	-734
Net cash used in financing activities	-16,180	-11,315
NET INCREASE IN CASH AND CASH EQUIVALENTS	-1,546	1,425
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	4,417	3,467
CASH AND CASH EQUIVALENTS, END OF PERIOD	2,871	4,892
Property and equipment:	'	'
Change in accrued capital costs	1,735	4,662
Asset retirement obligations	($181)	($313)

Description_of_Business

Description of Business	6 Months Ended
	Jun. 30, 2014
Organization and Description of Business	'
Organization and Description of Business	'
	1.Organization and Description of Business
	LRR Energy, L.P. (“we,” “us,” “our,” or the “Partnership”) is a Delaware limited partnership formed in April 2011 by Lime Rock Management LP (“Lime Rock Management”), an affiliate of Lime Rock Resources A, L.P. (“LRR A”), Lime Rock Resources B, L.P. (“LRR B”) and Lime Rock Resources C, L.P. (“LRR C”), to operate, acquire, exploit and develop producing oil and natural gas properties in North America with long-lived, predictable production profiles. As used herein, references to “Fund I” refer collectively to LRR A, LRR B and LRR C; references to “Fund II” refer collectively to Lime Rock Resources II-A, L.P. and Lime Rock Resources II-C, L.P.; and references to “Fund III” refer collectively to Lime Rock Resources III-A, L.P. and Lime Rock Resources III-C, L.P. References to “Lime Rock Resources” refer collectively to Fund I, Fund II and Fund III.
	Our properties are located in the Permian Basin region in West Texas and Southeast New Mexico, the Mid-Continent region in Oklahoma and East Texas and the Gulf Coast region in Texas. We conduct our operations through our wholly owned subsidiary, LRE Operating, LLC (“OLLC”).
	We own 100% of LRE Finance Corporation (“LRE Finance”). LRE Finance was organized for the purpose of co-issuing our debt securities and has no material assets or liabilities other than as co-issuer of our debt securities, if and when issued. Its activities will be limited to co-issuing our debt securities and engaging in activities related thereto.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Summary of Significant Accounting Policies	'
Summary of Significant Accounting Policies	'
	2.Summary of Significant Accounting Policies
	Our accounting policies are set forth in the audited consolidated/combined financial statements in our Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Annual Report”) and are supplemented by the notes to these unaudited consolidated condensed financial statements. There have been no significant changes to these policies, and these unaudited consolidated condensed financial statements should be read in conjunction with the audited consolidated/combined financial statements and notes in our 2013 Annual Report.
	Basis of presentation
	These interim financial statements are unaudited and have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the audited consolidated/combined financial statements in our 2013 Annual Report. While the year-end condensed balance sheet data was derived from audited financial statements, this interim report does not include all disclosures required by GAAP for annual periods. These unaudited interim consolidated condensed financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for the periods presented.
	Certain reclassifications were made to the historical financial statements to conform to the 2014 presentation. The effects of the reclassification were not material to our unaudited interim consolidated condensed financial statements.
	Recent accounting pronouncements
	On May 28, 2014, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers.” ASU No. 2014-09 outlined a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The core principle of the revenue model is that an entity recognizes revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016 and early adoption is not permitted. We are still evaluating the impact of our adoption of ASU No. 2014-09.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2014
Acquisitions	'
Acquisitions	'
	3.Acquisitions
	Acquisition between Entities under Common Control
	On January 3, 2013, we completed an acquisition from Fund I of certain oil and natural gas properties located in the Mid-Continent region in Oklahoma for a purchase price of $21.0 million, subject to customary purchase price adjustments (the “January 2013 Acquisition”). In addition, as part of the January 2013 Acquisition, we acquired in the money commodity hedge contracts valued at approximately $1.7 million as of the closing of the January 2013 Acquisition. The January 2013 Acquisition was effective October 1, 2012. In June 2013, we paid $0.4 million in cash to Fund I related to post-closing adjustments to the purchase price. We funded the January 2013 Acquisition with borrowings under our revolving credit facility (Note 7).
	The following table presents the net assets conveyed by Fund I to us in the January 2013 Acquisition (in thousands):
	Property and equipment, net	$	23,998
	Oil and natural gas commodity hedge contracts	1,742
	Asset retirement obligations and other liabilities	(1,067		)
	Net assets	$	24,673
	On April 1, 2013, we completed an acquisition of certain oil and natural gas properties located in the Mid-Continent region in Oklahoma and crude oil hedges from Fund II for a purchase price of $38.2 million (the “April 2013 Acquisition”). As part of the April 2013 Acquisition, we acquired in the money crude oil hedges valued at approximately $0.4 million as of the closing of the April 2013 Acquisition. The April 2013 Acquisition was effective April 1, 2013. We funded the April 2013 Acquisition with proceeds from our equity offering (Note 10).
	The following table presents the net assets conveyed by Fund II to us in the April 2013 Acquisition (in thousands):
	Property and equipment, net	$	36,586
	Oil and natural gas commodity hedge contracts	386
	Asset retirement obligations and other liabilities	(990		)
	Net assets	$	35,982
	The net assets of the January 2013 Acquisition and April 2013 Acquisition were recorded using carryover book value of Fund I and Fund II, as the acquisitions were deemed transactions between entities under common control. Our historical financial statements were revised to include the results attributable to previous acquisitions from Fund I and Fund II as if we owned the properties for all periods presented in our consolidated condensed financial statements.

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Measurements	'
Fair Value Measurements	'
	4.Fair Value Measurements
	Our financial instruments, including cash and cash equivalents and accounts receivable, are carried at cost, which approximates fair value due to the short-term maturity of these instruments. All such financial instruments are considered Level 1 instruments. The carrying value of our senior secured revolving credit facility and term loan, including the current portion, approximates fair value, as interest rates are variable based on prevailing market rates and are therefore considered Level 1 instruments. Our financial and non-financial assets and liabilities that are measured on a recurring basis are measured and reported at fair value.
	Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP establishes a three-tier fair value hierarchy, which prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of fair value hierarchy are as follows:
	Level 1—Defined as inputs such as unadjusted quoted prices in active markets for identical assets or liabilities.
	Level 2—Defined as inputs other than quoted prices in active markets that are either directly or indirectly observable for the asset or liability.
	Level 3—Defined as unobservable inputs for use when little or no market data exists, requiring an entity to develop its own assumptions for the asset or liability.
	We utilize the most observable inputs available for the valuation technique used. The financial assets and liabilities are classified in their entirety based on the lowest level of input that is of significance to the fair value measurement. The following table describes, by level within the hierarchy, the fair value of our financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2014 and December 31, 2013 (in thousands).
		Level 1		Level 2		Level 3		Total
	June 30, 2014
	Assets:
	Commodity derivative instruments	$	—	$	13,591	$	—	$	13,591
	Liabilities:
	Commodity derivative instruments	—		9,426		—		9,426
	Interest rate derivative instruments	—		3,219		—		3,219
	December 31, 2013
	Assets:
	Commodity derivative instruments	$	—	$	26,472	$	—	$	26,472
	Liabilities:
	Commodity derivative instruments	—		2,391		—		2,391
	Interest rate derivative instruments	—		2,202		—		2,202
	All fair values reflected in the table above and on the consolidated condensed balance sheets have been adjusted for non-performance risk. The following methods and assumptions were used to estimate the fair values of the assets and liabilities in the table above.
	Commodity Derivative Instruments—The fair value of the commodity derivative instruments is estimated using a combined income and market valuation methodology based upon forward commodity price and volatility curves. The curves are obtained from independent pricing services reflecting broker market quotes.
	Interest Rate Derivative Instruments—The fair value of the interest rate derivative instruments is estimated using a combined income and market valuation methodology based upon forward interest rates and volatility curves. The curves are obtained from independent pricing services reflecting broker market quotes.

