Amplify Energy (AMPYW) 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 [Member]	General Partner [Member]
Document Information [Line Items]	'	'	'	'
Document Type	'10-Q	'	'	'
Amendment Flag	'false	'	'	'
Document Period End Date	30-Jun-14	'	'	'
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q2	'	'	'
Trading Symbol	'MEMP	'	'	'
Entity Registrant Name	'MEMORIAL PRODUCTION PARTNERS LP	'	'	'
Entity Central Index Key	'0001521847	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'
Entity Filer Category	'Accelerated Filer	'	'	'
Entity Common Stock, Shares Outstanding	'	66,384,211	5,360,912	71,820

UNAUDITED_CONDENSED_CONSOLIDAT

UNAUDITED CONDENSED CONSOLIDATED AND COMBINED BALANCE SHEETS (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$349	$13,139
Accounts receivable:	'	'
Oil and natural gas sales	50,264	31,132
Joint interest owners and other	11,943	4,634
Affiliates	'	4,473
Short-term derivative instruments	1,436	7,600
Prepaid expenses and other current assets	9,403	9,146
Total current assets	73,395	70,124
Property and equipment, at cost:	'	'
Oil and natural gas properties, successful efforts method	2,107,459	1,764,468
Other	2,917	2,900
Accumulated depreciation, depletion and impairment	-487,409	-418,688
Oil and natural gas properties, net	1,622,967	1,348,680
Long-term derivative instruments	1,149	42,657
Restricted investments	75,506	73,385
Other long-term assets	86,332	17,461
Total assets	1,859,349	1,552,307
Current liabilities:	'	'
Accounts payable	18,207	8,566
Accounts payable - affiliates	2,409	474
Revenues payable	23,487	16,291
Accrued liabilities	54,455	39,847
Short-term derivative instruments	45,188	7,996
Total current liabilities	143,746	73,174
Long-term debt (Note 8)	1,148,806	792,067
Asset retirement obligations	103,513	99,619
Long-term derivative instruments	90,696	5,875
Other long-term liabilities	3,804	1,956
Total liabilities	1,490,565	972,691
Commitments and contingencies (Note 13)	'	'
Partners' equity (deficit):	'	'
General partner (61,920 units outstanding at June 30, 2014 and 61,300 units outstanding at December 31, 2013)	529	728
Total partners' equity	363,213	574,088
Noncontrolling interests	5,571	5,528
Total equity	368,784	579,616
Total liabilities and equity	1,859,349	1,552,307
Limited Partners Common Units [Member]	'	'
Partners' equity (deficit):	'	'
Limited partners units	389,906	582,075
Total equity	389,906	582,075
Subordinated Units [Member]	'	'
Partners' equity (deficit):	'	'
Limited partners units	($27,222)	($8,715)

UNAUDITED_CONDENSED_CONSOLIDAT1

UNAUDITED CONDENSED CONSOLIDATED AND COMBINED BALANCE SHEETS (Parenthetical)	Jun. 30, 2014	Dec. 31, 2013
General partner, units outstanding	61,920	61,300
Limited Partners Common Units [Member]	'	'
Limited partners, units outstanding	56,497,187	55,877,831
Subordinated Units [Member]	'	'
Limited partners, units outstanding	5,360,912	5,360,912

UNAUDITED_CONDENSED_STATEMENTS

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED AND COMBINED OPERATIONS (USD $)	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
Revenues:	'	'	'	'
Oil & natural gas sales	$122,247	$89,673	$222,546	$157,261
Pipeline tariff income and other	1,063	501	1,741	1,015
Total revenues	123,310	90,174	224,287	158,276
Costs and expenses:	'	'	'	'
Lease operating	26,067	20,217	54,055	41,588
Pipeline operating	676	479	1,165	949
Exploration	204	48	210	275
Production and ad valorem taxes	7,076	4,967	12,660	8,847
Depreciation, depletion, and amortization	35,157	24,672	61,902	45,063
General and administrative	10,588	14,170	20,546	21,483
Accretion of asset retirement obligations	1,366	1,148	2,723	2,293
(Gain) loss on commodity derivative instruments	138,346	-36,079	185,112	-23,010
(Gain) loss on sale of properties	'	-885	'	-2,868
Other, net	'	623	-12	597
Total costs and expenses	219,480	29,360	338,361	95,217
Operating income (loss)	-96,170	60,814	-114,074	63,059
Other income (expense):	'	'	'	'
Interest expense, net	-18,036	-7,931	-34,114	-14,473
Total other income (expense)	-18,036	-7,931	-34,114	-14,473
Income (loss) before income taxes	-114,206	52,883	-148,188	48,586
Income tax benefit (expense)	'	-188	-75	-188
Net income (loss)	-114,206	52,695	-148,263	48,398
Net income (loss) attributable to noncontrolling interest	-12	98	43	94
Net income (loss) attributable to Memorial Production Partners LP	-114,194	52,597	-148,306	48,304
Limited partners' interest in net income (loss):	'	'	'	'
Net income (loss) attributable to Memorial Production Partners LP	-114,194	52,597	-148,306	48,304
Net (income) loss allocated to previous owners	'	-6,418	'	-7,147
Net (income) loss allocated to general partner	94	-46	108	-41
Net (income) loss allocated to NGP IDRs	-20	'	-40	'
Limited partners' interest in net income (loss)	($114,120)	$46,133	($148,238)	$41,116
Earnings per unit: (Note 10)	'	'	'	'
Basic and diluted earnings per unit	($1.86)	$1.04	($2.42)	$1.04
Weighted average limited partner units outstanding:	'	'	'	'
Basic and diluted	61,464	44,231	61,358	39,668