Property_and_Equipment

Property and Equipment	6 Months Ended
	Jun. 30, 2014
Property and Equipment	'
Property and Equipment	'
	5.Property and Equipment
	Property and equipment is stated at cost less accumulated depletion, depreciation and impairment and consisted of the following (in thousands):
		June 30, 2014			December 31, 2013
	Oil and natural gas properties (successful efforts method)	$	893,825		$	875,126
	Unproved properties	1,238			1,258
	Other property and equipment	289			290
		895,352			876,674
	Accumulated depletion, depreciation and impairment	(449,054		)	(431,837		)
	Total property and equipment, net	$	446,298		$	444,837
	We recorded $8.7 million and $10.1 million of depletion and depreciation expense for the three months ended June 30, 2014 and 2013, respectively. We recorded $17.1 million and $20.2 million of depletion and depreciation expense for the six months ended June 30, 2014 and 2013, respectively.
	We perform an impairment analysis of our oil and natural gas properties on a quarterly basis due to the volatility in commodity prices. We did not record any impairment charges in the three or six months ended June 30, 2014 or 2013. If future oil or natural gas prices or our reserves decline, the estimated undiscounted future cash flows for the oil and natural gas properties may not exceed the net capitalized costs for our properties and a non-cash impairment charge may be required to be recognized in future periods.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	6.Asset Retirement Obligations
	The following is a summary of our asset retirement obligations as of and for the six months ended June 30, 2014 (in thousands):
	Beginning of period	$	36,326
	Dispositions	(84		)
	Liabilities incurred	181
	Accretion expense	1,013
	End of period	37,436
	Current portion of asset retirement obligations	(503		)
	Asset retirement obligations — non-current	$	36,933

LongTerm_Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2014
Long-Term Debt	'
Long-Term Debt	'
	7.Long-Term Debt
	Credit Agreement
	In July 2011, subject to consummation of our initial public offering, we, as guarantor, and our wholly owned subsidiary, OLLC, as borrower, entered into a five-year, $500.0 million senior secured revolving credit facility, as amended (the “Credit Agreement”), that matures in July 2016. The Credit Agreement is reserve-based and we are permitted to borrow under our credit facility an amount up to the borrowing base, which was $235.0 million as of June 30, 2014. Our borrowing base, which is primarily based on the estimated value of our oil, NGL, and natural gas properties and our commodity derivative contracts, is subject to redetermination semi-annually by our lenders at their sole discretion. As of June 30, 2014, we were in compliance with all covenants contained in the Credit Agreement.
	Term Loan Agreement
	On June 28, 2012, we, as parent guarantor, and our wholly owned subsidiary, OLLC, as borrower, entered into a Second Lien Credit Agreement (the “Term Loan Agreement”). The Term Loan Agreement provides for a $50.0 million senior secured second lien term loan to OLLC. OLLC borrowed $50.0 million under the Term Loan Agreement and used the borrowings to repay outstanding borrowings under the Credit Agreement. As of June 30, 2014, we were in compliance with all covenants contained in the Term Loan Agreement. The Term Loan Agreement was amended in June 2014 (Note 10).
	The obligations under the Term Loan Agreement and the Credit Agreement are governed by an Intercreditor Agreement with OLLC as borrower and the Partnership as parent guarantor, which (i) provides that any liens on the assets and properties of OLLC, the Partnership or any of their subsidiaries securing the indebtedness under the Term Loan Agreement are subordinate to liens on the assets and properties of OLLC, the Partnership or any of their subsidiaries securing indebtedness under the Credit Agreement and derivative contracts with lenders and their affiliates and (ii) sets forth the respective rights, obligations and remedies of the lenders under the Credit Agreement with respect to their first-priority liens and the lenders under the Term Loan Agreement with respect to their second-priority liens.
	As of June 30, 2014, we had $245.0 million of outstanding debt and accrued interest was approximately $0.2 million. As of December 31, 2013, we had $250.0 million of outstanding debt and accrued interest was approximately $0.2 million.
	Interest expense for the three months ended June 30, 2014 and 2013 was $2.6 million and $2.2 million, respectively. Interest expense for the six months ended June 30, 2014 and 2013 was $5.1 million and $4.5 million, respectively. As of June 30, 2014 and December 31, 2013, our weighted average interest rate on our outstanding indebtedness was 4.21% and 3.88%, respectively. Please refer to Note 8 below for a discussion of our interest rate derivative contracts.

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2014
Derivatives	'
Derivatives	'
	8.Derivatives
	We are exposed to commodity price and interest rate risk and consider it prudent to periodically reduce our exposure to cash flow variability resulting from commodity price changes and interest rate fluctuations. Accordingly, we enter into derivative instruments to manage our exposure to commodity price fluctuations, locational differences between a published index and the NYMEX futures on natural gas or crude oil productions, and interest rate fluctuations.
	Our open positions typically consist of contracts such as (i) crude oil and natural gas financial collar contracts, (ii) crude oil, natural gas liquids (“NGL”) and natural gas financial swaps, (iii) crude oil and natural gas basis financial swaps, (iv) crude oil and natural gas puts and (v) interest rate swap agreements. Our derivative instruments are with the counterparties that are also lenders in our Credit Agreement.
	Swaps and options are used to manage our exposure to commodity price risk and basis risk inherent in our oil and natural gas production. Commodity price swap agreements are used to fix the price of expected future oil and natural gas sales at major industry trading locations such as Henry Hub Louisiana (“HH”) for gas and Cushing Oklahoma (“WTI”) for oil. Basis swaps are used to fix the price differential between the product price at one location versus another. Options are used to establish a floor and a ceiling price (collar) for expected oil or gas sales. Interest rate swaps are used to fix interest rates on existing indebtedness.
	Under commodity swap agreements, we exchange a stream of payments over time according to specified terms with another counterparty. Specifically for commodity price swap agreements, we agree to pay an adjustable or floating price tied to an agreed upon index for the commodity, either gas or oil, and in return receive a fixed price based on notional quantities. Under basis swap agreements, we agree to pay an adjustable or floating price tied to two agreed upon indices for gas and in return receive the differential between a floating index and fixed price based on notional quantities. A collar is a combination of a put purchased by us and a call option written by us. In a typical collar transaction, if the floating price based on a market index is below the floor price, we receive from the counterparty an amount equal to this difference multiplied by the specified volume, effectively a put option. If the floating price exceeds the floor price and is less than the ceiling price, no payment is required by either party. If the floating price exceeds the ceiling price, we must pay the counterparty an amount equal to the difference multiplied by the specific quantity, effectively a call option.
	The interest rate swap agreements effectively fix our interest rate on amounts borrowed under the credit facility. The purpose of these instruments is to mitigate our existing exposure to unfavorable interest rate changes. Under interest rate swap agreements, we pay a fixed interest rate payment on a notional amount in exchange for receiving a floating amount based on LIBOR on the same notional amount.
	We elected not to designate any positions as cash flow hedges for accounting purposes and, accordingly, recorded the net change in the mark-to-market valuation of these derivative contracts in the consolidated condensed statements of operations. We record our derivative activities on a mark-to-market or fair value basis. Fair values are based on pricing models that consider various assumptions, including quoted forward prices for commodities, the time value of money and volatility, and are comparable to values obtained from counterparties. We present the fair value of derivative financial instruments on a net basis in the consolidated condensed balance sheets.
	At June 30, 2014, we had the following open commodity derivative contracts:
			Index		2014			2015			2016			2017
	Natural gas positions
	Price swaps (MMBTUs)		NYMEX-HH		2,961,198			5,500,236			5,433,888			5,045,760
	Weighted average price				$	5.56		$	5.72		$	4.29		$	4.61
	Basis swaps (MMBTUs)		-1		2,860,739			5,326,559			2,877,047			—
	Weighted average price				$	(0.1530	)	$	(0.1661	)	$	(0.1115	)	$	—
	Oil positions
	Price swaps (BBLs)		NYMEX-WTI		378,675			683,286			397,488			198,744
	Weighted average price				$	96.18		$	93.39		$	86.02		$	85.75
	Basis swaps (BBLs)		Argus-		195,605			—			—			—
	Weighted average price		Midland-Cushing		$	(1.00	)	$	—		$	—		$	—
	NGL positions
	Price swaps (BBLs)		Mont Belvieu		137,760			236,149			—			—
	Weighted average price				$	34.72		$	34.46		$	—		$	—
		-1		Our natural gas basis swaps are traded on the following indices: Centerpoint East, Houston Ship Channel, WAHA and TEXOK.
	At December 31, 2013, we had the following open commodity derivative contracts:
			Index		2014			2015			2016			2017
	Natural gas positions
	Price swaps (MMBTUs)		NYMEX-HH		6,077,016			5,500,236			5,433,888			5,045,760
	Weighted average price				$	5.53		$	5.72		$	4.29		$	4.61
	Basis swaps (MMBTUs)		-1		5,876,098			5,326,559			2,877,047			—
	Weighted average price				$	(0.1521	)	$	(0.1661	)	$	(0.1115	)	$	—
	Oil positions
	Price swaps (BBLs)		NYMEX-WTI		723,634			561,833			397,488			198,744
	Weighted average price				$	95.76		$	93.16		$	86.02		$	85.75
	Basis swaps (BBLs)		Argus-		410,400			—			—			—
	Weighted average price		Midland-Cushing		$	(1.00	)	$	—		$	—		$	—
	NGL positions
	Price swaps (BBLs)		Mont Belvieu		183,857			147,823			—			—
	Weighted average price				$	34.11		$	34.5		$	—		$	—
		-1		Our natural gas basis swaps are traded on the following indices: Centerpoint East, Houston Ship Channel, WAHA and TEXOK.
	At June 30, 2014 and December 31, 2013, we had the following interest rate swap derivative contracts (in thousands):
					Notional
	Effective		Maturity		Amount			Average %		Index
	February 2012		February 2015		$	150,000		0.51750	%	LIBOR
	February 2015		February 2017		75,000			1.72500	%	LIBOR
	February 2015		February 2017		75,000			1.72750	%	LIBOR
	June 2012		June 2015		70,000			0.52375	%	LIBOR
	June 2015		June 2017		70,000			1.42750	%	LIBOR
	Effect of Derivative Instruments — Balance Sheet
	The fair value of our commodity and interest rate derivative instruments is included in the tables below (in thousands):
			As of June 30, 2014
			Current			Long-term			Current			Long-term
			Assets			Assets			Liabilities			Liabilities
	Interest rate
	Swaps		$	—		$			$	1,304		$	1,915
	Gross fair value		—						1,304			1,915
	Netting arrangements		—						—			—
	Net recorded fair value		$	—		$	—		$	1,304		$	1,915
	Sale of natural gas production
	Price swaps		$	7,374		$	5,563		$	240		$	3
	Basis swaps		2			49			413			379
	Sale of crude oil production
	Price swaps		40			458			4,621			3,629
	Basis swaps		648			—			—			—
Sale of NGLs
Price swaps		65			4			616			137
Gross fair value		8,129			6,074			5,890			4,148
Netting arrangements		(107		)	(505		)	(107		)	(505		)
Net recorded fair value		$	8,022		$	5,569		$	5,783		$	3,643
		As of December 31, 2013
		Current			Long-term			Current			Long-term
		Assets			Assets			Liabilities			Liabilities
Interest rate
Swaps		$	—		$	637		$	648		$	2,191
Gross fair value		—			637			648			2,191
Netting arrangements		—			(637		)	—			(637		)
Net recorded fair value		$	—		$	—		$	648		$	1,554
Sale of natural gas production
Price swaps		$	8,250		$	11,937		$	196		$	73
Basis swaps		56			211			317			65
Sale of crude oil production
Price swaps		1,564			5,042			1,519			331
Basis swaps		227			—			—			—
Sale of NGLs
Price swaps		106			4			662			153
Gross fair value		10,203			17,194			2,694			622
Netting arrangements		(477		)	(448		)	(477		)	(448		)
Net recorded fair value		$	9,726		$	16,746		$	2,217		$	174
Effect of Derivative Instruments — Statements of Operations
The net gain (loss) amounts and classification related to derivative instruments for the periods indicated are as follows (in thousands):
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
Commodity derivatives (revenue)		$	(13,328	)	$	12,354		$	(18,950	)	$	6,287
Interest rate derivatives (other income (expense), net)		(1,128		)	2,657			(1,422		)	2,772
Credit Risk
All of our derivative transactions have been carried out in the over-the-counter market. The use of derivative instruments involves the risk that the counterparties may be unable to meet the financial terms of the transactions. We monitor the creditworthiness of each of our counterparties and assess the possibility of whether each counterparty to the derivative contract would default by failing to make any contractually required payments as scheduled in the derivative instrument in determining the fair value. We also have netting arrangements in place with each counterparty to reduce credit exposure. The derivative transactions are placed with major financial institutions that present minimal credit risks to us. Additionally, we consider ourselves to be of substantial credit quality and have the financial resources and willingness to meet our potential repayment obligations associated with the derivative transactions.

Related_Parties

Related Parties	6 Months Ended
	Jun. 30, 2014
Related Parties	'
Related Parties	'
	9.Related Parties
	Ownership in Our General Partner by Lime Rock Management and its Affiliates
	As of June 30, 2014, Lime Rock Management, an affiliate of Fund I, owned all of the Class A member interests in our general partner, Fund I owned all of the Class B member interests in our general partner and Fund II owned all of the Class C member interests in our general partner. In addition, Fund I owned an aggregate of approximately 18.0% of our outstanding common units and all of our subordinated units, representing an approximate 31.5% limited partner interest in us. As of June 30, 2014, our general partner owned an approximate 0.1% general partner interest in us, represented by 22,400 general partner units, and all of our incentive distribution rights.
	As more fully described in our 2013 Annual Report, three separate one-third tranches of the subordinated units may convert on the first business day after the distribution to unitholders in respect of any quarter ending on or after December 31, 2012, December 31, 2013 and December 31, 2014, respectively, provided that an aggregate amount equal to the minimum quarterly distribution payable with respect to all units that would be payable on four, eight or twelve consecutive quarters, as applicable, has been earned and paid prior to the applicable date, in each case provided there are no arrearages in the minimum quarterly distribution on our common units at that time. We converted 2,240,000 subordinated units on a one-for-one basis into common units pursuant to the terms of our partnership agreement on May 16, 2014. We do not expect the second tranche of the subordinated units to convert pursuant to the provisions of our partnership agreement following our distribution for the second quarter of 2014 that will be paid on August 14, 2014. Each quarter, we will determine whether the test for conversion of the subordinated units has been met until the subordinated units convert pursuant to the provisions of our partnership agreement.
	Contracts with our General Partner and its Affiliates
	As more fully described in our 2013 Annual Report, we have entered into agreements with our general partner and its affiliates. For the three months ended June 30, 2014 and 2013, we paid Lime Rock Management approximately $0.4 million and $0.2 million either directly or indirectly related to these agreements, respectively. For the six months ended June 30, 2014 and 2013, we paid Lime Rock Management approximately $0.6 million and $0.5 million either directly or indirectly related to these agreements, respectively.
	In connection with the management of our business, Lime Rock Resources Operating Company, Inc. (“ServCo”), an affiliate of our general partner, provides services for invoicing and processing of payments to our vendors. Periodically, ServCo remits cash to us for the net working capital received on our behalf. Changes in the affiliates (payable)/receivable balances during the six months ended June 30, 2014 are included below (in thousands):
					Lime Rock
		ServCo			Resources			Total
	Balance as of December 31, 2013	$	(518	)	$	263		$	(255	)
	Expenditures	(51,549		)	—			(51,549		)
	Cash paid for expenditures	66,718			—			66,718
	Revenues and other	(9,175		)	(2		)	(9,177		)
	Balance as of June 30, 2014	$	5,476		$	261		$	5,737
	Distributions of Available Cash to Our General Partner and Affiliates
	We will generally make cash distributions to our unitholders and our general partner pro rata. As of June 30, 2014, our general partner and its affiliates held 4,089,600 of our common units, all of our subordinated units and 22,400 general partner units. During the six months ended June 30, 2014 and 2013, we paid cash distributions of $26.0 million and $23.4 million, respectively, to all unitholders as of the respective record dates.
	We announced our second quarter 2014 distribution on July 18, 2014 as discussed in Note 14.