UNAUDITED_CONDENSED_STATEMENTS1

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED AND COMBINED CASH FLOWS (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash flows from operating activities:	'	'
Net income (loss)	($148,263)	$48,398
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion, and amortization	61,902	45,063
(Gain) loss on derivative instruments	186,203	-24,680
Cash settlements (paid) received on derivative instruments	-16,518	9,357
Amortization of deferred financing costs	1,701	3,823
Accretion of senior notes net discount	739	86
Accretion of asset retirement obligations	2,723	2,293
Amortization of equity awards	2,960	1,085
Gain on sale of properties	'	-2,868
Non-cash compensation expense	'	1,125
Changes in operating assets and liabilities:	'	'
Accounts receivable	-17,278	-8,563
Prepaid expenses and other assets	-117	-369
Payables and accrued liabilities	20,050	7,040
Other	1,950	75
Net cash provided by operating activities	96,052	81,865
Cash flows from investing activities:	'	'
Acquisitions of oil and natural gas properties	-173,000	-6,310
Additions to oil and gas properties	-117,616	-88,629
Additions to restricted investments	-2,121	-3,080
Additions to other property and equipment	'	-130
Deposits for property acquisitions	-70,125	'
Proceeds from the sale of oil and natural gas properties	'	4,525
Net cash used in investing activities	-362,862	-93,624
Cash flows from financing activities:	'	'
Advances on revolving credit facilities	418,000	251,250
Payments on revolving credit facilities	-62,000	-691,702
Proceeds from borrowings of long-term debt	'	397,563
Deferred financing costs	-590	-11,224
Capital contributions from previous owners	'	7,126
Contributions related to sale of assets to NGP affiliate	'	2,013
Proceeds from general partner contribution	14	189
Proceeds from the issuance of common units	'	179,371
Costs incurred in conjunction with issuance of common units	'	-7,592
Distributions to partners	-67,524	-40,030
Distribution to Memorial Resource (see Note 12)	-33,880	-55,419
Distributions made by previous owners	'	-23,157
Net cash provided by financing activities	254,020	8,388
Net change in cash and cash equivalents	-12,790	-3,371
Cash and cash equivalents, beginning of period	13,139	24,440
Cash and cash equivalents, end of period	349	21,069
Supplemental cash flows:	'	'
Cash paid for interest	31,298	8,078
Noncash investing and financing activities:	'	'
Change in capital expenditures in payables and accrued liabilities	12,434	16,768
Eagle Ford Acquisition [Member]	'	'
Noncash investing and financing activities:	'	'
Accounts receivable	3,879	'
Double A Acquisition [Member]	'	'
Noncash investing and financing activities:	'	'
Accounts receivable	$586	'

UNAUDITED_CONDENSED_STATEMENTS2

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED AND COMBINED EQUITY (USD $)	Total	Noncontrolling Interest [Member]	NGP IDR [Member]	Limited Partners Common Units [Member]	Limited Partners Subordinated [Member]	General Partner [Member]
In Thousands
Balance at Dec. 31, 2013	$579,616	$5,528	'	$582,075	($8,715)	$728
Net income (loss)	-148,263	43	40	-135,376	-12,862	-108
Amortization of equity awards	2,960	'	'	2,960	'	'
Contributions	14	'	'	'	'	14
Distributions	-67,524	'	-40	-61,479	-5,897	-108
Contributions attributable to net assets acquired	2,914	'	'	2,656	255	3
Other	-933	'	'	-930	-3	'
Balance at Jun. 30, 2014	$368,784	$5,571	'	$389,906	($27,222)	$529

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Organization and Basis of Presentation	'
	Note 1.  Organization and Basis of Presentation
	General
	Memorial Production Partners LP (the “Partnership”) is a publicly traded Delaware limited partnership, the common units of which are listed on the NASDAQ Global Market (“NASDAQ”) under the symbol “MEMP.” Unless the context requires otherwise, references to “we,” “us,” “our,” or “the Partnership” are intended to mean the business and operations of Memorial Production Partners LP and its consolidated subsidiaries.
	The Partnership was formed in April 2011 by Memorial Resource Development LLC (“MRD LLC”) to own, acquire and exploit oil and natural gas properties in North America. In January 2014, MRD LLC formed Memorial Resource Development Corp (“MRD”). On June 18, 2014, MRD LLC contributed substantially all of its assets, including its interest in our general partner, to MRD in connection with MRD’s initial public offering. Unless the context requires otherwise, references to “Memorial Resource” refer collectively to MRD and its subsidiaries other than the Partnership. The Partnership is owned 99.9% by its limited partners and 0.1% by its general partner, Memorial Production Partners GP LLC, which is a wholly-owned subsidiary of Memorial Resource. Our general partner is responsible for managing all of the Partnership’s operations and activities.
	We operate in one reportable segment engaged in the acquisition, exploitation, development and production of oil and natural gas properties. Our management evaluates performance based on one reportable business segment as there are not different economic environments within the operation of our oil and natural gas properties. Our business activities are conducted through Memorial Production Operating LLC (“OLLC”), our wholly owned subsidiary, and its wholly-owned subsidiaries. Our assets consist primarily of producing oil and natural gas properties and are located in Texas, Louisiana, Colorado, Wyoming, New Mexico, and offshore Southern California. Most of our oil and natural gas properties are located in large, mature oil and natural gas reservoirs. The Partnership’s properties consist primarily of operated and non-operated working interests in producing and undeveloped leasehold acreage and working interests in identified producing wells (often referred to as wellbore assignments).
	Memorial Production Finance Corporation (“Finance Corp.”), our wholly-owned subsidiary, has no material assets or any liabilities other than as a co-issuer of our debt securities and as a guarantor of certain of our other indebtedness. Its activities will be limited to co-issuing our debt securities and engaging in other activities incidental thereto.
	Memorial Resource was formed by MRD LLC in January 2014 to exploit, develop and acquire natural gas, NGL and oil properties in North America. MRD LLC was a Delaware limited liability company formed in April 2011 by Natural Gas Partners VIII, L.P., Natural Gas Partners IX, L.P. and NGP IX Offshore Holdings, L.P. (collectively, the “Funds”) to own, acquire, exploit and develop oil and natural gas properties and to own our general partner. In June 2014, (i) the Funds contributed all of their interests in MRD LLC to MRD Holdco LLC (“MRD Holdco”), after which MRD Holdco owned 100% of MRD LLC, and (ii) MRD LLC distributed certain assets, including all of our subordinated units, to MRD Holdco. On June 27, 2014, MRD LLC merged into MRD Operating LLC, a subsidiary of MRD. Memorial Resource provides management, administrative, and operations personnel to us and our general partner under an omnibus agreement (see Note 12). The Funds are private equity funds managed by Natural Gas Partners (“NGP”). The Funds collectively indirectly own 50% of our incentive distribution rights (“IDRs”). The remaining IDRs are owned by our general partner.
	References to “the previous owners” for accounting and financial reporting purposes refer collectively to: (i) certain oil and natural gas properties and related assets in East Texas and North Louisiana that the Partnership acquired in March 2013 (the “WHT Properties”) owned by WHT Energy Partners LLC (“WHT”) from February 2, 2011 (inception) through the date of acquisition, and (ii) certain oil and natural gas properties and related assets primarily in the Permian Basin, East Texas and the Rockies that the Partnership acquired through equity and asset transactions on October 1, 2013, which we refer to collectively as the “Cinco Group acquisition,” from MRD LLC and certain affiliates of NGP.
	Each of these acquisitions was accounted for as a transaction between entities under common control, similar to a pooling of interests, whereby the net assets acquired were recorded at historical cost and certain financial and other information has been retrospectively revised to give effect to such acquisitions as if the Partnership owned the assets for periods after common control commenced through their respective acquisition dates. The WHT Properties represent additional working interests in properties that we originally acquired in December 2011 in conjunction with our initial public offering. See Note 12 for additional information regarding these common control transactions.
	Basis of Presentation
	Our consolidated results of operations are presented together with the combined results of operations pertaining to the previous owners. The combined financial statements of the previous owners were derived from their historical accounting records and reflect their historical financial position, results of operations and cash flows.
	The ownership interest of the noncontrolling shareholder in the San Pedro Bay Pipeline Company (“SPBPC”), an indirect majority-owned subsidiary of the Partnership, is presented as a noncontrolling interest in the financial statements.
	Our results of operations for the three and six months ended June 30, 2014 are not necessarily indicative of results expected for the full year. In our opinion, the accompanying unaudited condensed consolidated and combined financial statements include all adjustments of a normal recurring nature necessary for fair presentation. Although we believe the disclosures in these financial statements are adequate and make the information presented not misleading, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted pursuant to the rules and regulations of the United States Securities and Exchange Commission (“SEC”). These unaudited condensed consolidated and combined financial statements and the notes thereto should be read in conjunction with the audited consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2013 (the “2013 Form 10-K”).
	All material intercompany transactions and balances have been eliminated in preparation of our consolidated and combined financial statements.
	Use of Estimates
	The preparation of the accompanying unaudited condensed consolidated and combined financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated and combined financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Significant estimates include, but are not limited to, oil and natural gas reserves; depreciation, depletion, and amortization of proved oil and natural gas properties; future cash flows from oil and natural gas properties; impairment of long-lived assets; fair value of derivatives; fair value of equity compensation; fair values of assets acquired and liabilities assumed in business combinations and asset retirement obligations.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Note 2.  Summary of Significant Accounting Policies
	A discussion of our critical accounting policies and estimates is included in our 2013 Form 10-K.
	Current Liabilities – Accrued liabilities
	Current accrued liabilities consisted of the following at the dates indicated (in thousands):
		June 30,		December 31,
		2014		2013
	Accrued capital expenditures	$	28,627	$	16,193
	Accrued lease operating expense		9,509		10,666
	Accrued general and administrative expenses		688		1,547
	Accrued ad valorem taxes		4,778		1,531
	Accrued interest payable		8,923		8,931
	Environmental liability		698		437
	Other		1,232		542
		$	54,455	$	39,847
	New Accounting Pronouncements
	Revenue from Contracts with Customers. In May 2014, the FASB issued a comprehensive new revenue recognition standard for contracts with customers that will supersede most current revenue recognition guidance, including industry-specific guidance. The core principle of this standard is that an entity should recognize 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. To achieve this core principle, the standard provides a five-step analysis of transactions to determine when and how revenue is recognized. Other major provisions include the capitalization and amortization of certain contract costs, ensuring the time value of money is considered in the transaction price, and allowing estimates of variable consideration to be recognized before contingencies are resolved in certain circumstances. This guidance also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from an entity’s contracts with customers. The new standard is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early application is prohibited. The standard permits the use of either the retrospective or cumulative effect transition method. This guidance will be applicable to the Partnership beginning on January 1, 2017. The Partnership is currently assessing the impact that adopting this new accounting guidance will have on its consolidated financial statements and footnote disclosures.
	Reporting Discontinued Operations. In April 2014, the FASB issued an accounting standards update that changes the criteria for determining when disposals can be presented as discontinued operations and modifies discontinued operations disclosures. The new guidance now defines a “discontinued operation” as (i) a disposal of a component or group of components that is disposed of or is classified as held for sale and “represents a strategic shift that has (or will have) a major effect on an entity’s operations and financial results” or (ii) an acquired business or nonprofit activity that is classified as held for sale on the date of acquisition. We will adopt this guidance and apply the disclosure requirements prospectively beginning on January 1, 2015.
	Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Partnership’s financial position, results of operations and cash flows.