Unitholders_Equity

Unitholders' Equity	6 Months Ended
	Jun. 30, 2014
Unitholders' Equity	'
Unitholders' Equity	'
	10.Unitholders’ Equity
	At-the-Market Offering Program
	On February 4, 2014, we launched an “at-the-market” offering program (the “ATM Program”) with MLV & Co. LLC (“MLV”) as sales agent. We may sell from time to time through MLV our common units representing limited partner interests having an aggregate offering amount of up to $75.0 million. Any sales of common units under the ATM Program may be made by any method permitted by law deemed to be an “at-the-market offering” defined by Rule 415 of the Securities Act, including, without limitation, sales made directly on the New York Stock Exchange, or any other existing trading market for our common units or to or through a market maker.
	Our second lien term loan requires that 50% of the net cash proceeds from any equity offering be used to repay borrowings outstanding under the term loan. On June 6, 2014, we entered into an amendment to our Term Loan to waive this requirement through September 30, 2014. During the six months ended June 30, 2014, we received net proceeds from the sale of 885,135 newly issued common units of $14.8 million, after deducting underwriting discounts and commissions and offering expenses of approximately $0.5 million, and used the proceeds for general partnership purposes. During the six months ended June 30, 2014, we paid approximately $0.3 million of aggregate compensation to MLV for sales under the ATM Program.
	Equity Offering
	On March 22, 2013, we closed a public equity offering of 3,700,000 common units representing limited partner interests in the Partnership at a price to the public of $16.84 per common unit, or $16.1664 per common unit after payment of the underwriting discount. We received net proceeds from the sale of 3,700,000 newly issued common units of $59.5 million, after deducting underwriting discounts and commissions and offering expenses of $0.3 million. We used the net proceeds of the offering to fund our April 2013 Acquisition discussed in Note 3 and repay borrowings outstanding on our Credit Agreement.
	Fund I sold 3,200,000 common units in the equity offering at a price to the public of $16.84 per common unit, or $16.1664 per common unit after payment of the underwriting discount. We did not receive any proceeds from the sale of common units by Fund I; however, the equity balance of Fund I was adjusted for its reduced ownership interest in us.
	Units Outstanding
	As of June 30, 2014, we had 22,674,390 common units, 4,480,000 subordinated units and 22,400 general partner units outstanding. As of June 30, 2014, Fund I owned 4,089,600 common units and all of our subordinated units, representing an approximate 31.5% limited partner interest in us.

Net_Income_Loss_Per_Limited_Pa

Net Income (Loss) Per Limited Partner Unit	6 Months Ended
	Jun. 30, 2014
Net Income (Loss) Per Limited Partner Unit	'
Net Income (Loss) Per Limited Partner Unit	'
	11.Net Income (Loss) Per Limited Partner Unit
	The following sets forth the calculation of net income (loss) per limited partner unit for the following periods (in thousands, except per unit amounts):
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Net income (loss)	$	(7,337	)	$	20,523		$	(4,643	)	$	13,521
	Net income (loss) attributable to common control operations	—			—			—			(448		)
	Net income (loss) available to unitholders	(7,337		)	20,523			(4,643		)	13,073
	Less: General partner’s interest in net loss (income)	7			(21		)	4			(13		)
	Limited partners’ interest in net income (loss)	$	(7,330	)	$	20,502		$	(4,639	)	$	13,060
	Weighted average limited partner units outstanding:
	Common units	21,121			19,449			20,376			17,835
	Subordinated units	5,612			6,720			6,163			6,720
	Total	26,733			26,169			26,539			24,555
	Net income (loss) per limited partner unit (basic and diluted)	$	(0.27	)	$	0.78		$	(0.17	)	$	0.53
	Our subordinated units and restricted unit awards are considered to be participating securities for purposes of calculating our net income (loss) per limited partner unit, and accordingly, are included in basic computation as such. Net income (loss) per limited partner unit is determined by dividing the net income (loss) available to the common unitholders, after deducting our general partner’s approximate 0.1% interest in net income (loss), by the weighted average number of common units and subordinated units outstanding as of June 30, 2014 and 2013. The aggregate number of common units and subordinated units outstanding was 22,674,390 and 4,480,000, respectively, as of June 30, 2014. The aggregate number of common units and subordinated units outstanding was 19,448,539 and 6,720,000, respectively, as of June 30, 2013.

EquityBased_Compensation

Equity-Based Compensation	6 Months Ended
	Jun. 30, 2014
Equity-Based Compensation	'
Equity-Based Compensation	'
	12.Equity-Based Compensation
	On November 10, 2011, our General Partner adopted a long-term incentive plan (“2011 LTIP”) for employees, consultants and directors of our General Partner and its affiliates, including Lime Rock Management and ServCo, who perform services for us. The 2011 LTIP consists of unit options, restricted units, phantom units, unit appreciation rights, distribution equivalent rights, unit awards and other unit-based awards. The 2011 LTIP initially limits the number of units that may be delivered pursuant to vested awards to 1,500,000 common units. As of June 30, 2014, there were 1,308,345 units available for issuance under the 2011 LTIP. The 2011 LTIP is currently administered by our General Partner’s board of directors or a committee thereof.
	The fair value of restricted units is determined based on the fair market value of the units on the date of grant. The outstanding restricted units vest in equal amounts (subject to rounding) over a three-year period following the date of grant and are entitled to receive quarterly distributions during the vesting period.
	A summary of the status of the non-vested restricted units as of June 30, 2014, is presented below:
		Number of		Weighted Average
		Non-vested		Grant-Date
		Restricted Units		Fair Value
	Non-vested restricted units at December 31, 2013	165,262		$	—
	Granted	3,012		16.6
	Vested	(12,341	)	17.92
	Forfeited	(13,691	)	16.54
	Non-vested restricted units at June 30, 2014	142,242		—
	As of June 30, 2014, there was approximately $2.1 million of unrecognized compensation cost related to non-vested restricted units. The cost is expected to be recognized over a weighted average period of approximately 2.2 years. There were 49,410 vested restricted units as of June 30, 2014.

Subsidiary_Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2014
Subsidiary Guarantors	'
Subsidiary Guarantors	'
	13.Subsidiary Guarantors
	We and LRE Finance, our 100 percent-owned subsidiary, filed a registration statement on Form S-3 with the SEC on August 28, 2013, and the SEC declared the registration statement effective on September 10, 2013. Securities that may be offered and sold include debt securities that are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933. LRE Finance may co-issue any debt securities issued by us pursuant to the registration statement. LRE Finance was formed solely for the purpose of co-issuing our debt securities and has no material assets or liabilities other than as co-issuer of our debt securities, if and when issued. OLLC, our 100 percent-owned subsidiary, may guarantee any debt securities issued by us and such guarantee will be full and unconditional, subject to customary release provisions. The guarantee will be released (i) automatically upon any sale, exchange or transfer of our equity interests in OLLC, (ii) automatically upon the liquidation and dissolution of OLLC, (iii) following delivery of notice to the trustee under the indenture related to the debt securities of the release of OLLC of its obligations under our revolving credit facility, and (iv) upon legal or covenant defeasance or other satisfaction of the obligations under the related debt securities. Other than LRE Finance, OLLC is our sole subsidiary, and thus, no other subsidiary will guarantee our debt securities.
	Furthermore, we have no assets or operations independent of OLLC, and there are no significant restrictions upon the ability of OLLC to distribute funds to us by dividend or loan. Finally, none of our or OLLC’s assets represents restricted net assets pursuant to Rule 4-08(e)(3) of Regulation S-X.

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events	'
Subsequent Events	'
	14.Subsequent Events
	Unit Distribution
	On July 18, 2014, we announced that the board of directors of our general partner declared a cash distribution for the second quarter of 2014 of $0.4950 per outstanding unit, or $1.98 on an annualized basis. The distribution will be paid on August 14, 2014 to all unitholders of record as of the close of business on July 31, 2014. The aggregate amount of the distribution will be $13.6 million.
	Commodity Hedges
	Subsequent to June 30, 2014, we acquired the following commodity hedges:
		Index	2015
	Oil positions
	Basis swaps (BBLs)	Argus-	397,035
	Weighted average price	Midland-Cushing	$	(3.41	)

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Summary of Significant Accounting Policies	'
Basis of Presentation	'
	Basis of presentation
	These interim financial statements are unaudited and have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the audited consolidated/combined financial statements in our 2013 Annual Report. While the year-end condensed balance sheet data was derived from audited financial statements, this interim report does not include all disclosures required by GAAP for annual periods. These unaudited interim consolidated condensed financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for the periods presented.
	Certain reclassifications were made to the historical financial statements to conform to the 2014 presentation. The effects of the reclassification were not material to our unaudited interim consolidated condensed financial statements.
Recent accounting pronouncements	'
	Recent accounting pronouncements
	On May 28, 2014, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers.” ASU No. 2014-09 outlined a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The core principle of the revenue model is that an entity recognizes revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU No. 2014-09 is effective for annual reporting periods beginning after December 15, 2016 and early adoption is not permitted. We are still evaluating the impact of our adoption of ASU No. 2014-09.

Acquisitions_Tables

Acquisitions (Tables) (Oil And Natural Gas Properties In Mid Continent Region In Oklahoma [Member])	6 Months Ended
	Jun. 30, 2014
Fund I [Member]	'
Acquisitions	'
Net assets conveyed by entity under common control in acquisition	'
	The following table presents the net assets conveyed by Fund I to us in the January 2013 Acquisition (in thousands):
	Property and equipment, net	$	23,998
	Oil and natural gas commodity hedge contracts	1,742
	Asset retirement obligations and other liabilities	(1,067		)
	Net assets	$	24,673
Fund I I [Member]	'
Acquisitions	'
Net assets conveyed by entity under common control in acquisition	'
	The following table presents the net assets conveyed by Fund II to us in the April 2013 Acquisition (in thousands):
	Property and equipment, net	$	36,586
	Oil and natural gas commodity hedge contracts	386
	Asset retirement obligations and other liabilities	(990		)
	Net assets	$	35,982

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Measurements	'
Schedule of the fair value of the financial assets and liabilities that were accounted for at fair value on a recurring basis, by level within the hierarchy	'
	The following table describes, by level within the hierarchy, the fair value of our financial assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2014 and December 31, 2013 (in thousands).
		Level 1		Level 2		Level 3		Total
	June 30, 2014
	Assets:
	Commodity derivative instruments	$	—	$	13,591	$	—	$	13,591
	Liabilities:
	Commodity derivative instruments	—		9,426		—		9,426
	Interest rate derivative instruments	—		3,219		—		3,219
	December 31, 2013
	Assets:
	Commodity derivative instruments	$	—	$	26,472	$	—	$	26,472
	Liabilities:
	Commodity derivative instruments	—		2,391		—		2,391
	Interest rate derivative instruments	—		2,202		—		2,202

Property_and_Equipment_Tables

Property and Equipment (Tables)	6 Months Ended
	Jun. 30, 2014
Property and Equipment	'
Schedule of property and equipment, net	'
	Property and equipment is stated at cost less accumulated depletion, depreciation and impairment and consisted of the following (in thousands):
		June 30, 2014			December 31, 2013
	Oil and natural gas properties (successful efforts method)	$	893,825		$	875,126
	Unproved properties	1,238			1,258
	Other property and equipment	289			290
		895,352			876,674
	Accumulated depletion, depreciation and impairment	(449,054		)	(431,837		)
	Total property and equipment, net	$	446,298		$	444,837

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations	'
Summary of our asset retirement obligations	'
	The following is a summary of our asset retirement obligations as of and for the six months ended June 30, 2014 (in thousands):
	Beginning of period	$	36,326
	Dispositions	(84		)
	Liabilities incurred	181
	Accretion expense	1,013
	End of period	37,436
	Current portion of asset retirement obligations	(503		)
	Asset retirement obligations — non-current	$	36,933

Derivatives_Tables

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2014
Derivatives	'
Schedule of open commodity derivative contracts	'
	At June 30, 2014, we had the following open commodity derivative contracts:
			Index		2014			2015			2016			2017
	Natural gas positions
	Price swaps (MMBTUs)		NYMEX-HH		2,961,198			5,500,236			5,433,888			5,045,760
	Weighted average price				$	5.56		$	5.72		$	4.29		$	4.61
	Basis swaps (MMBTUs)		-1		2,860,739			5,326,559			2,877,047			—
	Weighted average price				$	(0.1530	)	$	(0.1661	)	$	(0.1115	)	$	—
	Oil positions
	Price swaps (BBLs)		NYMEX-WTI		378,675			683,286			397,488			198,744
	Weighted average price				$	96.18		$	93.39		$	86.02		$	85.75
	Basis swaps (BBLs)		Argus-		195,605			—			—			—
	Weighted average price		Midland-Cushing		$	(1.00	)	$	—		$	—		$	—
	NGL positions
	Price swaps (BBLs)		Mont Belvieu		137,760			236,149			—			—
	Weighted average price				$	34.72		$	34.46		$	—		$	—
		-1		Our natural gas basis swaps are traded on the following indices: Centerpoint East, Houston Ship Channel, WAHA and TEXOK.
	At December 31, 2013, we had the following open commodity derivative contracts:
			Index		2014			2015			2016			2017
	Natural gas positions
	Price swaps (MMBTUs)		NYMEX-HH		6,077,016			5,500,236			5,433,888			5,045,760
	Weighted average price				$	5.53		$	5.72		$	4.29		$	4.61
	Basis swaps (MMBTUs)		-1		5,876,098			5,326,559			2,877,047			—
	Weighted average price				$	(0.1521	)	$	(0.1661	)	$	(0.1115	)	$	—
	Oil positions
	Price swaps (BBLs)		NYMEX-WTI		723,634			561,833			397,488			198,744
	Weighted average price				$	95.76		$	93.16		$	86.02		$	85.75
	Basis swaps (BBLs)		Argus-		410,400			—			—			—
	Weighted average price		Midland-Cushing		$	(1.00	)	$	—		$	—		$	—
	NGL positions
	Price swaps (BBLs)		Mont Belvieu		183,857			147,823			—			—
	Weighted average price				$	34.11		$	34.5		$	—		$	—
		-1		Our natural gas basis swaps are traded on the following indices: Centerpoint East, Houston Ship Channel, WAHA and TEXOK.
Schedule of interest rate swap derivative contracts	'
	At June 30, 2014 and December 31, 2013, we had the following interest rate swap derivative contracts (in thousands):
					Notional
	Effective		Maturity		Amount			Average %		Index
	February 2012		February 2015		$	150,000		0.51750	%	LIBOR
	February 2015		February 2017		75,000			1.72500	%	LIBOR
	February 2015		February 2017		75,000			1.72750	%	LIBOR
	June 2012		June 2015		70,000			0.52375	%	LIBOR
	June 2015		June 2017		70,000			1.42750	%	LIBOR
Schedule of fair value of commodity and interest rate derivative contracts	'
	The fair value of our commodity and interest rate derivative instruments is included in the tables below (in thousands):
			As of June 30, 2014
			Current			Long-term			Current			Long-term
			Assets			Assets			Liabilities			Liabilities
	Interest rate
	Swaps		$	—		$			$	1,304		$	1,915
	Gross fair value		—						1,304			1,915
	Netting arrangements		—						—			—
	Net recorded fair value		$	—		$	—		$	1,304		$	1,915
	Sale of natural gas production
	Price swaps		$	7,374		$	5,563		$	240		$	3
	Basis swaps		2			49			413			379
	Sale of crude oil production
	Price swaps		40			458			4,621			3,629
	Basis swaps		648			—			—			—
	Sale of NGLs
	Price swaps		65			4			616			137
	Gross fair value		8,129			6,074			5,890			4,148
	Netting arrangements		(107		)	(505		)	(107		)	(505		)
	Net recorded fair value		$	8,022		$	5,569		$	5,783		$	3,643
			As of December 31, 2013
			Current			Long-term			Current			Long-term
			Assets			Assets			Liabilities			Liabilities
	Interest rate
	Swaps		$	—		$	637		$	648		$	2,191
	Gross fair value		—			637			648			2,191
	Netting arrangements		—			(637		)	—			(637		)
	Net recorded fair value		$	—		$	—		$	648		$	1,554
	Sale of natural gas production
	Price swaps		$	8,250		$	11,937		$	196		$	73
	Basis swaps		56			211			317			65
	Sale of crude oil production
	Price swaps		1,564			5,042			1,519			331
	Basis swaps		227			—			—			—
	Sale of NGLs
	Price swaps		106			4			662			153
	Gross fair value		10,203			17,194			2,694			622
	Netting arrangements		(477		)	(448		)	(477		)	(448		)
	Net recorded fair value		$	9,726		$	16,746		$	2,217		$	174
Schedule of net gain or (loss) amounts and classification related to derivative instruments	'
	The net gain (loss) amounts and classification related to derivative instruments for the periods indicated are as follows (in thousands):
			Three Months Ended June 30,						Six Months Ended June 30,
			2014			2013			2014			2013
	Commodity derivatives (revenue)		$	(13,328	)	$	12,354		$	(18,950	)	$	6,287
	Interest rate derivatives (other income (expense), net)		(1,128		)	2,657			(1,422		)	2,772