Acquisitions_and_Divestitures

Acquisitions and Divestitures	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Acquisitions and Divestitures	'
	Note 3. Acquisitions and Divestitures
	Related Party Acquisitions. See Note 12 for further information regarding related party acquisitions that have been accounted for as transactions between entities under common control that impact the basis of presentation for the periods presented.
	Third Party Acquisition. In March 2014, we closed a transaction to acquire certain oil and natural gas producing properties from a third party in the Eagle Ford for approximately $169.1 million, including estimated customary post-closing adjustments (the “Eagle Ford Acquisition”). In addition, we acquired a 30% interest in the seller’s Eagle Ford leasehold. During the three and six months ended June 30, 2014, revenues of approximately $13.4 million and $14.4 million, respectively, were recorded in the statement of operations related to the Eagle Ford Acquisition subsequent to the closing date and we generated earnings of approximately $7.4 million and $8.0 million for the three and six months ended June 30, 2014, respectively. The following table summarizes the preliminary fair value assessment of the assets acquired and liabilities assumed as of the acquisition date (in thousands):
			Eagle Ford
			Acquisition
	Oil and gas properties		$	169,656
	Asset retirement obligations			(285)
	Accrued liabilities			(250)
	Total identifiable net assets		$	169,121
	Acquisition-related costs. Acquisition-related costs for both related party and third party transactions are included in general and administrative expenses in the accompanying statements of operations for the periods indicated below (in thousands):
	For the Three Months								For the Six Months
	Ended June 30,								Ended June 30,
	2014				2013				2014				2013
	$	1,093			$	897			$	2,987			$	1,112
	The following unaudited pro forma combined results of operations are provided for the three and six months ended June 30, 2014 and 2013 as though the Eagle Ford Acquisition had been completed on January 1, 2013. The unaudited pro forma financial information was derived from the historical combined statements of operations of the Partnership and the previous owners and adjusted to include: (i) the revenues and direct operating expenses associated with oil and gas properties acquired, (ii) depletion expense applied to the adjusted basis of the properties acquired and (iii) interest expense on additional borrowings necessary to finance the acquisition. The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the transaction occurred on the basis assumed above, nor is such information indicative of expected future results of operations.
			For the Three Months								For the Six Months
			Ended June 30,								Ended June 30,
			2014				2013				2014				2013
			(In thousands, except per unit amounts)
	Revenues		$	123,310			$	104,050			$	233,553			$	184,911
	Net income (loss)			(114,206)				59,775				(144,054)				61,887
	Basic and diluted earnings per unit			(1.86)				1.20				(2.35)				1.38
	Previous Owners’ Divestitures
	On January 1, 2013, Tanos sold a natural gas gathering pipeline located in East Texas, which it had originally acquired in April 2010, to a privately held gas transportation company for a minimum of $1.5 million. The maximum allowable additional proceeds are $2.0 million. The contingent consideration is based on the natural gas pipeline servicing any new wells that Tanos drills in the area over the following three years. The contingent consideration portion of an arrangement is recorded when the consideration is determined to be realizable. Tanos recorded an aggregate gain of approximately $1.4 million related to this transaction, of which $0.4 million was contingent consideration.
	During the six months ended June 30, 2013, Tanos also sold certain non-operated oil and gas properties for $2.9 million and recorded a gain of $1.4 million.
	Previous Owners’ Acquisitions
	2013 Acquisitions
	During the six months ended June 30, 2013, Propel Energy acquired incremental interests in certain oil and gas properties and leases in the Hendrick Field located in Winkler County, Texas from two third parties in two separate transactions for an aggregate purchase price of approximately $6.3 million.