Related_Parties_Tables

Related Parties (Tables)	6 Months Ended
	Jun. 30, 2014
Related Parties	'
Schedule of changes in the affiliates (payable)/receivable balances	'
	Changes in the affiliates (payable)/receivable balances during the six months ended June 30, 2014 are included below (in thousands):
					Lime Rock
		ServCo			Resources			Total
	Balance as of December 31, 2013	$	(518	)	$	263		$	(255	)
	Expenditures	(51,549		)	—			(51,549		)
	Cash paid for expenditures	66,718			—			66,718
	Revenues and other	(9,175		)	(2		)	(9,177		)
	Balance as of June 30, 2014	$	5,476		$	261		$	5,737

Net_Income_Loss_Per_Limited_Pa1

Net Income (Loss) Per Limited Partner Unit (Tables)	6 Months Ended
	Jun. 30, 2014
Net Income (Loss) Per Limited Partner Unit	'
Schedule of calculation of net income (loss) per limited partner unit	'
	The following sets forth the calculation of net income (loss) per limited partner unit for the following periods (in thousands, except per unit amounts):
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Net income (loss)	$	(7,337	)	$	20,523		$	(4,643	)	$	13,521
	Net income (loss) attributable to common control operations	—			—			—			(448		)
	Net income (loss) available to unitholders	(7,337		)	20,523			(4,643		)	13,073
	Less: General partner’s interest in net loss (income)	7			(21		)	4			(13		)
	Limited partners’ interest in net income (loss)	$	(7,330	)	$	20,502		$	(4,639	)	$	13,060
	Weighted average limited partner units outstanding:
	Common units	21,121			19,449			20,376			17,835
	Subordinated units	5,612			6,720			6,163			6,720
	Total	26,733			26,169			26,539			24,555
	Net income (loss) per limited partner unit (basic and diluted)	$	(0.27	)	$	0.78		$	(0.17	)	$	0.53

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Equity-Based Compensation	'
Summary of the non-vested restricted units	'
		Number of		Weighted Average
		Non-vested		Grant-Date
		Restricted Units		Fair Value
	Non-vested restricted units at December 31, 2013	165,262		$	—
	Granted	3,012		16.6
	Vested	(12,341	)	17.92
	Forfeited	(13,691	)	16.54
	Non-vested restricted units at June 30, 2014	142,242		—

Subsequent_Events_Tables

Subsequent Events (Tables)	6 Months Ended
	Jun. 30, 2014
Subsequent Events	'
Schedule of commodity hedges	'
	Subsequent to June 30, 2014, we acquired the following commodity hedges:
		Index	2015
	Oil positions
	Basis swaps (BBLs)	Argus-	397,035
	Weighted average price	Midland-Cushing	$	(3.41	)

Description_of_Business_Detail

Description of Business (Details) (L R E Finance Corporation [Member])	6 Months Ended
	Jun. 30, 2014
L R E Finance Corporation [Member]	'
Description of Business	'
Ownership interest held (as a percent)	100.00%

Acquisitions_Details

Acquisitions (Details) (Oil And Natural Gas Properties In Mid Continent Region In Oklahoma [Member], USD $)	Jun. 30, 2013	Jan. 03, 2013	Apr. 02, 2013
	Fund I [Member]	Fund I [Member]	Fund I I [Member]
Acquisitions	'	'	'
Purchase price	$400,000	$21,000,000	$38,200,000
Net assets conveyed by Fund I to the Partnership in the Transaction	'	'	'
Property and equipment, net	'	23,998,000	36,586,000
Oil and natural gas commodity hedge contracts	'	1,742,000	386,000
Asset retirement obligations and other liabilities	'	-1,067,000	-990,000
Net assets	'	$24,673,000	$35,982,000

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (Fair Value Measurements Recurring [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value Inputs Level2 [Member] | Commodity Contract [Member]	'	'
Fair Value Measurements	'	'
Assets	$13,591	$26,472
Liabilities	9,426	2,391
Fair Value Inputs Level2 [Member] | Interest Rate Contract [Member]	'	'
Fair Value Measurements	'	'
Liabilities	3,219	2,202
Estimate Of Fair Value Fair Value Disclosure [Member] | Commodity Contract [Member]	'	'
Fair Value Measurements	'	'
Assets	13,591	26,472
Liabilities	9,426	2,391
Estimate Of Fair Value Fair Value Disclosure [Member] | Interest Rate Contract [Member]	'	'
Fair Value Measurements	'	'
Liabilities	$3,219	$2,202

Property_and_Equipment_Details

Property and Equipment (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Property and Equipment	'	'	'	'	'
Oil and natural gas properties (successful efforts method)	$893,825	'	$893,825	'	$875,126
Unproved properties	1,238	'	1,238	'	1,258
Other property and equipment	289	'	289	'	290
Property and equipment, gross	895,352	'	895,352	'	876,674
Accumulated depletion, depreciation and impairment	-449,054	'	-449,054	'	-431,837
Total property and equipment, net	446,298	'	446,298	'	444,837
Depletion and depreciation expense	$8,680	$10,129	$17,145	$20,239	'