Fair_Value_Measurements_of_Fin

Fair Value Measurements of Financial Instruments	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements of Financial Instruments	'
	Note 4.  Fair Value Measurements of Financial Instruments
	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 a specified measurement date. Fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk. A three-tier hierarchy has been established that classifies fair value amounts recognized or disclosed in the financial statements. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). All of the derivative instruments reflected on the accompanying balance sheets were considered Level 2.
	The carrying values of accounts receivables, accounts payables (including accrued liabilities) and amounts outstanding under long-term debt agreements with variable rates included in the accompanying balance sheets approximated fair value at June 30, 2014 and December 31, 2013. The fair value estimates are based upon observable market data and are classified within Level 2 of the fair value hierarchy. These assets and liabilities are not presented in the following tables. See Note 8 for the estimated fair value of our outstanding fixed-rate debt.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	The fair market values of the derivative financial instruments reflected on the balance sheets as of June 30, 2014 and December 31, 2013 were based on estimated forward commodity prices and forward interest rate yield curves. Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement in its entirety. The significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The following table presents the gross derivative assets and liabilities that are measured at fair value on a recurring basis at June 30, 2014 and December 31, 2013 for each of the fair value hierarchy levels:
			Fair Value Measurements at June 30, 2014 Using
			Quoted Prices in				Significant Other		Significant		Fair Value
									Unobservable Inputs
			Active Market				Observable Inputs
									(Level 3)
			(Level 1)				(Level 2)
					(In thousands)
	Assets:
	Commodity derivatives				$	--	$	47,256	$	--	$	47,256
	Interest rate derivatives					--		11		--		11
	Total assets					--	$	47,267		--	$	47,267
	Liabilities:
	Commodity derivatives				$	--	$	176,143	$	--	$	176,143
	Interest rate derivatives					--		4,423		--		4,423
	Total liabilities				$	--	$	180,566	$	--	$	180,566
			Fair Value Measurements at December 31, 2013 Using
			Quoted Prices in				Significant Other		Significant		Fair Value
									Unobservable Inputs
			Active Market				Observable Inputs
									(Level 3)
			(Level 1)				(Level 2)
					(In thousands)
	Assets:
	Commodity derivatives				$	--	$	95,926	$	--	$	95,926
	Interest rate derivatives					--		872		--		872
	Total assets				$	--	$	96,798	$	--	$	96,798
	Liabilities:
	Commodity derivatives				$	--	$	55,576	$	--	$	55,576
	Interest rate derivatives					--		4,836		--		4,836
	Total liabilities				$	--	$	60,412	$	--	$	60,412
	See Note 5 for additional information regarding our derivative instruments.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Certain assets and liabilities are reported at fair value on a nonrecurring basis as reflected on the balance sheets. The following methods and assumptions are used to estimate the fair values:
		•		The fair value of asset retirement obligations (“AROs”) is based on discounted cash flow projections using numerous estimates, assumptions, and judgments regarding factors such as the existence of a legal obligation for an ARO; amounts and timing of settlements; the credit-adjusted risk-free rate; and inflation rates. See Note 6 for a summary of changes in AROs.
		•		If sufficient market data is not available, the determination of the fair values of proved and unproved properties acquired in transactions accounted for as business combinations are prepared by utilizing estimates of discounted cash flow projections. The factors to determine fair value include, but are not limited to, estimates of: (i) economic reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital.
		•		Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate a possible decline in the recoverability of the carrying value of such properties. The factors used to determine fair value include, but are not limited to, estimates of proved reserves, future commodity prices, the timing of future production and capital expenditures and a discount rate commensurate with the risk reflective of the lives remaining for the respective oil and gas properties.
	We did not have any impairment charges for the three and six months ended June 30, 2014 and 2013, respectively.

Risk_Management_and_Derivative

Risk Management and Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Risk Management and Derivative Instruments	'
	Note 5.  Risk Management and Derivative Instruments
	Derivative instruments are utilized to manage exposure to commodity price and interest rate fluctuations and achieve a more predictable cash flow in connection with natural gas and oil sales from production and borrowing related activities. These instruments limit exposure to declines in prices or increases in interest rates, but also limit the benefits that would be realized if prices increase or interest rates decrease.
	Certain inherent business risks are associated with commodity and interest derivative contracts, including market risk and credit risk. Market risk is the risk that the price of natural gas or oil will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by the counterparty to a contract. It is our policy to enter into derivative contracts, including interest rate swaps, only with creditworthy counterparties, which generally are financial institutions, deemed by management as competent and competitive market makers. Some of the lenders, or certain of their affiliates, under our credit agreement are counterparties to our derivative contracts. While collateral is generally not required to be posted by counterparties, credit risk associated with derivative instruments is minimized by limiting exposure to any single counterparty and entering into derivative instruments only with creditworthy counterparties that are generally large financial institutions. Additionally, master netting agreements are used to mitigate risk of loss due to default with counterparties on derivative instruments. We have also entered into the International Swaps and Derivatives Association Master Agreements (“ISDA Agreements”) with each of our counterparties. The terms of the ISDA Agreements provide us and each of our counterparties with rights of set-off upon the occurrence of defined acts of default by either us or our counterparty to a derivative, whereby the party not in default may set-off all liabilities owed to the defaulting party against all net derivative asset receivables from the defaulting party. At June 30, 2014, after taking into effect netting arrangements, we do not have any counterparty exposure related to our derivative instruments. As a result, had certain counterparties failed completely to perform according to the terms of their existing contracts, we would have the right to offset $1.7 million against amounts outstanding under our revolving credit facility at June 30, 2014. See Note 8 for additional information regarding our revolving credit facility.
	Commodity Derivatives
	We may use a combination of commodity derivatives (e.g., floating-for-fixed swaps, costless collars, call spreads and basis swaps) to manage exposure to commodity price volatility. Historically, the Partnership has not paid or received premiums for put options. We enter into natural gas derivative contracts that are indexed to NYMEX-Henry Hub and regional indices such as NGPL TXOK, TETCO STX, and Houston Ship Channel in proximity to our areas of production. We also enter into oil derivative contracts indexed to Inter-Continental Exchange (“ICE”) Brent and California Midway-Sunset. Our NGL derivative contracts are indexed to OPIS Mont Belvieu. At June 30, 2014, we had the following open commodity positions:
		Remaining				2015				2016				2017				2018		2019
		2014
	Natural Gas Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (MMBtu)		2,626,033				2,605,278				2,692,442				2,450,067				2,160,000		1,914,583
	Weighted-average fixed price	$	4.33			$	4.28			$	4.4			$	4.31			$	4.51	$	4.75
	Collar contracts:
	Average Monthly Volume (MMBtu)		340,000				350,000				--				--				--		--
	Weighted-average floor price	$	5			$	4.62			$	--			$	--			$	--	$	--
	Weighted-average ceiling price	$	6.31			$	5.8			$	--			$	--			$	--	$	--
	Call spreads (1):
	Average Monthly Volume (MMBtu)		120,000				80,000				--				--				--		--
	Weighted-average sold strike price	$	5.17			$	5.25			$	--			$	--			$	--	$	--
	Weighted-average bought strike price	$	6.53			$	6.75			$	--			$	--			$	--	$	--
	Basis swaps:
	Average Monthly Volume (MMBtu)		2,875,833				2,940,000				600,000				--				--		--
	Spread	$	-0.09			$	-0.12			$	-0.1			$	--			$	--	$	--
	Crude Oil Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (Bbls)		285,285				314,281				300,313				286,600				272,000		60,000
	Weighted-average fixed price	$	95.8			$	90.96			$	85.44			$	83.96			$	83.24	$	83.33
	Collar contracts:
	Average Monthly Volume (Bbls)		23,000				5,000				--				--				--		--
	Weighted-average floor price	$	82.83			$	80			$	--			$	--			$	--	$	--
	Weighted-average ceiling price	$	105.31			$	94			$	--			$	--			$	--	$	--
	Basis swaps:
	Average Monthly Volume (Bbls)		134,000				97,500				--				--				--		--
	Spread	$	-4.32			$	-7.07			$	--			$	--			$	--	$	--
	NGL Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (Bbls)		171,000				149,200				--				--				--		--
	Weighted-average fixed price	$	42.96			$	43.02			$	--			$	--			$	--	$	--
	(1)    These transactions were entered into for the purpose of eliminating the ceiling portion of certain collar arrangements, which effectively converted the applicable collars into swaps.
	Interest Rate Swaps
	Periodically, we enter into interest rate swaps to mitigate exposure to market rate fluctuations by converting variable interest rates such as those in our credit agreement to fixed interest rates. From time to time we enter into offsetting positions to avoid being economically over-hedged. At June 30, 2014, we had the following interest rate swap open positions:
		Remaining				2015				2016
		2014
	Average Monthly Notional (in thousands)		$          236,667				$          280,833				$          150,000
	Weighted-average fixed rate		1.32%				1.42%				1.19%
	Floating rate		1 Month LIBOR				1 Month LIBOR				1 Month LIBOR
	Balance Sheet Presentation
	The following table summarizes both: (i) the gross fair value of derivative instruments by the appropriate balance sheet classification even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the balance sheet and (ii) the net recorded fair value as reflected on the balance sheet at June 30, 2014 and December 31, 2013. There was no cash collateral received or pledged associated with our derivative instruments since most of the counterparties, or certain of their affiliates, to our derivative contracts are lenders under our credit agreement.
				Asset Derivatives								Liability Derivatives
				June 30,				December 31,				June 30,				December 31,
	Type	Balance Sheet Location		2014				2013				2014				2013
				(In thousands)
	Commodity contracts	Short-term derivative instruments		$	10,425			$	18,578			$	50,721			$	17,120
	Interest rate swaps	Short-term derivative instruments			--				845				3,456				2,699
	Gross fair value				10,425				19,423				54,177				19,819
	Netting arrangements	Short-term derivative instruments			(8,989)				(11,823)				(8,989)				(11,823)
	Net recorded fair value	Short-term derivative instruments		$	1,436			$	7,600			$	45,188			$	7,996
	Commodity contracts	Long-term derivative instruments		$	36,831			$	77,348			$	125,422			$	38,456
	Interest rate swaps	Long-term derivative instruments			11				27				967				2,137
	Gross fair value				36,842				77,375				126,389				40,593
	Netting arrangements	Long-term derivative instruments			(35,693)				(34,718)				(35,693)				(34,718)
	Net recorded fair value	Long-term derivative instruments		$	1,149			$	42,657			$	90,696			$	5,875
	(Gains) Losses on Derivatives
	We do not designate derivative instruments as hedging instruments for accounting and financial reporting purposes and neither did the previous owners. Accordingly, all gains and losses, including changes in the derivative instruments’ fair values, have been recorded in the accompanying statements of operations. The following table details the gains and losses related to derivative instruments for the three and six months ended June 30, 2014 and 2013 (in thousands):
			For the Three Months								For the Six Months
			Ended June 30,								Ended June 30,
	Statements of		2014				2013				2014				2013
	Operations Location
Commodity derivative contracts	(Gain) loss on commodity derivatives		$	138,346			$	(36,079)			$	185,112			$	(23,010)
Interest rate derivatives	Interest expense, net			776				(1,677)				1,091				(1,670)

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	Note 6.  Asset Retirement Obligations
	The Partnership’s asset retirement obligations primarily relate to the Partnership’s portion of future plugging and abandonment costs for wells and related facilities. The following table presents the changes in the asset retirement obligations for the six months ended June 30, 2014 (in thousands):
	Asset retirement obligations at beginning of period	$	99,619
	Liabilities added from acquisitions or drilling		1,448
	Revisions		66
	Liabilities settled		(343)
	Accretion expense		2,723
	Asset retirement obligations at end of period	$	103,513

Restricted_Investments

Restricted Investments	6 Months Ended
	Jun. 30, 2014
Text Block [Abstract]	'
Restricted Investments	'
	Note 7.  Restricted Investments
	Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with our offshore Southern California oil and gas properties. The components of the restricted investment balance consisted of the following at the dates indicated:
		June 30,		December 31,
		2014		2013
		(In thousands)
	BOEM platform abandonment (See Note 13)	$	68,313	$	66,373
	BOEM lease bonds		794		794
	SPBPC Collateral:
	Contractual pipeline and surface facilities abandonment		2,487		2,306
	California State Lands Commission pipeline right-of-way bond		3,005		3,005
	City of Long Beach pipeline facility permit		500		500
	Federal pipeline right-of-way bond		307		307
	Port of Long Beach pipeline license		100		100
	Restricted investments	$	75,506	$	73,385