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Asset retirement obligations	'	'	'	'	'
Beginning of period	'	'	$36,326	'	'
Dispositions	'	'	-84	'	'
Liabilities incurred	'	'	181	'	'
Accretion expense	510	477	1,013	947	'
End of period	37,436	'	37,436	'	'
Current portion of asset retirement obligations	-503	'	-503	'	-488
Asset retirement obligation-non-current	$36,933	'	$36,933	'	$35,838

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	3 Months Ended		6 Months Ended			1 Months Ended		0 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Jul. 31, 2011	Jun. 30, 2014	Jun. 28, 2012
						Revolving Credit Facility [Member]	Revolving Credit Facility [Member]	Secured Debt [Member]
							Maximum [Member]
Long-Term Debt	'	'	'	'	'	'	'	'
Term of credit facility	'	'	'	'	'	'5 years	'	'
Maximum borrowing capacity	'	'	'	'	'	$500,000,000	'	'
Borrowing capacity	'	'	'	'	'	'	235,000,000	'
Face amount	'	'	'	'	'	'	'	50,000,000
Amount borrowed	'	'	'	'	'	'	'	50,000,000
Outstanding debt	245,000,000	'	245,000,000	'	250,000,000	'	'	'
Accrued interest	200,000	'	200,000	'	200,000	'	'	'
Interest expense	$2,575,000	$2,249,000	$5,116,000	$4,514,000	'	'	'	'
Weighted average interest rate (as a percent)	4.21%	'	4.21%	'	3.88%	'	'	'

Derivatives_Details

Derivatives (Details) (USD $)

6 Months Ended

12 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Commodity Basis Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Natural Gas Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Natural Gas Liquids Reserves [Member]

Natural Gas Liquids Reserves [Member]

Natural Gas Liquids Reserves [Member]

Natural Gas Liquids Reserves [Member]

item

February2012 To February2015 Term [Member]

February2012 To February2015 Term [Member]

February2015 To February2017 Term One [Member]

February2015 To February2017 Term One [Member]

February2015 To February2017 Term Two [Member]

February2015 To February2017 Term Two [Member]

June2012 To June2015 Term [Member]

June2012 To June2015 Term [Member]

June2015 To June2017 Term [Member]

June2015 To June2017 Term [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2017 [Member]

Derivative Contract Maturity In Year2017 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2016 [Member]

Derivative Contract Maturity In Year2017 [Member]

Derivative Contract Maturity In Year2017 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Derivatives

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of indices for gas on which floating price is based

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Volume of commodity hedge (in MMBTUs)

'

'

'

'

'

'

'

'

'

'

'

2,961,198

6,077,016

5,500,236

5,500,236

5,433,888

5,433,888

5,045,760

5,045,760

2,860,739

5,876,098

5,326,559

5,326,559

2,877,047

2,877,047

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Volume of commodity hedge (in BBLs)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

378,675

723,634

683,286

561,833

397,488

397,488

198,744

198,744

195,605

410,400

137,760

183,857

236,149

147,823

Weighted average price of commodity hedge (in dollars per MMBTU/BBL)

'

'

'

'

'

'

'

'

'

'

'

5.56

5.53

5.72

5.72

4.29

4.29

4.61

4.61

-0.153

-0.1521

-0.1661

-0.1661

-0.1115

-0.1115

96.18

95.76

93.39

93.16

86.02

86.02

85.75

85.75

-1

-1

34.72

34.11

34.46

34.5

Notional Amount

'

$150,000

$150,000

$75,000

$75,000

$75,000

$75,000

$70,000

$70,000

$70,000

$70,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average %

'

0.52%

0.52%

1.73%

1.73%

1.73%

1.73%

0.52%

0.52%

1.43%

1.43%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Index

'

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivatives_Details_2

Derivatives (Details 2) (Nondesignated [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	$8,129	$10,203
Netting arrangements, assets	-107	-477
Net recorded fair value of assets	8,022	9,726
Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	6,074	17,194
Netting arrangements, assets	-505	-448
Net recorded fair value of assets	5,569	16,746
Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	5,890	2,694
Netting arrangements, liabilities	-107	-477
Net recorded fair value of liabilities	5,783	2,217
Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	4,148	622
Netting arrangements, liabilities	-505	-448
Net recorded fair value of liabilities	3,643	174
Interest Rate Swap [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	'	637
Netting arrangements, assets	'	-637
Interest Rate Swap [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	1,304	648
Net recorded fair value of liabilities	1,304	648
Interest Rate Swap [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	1,915	2,191
Netting arrangements, liabilities	'	-637
Net recorded fair value of liabilities	1,915	1,554
Commodity Price Swap [Member] | Natural Gas Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	7,374	8,250
Commodity Price Swap [Member] | Natural Gas Reserves [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	5,563	11,937
Commodity Price Swap [Member] | Natural Gas Reserves [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	240	196
Commodity Price Swap [Member] | Natural Gas Reserves [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	3	73
Commodity Price Swap [Member] | Oil Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	40	1,564
Commodity Price Swap [Member] | Oil Reserves [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	458	5,042
Commodity Price Swap [Member] | Oil Reserves [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	4,621	1,519
Commodity Price Swap [Member] | Oil Reserves [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	3,629	331
Commodity Price Swap [Member] | Natural Gas Liquids Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	'	106
Commodity Price Swap [Member] | Natural Gas Liquids Reserves [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	'	4
Commodity Price Swap [Member] | Natural Gas Liquids Reserves [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	'	662
Commodity Price Swap [Member] | Natural Gas Liquids Reserves [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	'	153
Commodity Basis Swap [Member] | Natural Gas Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	2	56
Commodity Basis Swap [Member] | Natural Gas Reserves [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	49	211
Commodity Basis Swap [Member] | Natural Gas Reserves [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	413	317
Commodity Basis Swap [Member] | Natural Gas Reserves [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	379	65
Commodity Basis Swap [Member] | Oil Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	648	227
Commodity Basis Swap [Member] | Natural Gas Liquids Reserves [Member] | Current Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	65	'
Commodity Basis Swap [Member] | Natural Gas Liquids Reserves [Member] | Long Term Assets [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of assets	4	'
Commodity Basis Swap [Member] | Natural Gas Liquids Reserves [Member] | Current Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	616	'
Commodity Basis Swap [Member] | Natural Gas Liquids Reserves [Member] | Long Term Liabilities [Member]	'	'
Fair value of derivative instruments	'	'
Gross fair value of liabilities	$137	'

Derivatives_Details_3

Derivatives (Details 3) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Unrealized and realized gain or loss amounts	'	'	'	'
Derivative instruments, gains losses	($1,128)	$2,657	($1,422)	$2,772
Gain (loss) on commodity derivative instruments, net	-13,328	12,354	-18,950	6,287
Nondesignated [Member] | Commodity Contract [Member] | Sales [Member]	'	'	'	'
Unrealized and realized gain or loss amounts	'	'	'	'
Gain (loss) on commodity derivative instruments, net	-13,328	12,354	-18,950	6,287
Nondesignated [Member] | Interest Rate Contract [Member] | Other Expense [Member]	'	'	'	'
Unrealized and realized gain or loss amounts	'	'	'	'
Derivative instruments, gains losses	($1,128)	$2,657	($1,422)	$2,772

Related_Parties_Details

Related Parties (Details) (USD $)

0 Months Ended

6 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

16-May-14

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Common Units [Member]

Common Units [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Fund I [Member]

Fund I [Member]

Lime Rock Management L P [Member]

Lime Rock Management L P [Member]

Lime Rock Management L P [Member]

Lime Rock Management L P [Member]

General Partner And Affiliates [Member]

General Partner And Affiliates [Member]

Lime Rock Resources Operating Company Inc [Member]

Lime Rock Resources [Member]

item

Common Units [Member]

Common Units [Member]

Related Parties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of limited partner interest

'

'

'

'

'

'

'

'

'

31.50%

18.00%

'

'

'

'

'