Long_Term_Debt

Long Term Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Long Term Debt	'
	Note 8.  Long Term Debt
	The following table presents our consolidated and combined debt obligations at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	459,000	$	103,000
	2021 Senior Notes, fixed-rate, due May 2021 (1)			700,000		700,000
	Unamortized discounts			(10,194)		(10,933)
	Total long-term debt		$	1,148,806	$	792,067
	(1)	The estimated fair value of our fixed-rate debt was $735.0 million and $721.0 million at June 30, 2014 and December 31, 2013, respectively. The estimated fair value is based on quoted market prices and is classified as Level 2 within the fair value hierarchy.
	Subsidiary Guarantors
	We are a “Well-Known Seasoned Issuer” under SEC rules, and thus may at any time file, a universal shelf registration statement with the SEC that allows us to issue debt and equity securities. Any debt securities issued will be governed by an indenture. Our outstanding debt securities are, and any debt securities issued in the future will likely be, jointly and severally, fully and unconditionally guaranteed (subject to customary release provisions) by certain of the Partnership’s subsidiaries (collectively, the “Guarantor Subsidiaries”). The Guarantor Subsidiaries are 100% owned by the Partnership. The Partnership has no material assets or operations independent of the Guarantor Subsidiaries and there are no significant restrictions upon the ability of the Guarantor Subsidiaries to distribute funds to the Partnership.
	Borrowing Base
	Credit facilities tied to borrowing bases are common throughout the oil and gas industry. The borrowing base for our credit facility was the following at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	870,000	$	845,000
	OLLC Revolving Credit Facility
	OLLC is a party to a $2.0 billion revolving credit facility, which is guaranteed by us and all of our current and future subsidiaries (other than certain immaterial subsidiaries).
	2021 Senior Notes
	On April 17, 2013, May 23, 2013 and October 10, 2013, we and Finance Corp. (collectively, the “Issuers”) issued $300.0 million, $100.0 million and $300.0 million, respectively, of 7.625% senior unsecured notes due 2021 (the “2021 Senior Notes”). The 2021 Senior Notes are fully and unconditionally guaranteed (subject to customary release provisions) on a joint and several basis by the Guarantor Subsidiaries and by certain future subsidiaries of the Partnership. The 2021 Senior Notes will mature on May 1, 2021 with interest accruing at a rate of 7.625% per annum and payable semi-annually in arrears on May 1 and November 1 of each year. The 2021 Senior Notes are governed by an indenture and are subject to optional redemption at prices specified in the indenture plus accrued and unpaid interest, if any. The Issuers may also be required to repurchase the 2021 Senior Notes upon a change of control. The indenture contains customary covenants and restrictive provisions, many of which will terminate if at any time no default exists under the indenture and the 2021 Senior Notes receive an investment grade rating from both of two specified ratings agencies. The indenture also provides for customary and other events of default. In the case of an event of default arising from certain events of bankruptcy or insolvency with respect to either of the Issuers, all outstanding 2021 Senior Notes will become due and payable immediately without further action or notice. If any other event of default occurs and is continuing, the trustee or the holders of at least 25% in principal amount of the then outstanding 2021 Senior Notes may declare all the 2021 Senior Notes to be due and payable immediately.
	Weighted-Average Interest Rates
	The following table presents the weighted-average interest rates paid on our consolidated and combined variable-rate debt obligations for the periods presented:
			For the Three Months				For the Six Months
			Ended June 30,				Ended June 30,
			2014		2013		2014		2013
	OLLC revolving credit facility			2.46%		3.31%		2.70%		2.98%
	WHT revolving credit facility			n/a		n/a		n/a		1.11%
	Stanolind revolving credit facility			n/a		3.79%		n/a		3.56%
	Boaz revolving credit facility			n/a		2.89%		n/a		3.07%
	Crown revolving credit facility			n/a		3.50%		n/a		3.41%
	Tanos revolving credit facility			n/a		n/a		n/a		2.12%
	Propel Energy revolving credit facility			n/a		2.89%		n/a		3.08%
	Unamortized Deferred Financing Costs
	Unamortized deferred financing costs associated with our consolidated debt obligations were as follows at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	5,019	$	5,413
	2021 Senior Notes (1)			14,335		15,053
	(1)    Unamortized deferred financing costs are amortized using the straight line method which approximates the effective interest method.
	Advances and Repayments
	The following table presents borrowings and repayments under our consolidated and combined revolving credit facilities for the periods presented (in thousands):
			OLLC Revolving		Previous Owner		Total
			Credit Facility		Revolving
					Credit Facility
	For the Six Months Ended June 30, 2014:
	Advances on revolving credit facility			$          418,000	$	--	$	418,000
	Payments on revolving credit facility			(62,000)		--		-62,000
	For the Six Months Ended June 30, 2013:
	Advances on revolving credit facility			$          237,000	$	14,250	$	251,250
	Payments on revolving credit facility			(569,000)		-122,702		-691,702