'

'

'

Partnership interest (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.10%

'

'

'

General partner units held

'

22,400

'

22,400

'

'

'

'

'

'

'

'

'

'

'

22,400

'

'

'

Number of tranches in which subordinated units may convert to common units

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Number of consecutive quarters of minimum quarterly distribution to end subordination period, tranche one

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

Percentage conversion per tranche

'

'

'

'

'

'

0.33

'

'

'

'

'

'

'

'

'

'

'

'

Number of consecutive quarters of minimum quarterly distribution to end subordination period, tranche two

'

'

'

'

'

'

8

'

'

'

'

'

'

'

'

'

'

'

'

Number of consecutive quarters of minimum quarterly distribution to end subordination period, tranche three

'

'

'

'

'

'

12

'

'

'

'

'

'

'

'

'

'

'

'

Subordinated units

2,240,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Unit Conversion

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment made to related party

'

'

'

'

'

'

'

'

'

'

'

$400,000

$200,000

$600,000

$500,000

'

'

'

'

Limited partner units held

'

'

'

'

22,674,390

19,448,539

4,480,000

6,720,000

6,720,000

'

'

'

'

'

'

'

4,089,600

'

'

Aggregate amount of distribution

'

25,990,000

23,422,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in the affiliates (payable)/receivable balances

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at the beginning of the period

'

-255,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-518,000

263,000

Expenditures

'

-51,549,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-51,549,000

'

Cash paid for expenditures

'

66,718,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

66,718,000

'

Revenues and other

'

-9,177,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-9,175,000

-2,000

Balance at the end of the period

'

$5,737,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$5,476,000

$261,000

Unitholders_Equity_Details

Unitholders' Equity (Details) (USD $)

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

Jun. 30, 2014

Feb. 04, 2014

Dec. 31, 2013

Feb. 04, 2014

Jun. 30, 2014

Mar. 22, 2013

Jun. 30, 2014

Jun. 30, 2013

Mar. 22, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2013

Secured Debt [Member]

Fund I [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Fund I [Member]

Fund I [Member]

At-the-Market Offering Program

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate offering amount

'

$75,000,000

'

'

'

'

'

'

'

'

'

'

'

Percentage of net cash proceeds from equity offering required to be used to repay borrowings outstanding

'

'

'

0.5

'

'

'

'

'

'

'

'

'

Number of shares issued

'

'

'

'

'

3,700,000

885,135

'

'

'

'

'

'

Share price of units issued in equity offering (in dollars per unit)

'

'

'

'

'

$16.84

'

'

$16.84

'

'

'

'

Share price of units issued in equity offering after payment of underwriting discount (in dollars per unit)

'

'

'

'

'

$16.17

'

'

$16.17

'

'

'

'

Net proceeds from the sale of common units in equity offering

14,810,000

'

'

'

'

59,500,000

14,800,000

'

'

'

'

'

'

Offering expenses

'

'

'

'

'

300,000

500,000

'

'

'

'

'

'

Aggregate compensation to MLV

'

'

'

'

'

'

$300,000

'

'

'

'

'

'

Number of units sold by the related party as part of the equity offering

'

'

'

'

'

'

'

'

3,200,000

'

'

'

'

Units Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited partner, units outstanding

'

'

'

'

'

'

22,674,390

19,448,539

'

'

4,480,000

6,720,000

6,720,000

General partner, units outstanding

22,400

'

22,400

'

'

'

'

'

'

'

'

'

'

Partner units held

'

'

'

'

'

'

'

'

'

4,089,600

'

'

'

Limited partner interest (as a percent)

'

'

'

'

31.50%

'

'

'

'

18.00%

'

'

'

Percentage conversion per tranche

'

'

'

'

'

'

'

'

'

'

0.33

'

'

Net_Income_Loss_Per_Limited_Pa2

Net Income (Loss) Per Limited Partner Unit (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

In Thousands, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2012

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

General Partner [Member]

General Partner [Member]

General Partner [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Subordinated Units Affiliated [Member]

Net income (loss)

($7,337)

$20,523

($4,643)

$13,521

($4)

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to predecessor operations

'

'

'

-448

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss) available to unitholders

-7,337

20,523

-4,643

13,073

'

'

'

'

'

'

'

'

'

'

'

'

Less: General partner's approximate 0.1% interest in net income (loss)

7

-21

4

-13

'

'

'

'

'

'

'

'

'

'

'

'

Limited partners' interest in net income (loss)

($7,330)

$20,502

($4,639)

$13,060

'

'

'

'

'

'

'

'

'

'

'

'

Partner's interest in net income (loss) (as a percent)

'

'

'

'

'

0.10%

0.10%

'

'

'

'

'

'

'

'

'

Weighted average limited partner units outstanding

26,733,000

26,169,000

26,539,000

24,555,000

'

'

'

21,121,000

19,449,000

20,376,000

17,835,000

5,612,000

6,720,000

6,163,000

6,720,000

'

Net income (loss) per limited partner unit (basic and diluted) (in dollars per unit)

($0.27)

$0.78

($0.17)

$0.53

'

'

'

'

'

'

'

'

'

'

'

'

Limited partner, units outstanding

'

'

'

'

'

'

'

22,674,390

19,448,539

22,674,390

19,448,539

4,480,000

6,720,000

4,480,000

6,720,000

6,720,000

EquityBased_Compensation_Detai

Equity-Based Compensation (Details) (USD $)	6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014
Equity-Based Compensation	'
Number of units authorized	1,500,000
Number of units available for issuance	1,308,345
Restricted Stock [Member]	'
Equity-Based Compensation	'
Vesting period	'3 years
Number of Non-vested Restricted Units	'
Non-vested restricted units at the beginning of the period	165,262
Granted (in units)	3,012
Vested (in units)	-12,341
Forfeited (in units)	-13,691
Non-vested restricted units at the end of the period	142,242
Weighted Average Grant-Date Fair Value	'
Granted (in dollars per unit)	$16.60
Vested (in dollars per unit)	$17.92
Forfeited (in dollars per unit)	$16.54
Unrecognized compensation cost related to non-vested restricted units	$2.10
Weighted average period over which unrecognized compensation cost is to be recognized	'2 years 2 months 12 days
Number of units granted under the 2011 LTIP, that have vested	49,410

Subsidiary_Guarantors_Details

Subsidiary Guarantors (Details)	6 Months Ended
	Jun. 30, 2014
L R E Finance Corporation [Member]	'
Subsidiary Guarantors	'
Ownership interest held (as a percent)	100.00%
L R E Operating L L C [Member]	'
Subsidiary Guarantors	'
Ownership interest held (as a percent)	100.00%

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

6 Months Ended

0 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jul. 18, 2014

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2014 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Derivative Contract Maturity In Year2015 [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Natural Gas Liquids Reserves [Member]

Natural Gas Liquids Reserves [Member]

Oil Reserves [Member]

Oil Reserves [Member]

Natural Gas Liquids Reserves [Member]

Natural Gas Liquids Reserves [Member]

Derivative Contract Maturity In Year2015 [Member]

Dividend Declared [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Basis Swap [Member]

Commodity Basis Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Commodity Price Swap [Member]

Oil Reserves [Member]

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Commodity Basis Swap [Member]

bbl

Subsequent Events

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution declared per outstanding unit (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.50

Cash distribution declared on an annualized basis (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.98

Aggregate amount of distribution

$25,990

$23,422

'

'

'

'

'

'

'

'

'

'

'

$13,600

Volume of commodity hedge (in BBLs)

'

'

378,675

723,634

195,605

410,400

137,760

183,857

683,286

561,833

236,149

147,823

397,035

'

Weighted average price of commodity hedge (in dollars per MMBTU/BBL)

'

'

96.18

95.76

-1

-1

34.72

34.11

93.39

93.16

34.46

34.5

-3.41

'