Equity_Distributions

Equity & Distributions	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Equity & Distributions	'
	Note 9.  Equity & Distributions
	2013 Public Equity Offering
	On March 25, 2013, we issued 9,775,000 common units representing limited partner interests in the Partnership (including 1,275,000 common units purchased pursuant to the full exercise of the underwriters’ option to purchase additional common units) to the public at an offering price of $18.35 per unit generating total net proceeds of approximately $171.8 million after deducting underwriting discounts and offering expenses. The net proceeds from the equity offering, including our general partner’s proportionate capital contribution, partially funded the acquisition of all of the outstanding equity interests in WHT as further discussed under Note 12.
	Equity Outstanding
	The following table summarizes changes in the number of outstanding units since December 31, 2013:
			Common			Subordinated				General
										Partner
	Balance December 31, 2013			55,877,831			5,360,912				61,300
	Common units issued			--			--				--
	Restricted common units issued			669,898			--				--
	Restricted common units forfeited			(8,863)			--				--
	Restricted common units repurchased (1)			(41,679)			--				--
	General partner units issued			--			--				620
	Balance June 30, 2014			56,497,187			5,360,912				61,920
	(1)    Restricted common units are generally net-settled by unitholders to cover the required withholding tax upon vesting. Unitholders surrendered units with value equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes. Total payments remitted for the employees’ tax obligations to the appropriate taxing authorities were approximately $0.9 million. These net-settlements had the effect of unit repurchases by the Partnership as they reduced the number of units that would have otherwise been outstanding as a result of the vesting and did not represent an expense to the Partnership.
	Restricted common units are a component of common units as presented on our unaudited condensed consolidated balance sheets. See Note 11 for additional information regarding restricted common units that were granted during the six months ended June 30, 2014.
	As of June 30, 2014, MRD Holdco owned 100% of the subordinated units. Memorial Resource owns 100% of our general partner, which owns 50% of our incentive distribution rights. The Funds collectively indirectly own 50% of our incentive distribution rights.
	Allocations of Net Income (Loss)
	Net income (loss) attributable to the Partnership is allocated between our general partner and the common and subordinated unitholders in proportion to their pro rata ownership after giving effect to priority earnings allocations in an amount equal to incentive cash distributions allocated to our general partner and the Funds. Net income (loss) attributable to acquisitions accounted for as a transaction between entities under common control prior to their acquisition date is allocated to the previous owners.
	Cash Distributions to Unitholders
	The following table summarizes our declared quarterly cash distribution rates with respect to the quarter indicated (dollars in millions, except per unit amounts):
	Quarter		Declaration Date		Record Date	Payable Date		Amount				Aggregate		Distribution
								Per Unit				Distribution		Received by
														Affiliates (2)
	2nd Quarter 2014 (1)		24-Jul-14		5-Aug-14	12-Aug-14		$	0.55			$	39.5	$	3.0
	1st Quarter 2014		24-Apr-14		6-May-14	13-May-14		$	0.55			$	33.8	$	3.0
	4th Quarter 2013		27-Jan-14		6-Feb-14	13-Feb-14		$	0.55			$	33.8	$	3.0
	3rd Quarter 2013		22-Oct-13		1-Nov-13	12-Nov-13		$	0.55			$	33.8	$	6.9
	2nd Quarter 2013		18-Jul-13		1-Aug-13	12-Aug-13		$	0.5125			$	22.9	$	6.4
	1st Quarter 2013		18-Apr-13		1-May-13	13-May-13		$	0.5125			$	22.6	$	6.4
	4th Quarter 2012		15-Jan-13		1-Feb-13	13-Feb-13		$	0.5075			$	17.4	$	6.3
	(1)	Distributions paid on August 12, 2014 will include distributions paid on 9,890,000 common units which were issued on July 15, 2014. See Note 14 for more information regarding the equity offering.
	(2)	In June 2014, MRD LLC distributed all of our subordinated units to MRD Holdco. See Note 1 for additional information.

Earnings_per_Unit

Earnings per Unit	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings per Unit	'
	Note 10.  Earnings per Unit
	The following sets forth the calculation of earnings (loss) per unit, or EPU, for the periods indicated (in thousands, except per unit amounts):
		For the Three Months				For the Six Months
		Ended June 30,				Ended June 30,
		2014		2013		2014		2013
	Net income (loss) attributable to Memorial Production Partners LP	$	(114,194)	$	52,597	$	(148,306)	$	48,304
	Less: Previous owners interest in net income (loss)		--		6,418		--		7,147
	Less: General partner’s 0.1% interest in net income (loss)		(114)		46		(148)		41
	Less: IDRs attributable to corresponding period		47		--		87		--
	Net income (loss) available to limited partners	$	(114,127)	$	46,133	$	(148,245)	$	41,116
	Weighted average limited partner units outstanding:
	Common units		56,103		38,870		55,997		34,307
	Subordinated units		5,361		5,361		5,361		5,361
	Total		61,464		44,231		61,358		39,668
	Basic and diluted EPU	$	(1.86)	$	1.04	$	(2.42)	$	1.04
	The following sets forth the calculation of our supplemental EPU, for the periods indicated (in thousands, except per unit amounts):
		For the Three Months				For the Six Months
		Ended June 30,				Ended June 30,
		2014		2013		2014		2013
	Net income (loss) attributable to Memorial Production Partners LP	$	(114,194)	$	52,597	$	(148,306)	$	48,304
	Less: General partner’s 0.1% interest in net income (loss)		(114)		46		(148)		41
	Less: IDRs attributable to corresponding period		47		--		87		--
	Net income (loss) available to limited partners	$	(114,127)	$	52,551	$	(148,245)	$	48,263
	Weighted average limited partner units outstanding:
	Common units		56,103		38,870		55,997		34,307
	Subordinated units		5,361		5,361		5,361		5,361
	Total		61,464		44,231		61,358		39,668
	Supplemental basic and diluted EPU	$	(1.86)	$	1.19	$	(2.42)	$	1.22
	Our supplemental basic and diluted EPU includes all the earnings generated by the Partnership’s previous owners for the periods presented due to common control considerations. As discussed under Note 1, transactions between entities under common control are accounted for retrospectively.

Equitybased_Awards

Equity-based Awards	6 Months Ended
	Jun. 30, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Equity-based Awards	'
	Note 11.  Equity-based Awards
	The following table summarizes information regarding restricted common unit awards granted under the Memorial Production Partners GP LLC Long-Term Incentive Plan (“LTIP”) for the periods presented:
			Number of Units			Weighted-
						Average Grant
						Date Fair Value
						per Unit (1)
	Restricted common units outstanding at December 31, 2013			706,927		$	18.62
	Granted (2)			669,898		$	22.36
	Forfeited			(8,863)		$	18.57
	Vested			(256,130)		$	18.57
	Restricted common units outstanding at June 30, 2014			1,111,832		$	20.89
	(1)    Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
	(2)    The aggregate grant date fair value of restricted common unit awards issued in 2014 was $15.0 million based on a grant date market price range of $21.99 - $22.37 per unit.
	The following table summarizes the amount of recognized compensation expense associated with these awards that are reflected in the accompanying statements of operations for the periods presented (in thousands):
	For the Three Months					For the Six Months
	Ended June 30,					Ended June 30,
	2014				2013	2014		2013
	$	1,665			$            663		$  2,960		$1,085
	The unrecognized compensation cost associated with restricted common unit awards was $21.7 million at June 30, 2014. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of 2.5 years. Since the restricted common units are participating securities, distributions received by the restricted common unitholders are generally included in distributions to partners as presented on our unaudited condensed statements of consolidated and combined cash flows.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Note 12.  Related Party Transactions
	Amounts due to (due from) Memorial Resource and certain affiliates of NGP at June 30, 2014 and December 31, 2013 are presented as “Accounts receivable – affiliates” and “Accounts payable – affiliates” in the accompanying balance sheets.
	Common Control Acquisitions
	April 2014 Acquisition. In April 2014, we acquired certain oil and natural gas properties in East Texas from WildHorse Resources, LLC (“WildHorse”), a subsidiary of MRD LLC, for approximately $33.3 million, including estimated customary post-closing adjustments (the “Double A Acquisition”). The acquired properties primarily represent additional working interests in wells currently owned by us and located in Polk and Tyler Counties in the Double A Field of East Texas as well as the Sunflower, Segno and Sugar Creek Fields. Terms of the transaction were approved by our general partner’s board of directors and by its conflicts committee. This acquisition was accounted for as a transaction with an entity under common control whereby the acquisition was recorded at historical cost at the acquisition date. The Partnership recorded the following net assets (in thousands):
			Double A
			Acquisition
	Oil and gas properties, net		$	37,838
	Asset retirement obligations			(908)
	Other current liabilities			(722)
	Total identifiable net assets		$	36,208
	Due to common control considerations, the difference between the purchase price and the total identifiable assets has been recorded as a contribution on our Unaudited Condensed Statements of Consolidated and Combined Equity.
	March 2013 Acquisition. On March 28, 2013, we acquired all of the outstanding equity interests in WHT from operating subsidiaries of MRD LLC for a purchase price of $200.0 million, which included $4.0 million of working capital and other customary adjustments. This acquisition was funded with borrowings under our revolving credit facility and the net proceeds from our March 25, 2013 public offering of common units (including our general partner’s proportionate capital contribution). The effective date for this transaction was January 1, 2013. Terms of the transaction were approved by our general partner’s board of directors and by its conflicts committee. The acquired properties consist of additional working interests in properties that we originally acquired in December 2011 in conjunction with our initial public offering. This acquisition was accounted for as a combination of entities under common control at historical cost in a manner similar to the pooling of interest method. The Partnership recorded the following net assets (in thousands):
	Cash and cash equivalents		$	1,354
	Accounts receivable			3,866
	Short-term derivative instruments, net			1,206
	Prepaid expenses and other current assets			98
	Oil and natural gas properties, net			192,280
	Long-term derivative instruments, net			3,528
	Accrued liabilities			(3,494)
	Asset retirement obligations			(2,753)
	Credit facilities			(89,300)
	Other long-term liabilities			(111)
	Net assets		$	106,674
	Related Party Agreements
	We and certain of our affiliates have entered into various documents and agreements. These agreements have been negotiated among affiliated parties and, consequently, are not the result of arm’s-length negotiations.
	Omnibus Agreement
	Memorial Resource provides management, administrative and operating services for us and our general partner pursuant to our omnibus agreement. The following table summarizes the amount of general and administrative expenses recognized under the omnibus agreement that are reflected in the accompanying statements of operations for the periods presented (in thousands):
	For the Three Months						For the Six Months
	Ended June 30,						Ended June 30,
	2014				2013		2014		2013
	$	5,411			$	1,766	$	10,259	$	3,251
	Beta Management Agreement
	The Partnership acquired Rise Energy Operating, LLC (“REO”), which owns certain operating interests in producing and non-producing oil and gas properties offshore Southern California, in December 2012. We refer to this transaction as the “Beta acquisition” and the acquired properties as the “Beta properties.” In connection with the Beta acquisition, MRD LLC entered into a management agreement with its wholly-owned subsidiary, Beta Operating Company, LLC. Pursuant to such management agreement, Memorial Resource, as successor to MRD LLC under the agreement, provides management and administrative oversight with respect to the services provided by such subsidiary under certain operating agreements with our subsidiary, Rise Energy Beta, LLC, related to the Beta properties in exchange for an annual management fee. Pursuant to such management agreement and in connection with such operating agreements, Memorial Resource will receive approximately $0.4 million from Rise Energy Beta, LLC annually.
	WHT Management Agreement
	MRD LLC controlled WildHorse and Tanos Energy, LLC (“Tanos”), which collectively owned the outstanding equity interests in WHT prior to March 28, 2013. Under the terms of a management agreement dated April 8, 2011, WildHorse provided executive, financial, accounting and land services to WHT. WildHorse also managed day-to-day field operations and drilling activities. Geological, executive and other services were provided by Tanos. To compensate for these services, WHT paid WildHorse and Tanos management fees totaling approximately $0.2 million per month. In connection with the WHT acquisition, the management agreement was terminated as of March 28, 2013.
	As the designated operator, WildHorse received both operated and non-operated revenues on behalf of WHT and billed and received joint interest billings. WildHorse also paid for lease operating expenses, drilling cost and general and administrative costs on behalf of WHT. Receivable and payable balances were settled monthly between WHT and WildHorse.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Note 13. Commitments and Contingencies
	Litigation & Environmental
	As part of our normal business activities, we may be named as defendants in litigation and legal proceedings, including those arising from regulatory and environmental matters. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to indemnify us against liabilities arising from future legal proceedings. We are not aware of any litigation, pending or threatened, that we believe is reasonably likely to have a significant adverse effect on our financial position, results of operations or cash flows.
	At June 30, 2014 and December 31, 2013, we had $2.5 million and $0.4 million of environmental reserves recorded on our balance sheets, respectively. During the six months ended June 30, 2014, we recorded $2.9 million of estimated environmental remediation expenses associated with our Permian and Wyoming oil and gas properties. These expenses are reflected as a component of lease operating expenses on our statement of operations. Environmental costs for remediation are accrued when environmental remediation efforts are probable and the costs can be reasonably estimated. Such accruals are based on management’s best estimate of the ultimate cost to remediate a site and are adjusted as further information and circumstances develop. Those estimates may change substantially depending on information about the nature and extent of contamination, appropriate remediation technologies and regulatory approvals.
	Supplemental Bond for Decommissioning Liabilities Trust Agreement
	The trust account is held by REO for the benefit of all working interest owners. The following is a summary of the gross held-to-maturity investments held in the trust account less the outside working interest owners share as of June 30, 2014 (in thousands):
	Investment	Amortized
		Cost
	U.S. Bank Money Market Cash Equivalent	$	132,003
	Less: Outside working interest owners share		(63,690)
		$	68,313
	The trust account must maintain minimum balances attributable to REO’s net working interest as follows (in thousands):
	June 30, 2014	$	68,310
	June 30, 2015	$	72,450
	June 30, 2016	$	76,590
	December 31, 2016	$	78,660
	As of June 30, 2014, the maximum remaining obligation net to REO’s interest was approximately $10.3 million.

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Note 14. Subsequent Events
	2022 Senior Notes Offering
	On July 17, 2014, the Issuers completed a private placement of $500.0 million aggregate principal amount of 6.875% senior unsecured notes due in 2022 (the “2022 Senior Notes”). The 2022 Senior Notes were issued at 98.485% of par and are fully and unconditionally guaranteed (subject to customary release provisions) on a joint and several basis by the Guarantor Subsidiaries and by certain future subsidiaries of the Partnership. The 2022 Senior Notes will mature on August 1, 2022 with interest accruing at 6.875% per annum and payable semi-annually in arrears on February 1 and August 1 of each year, commencing on February 1, 2015. The indenture contains customary covenants and restrictive provisions, many of which will terminate if at any time no default exists under the indenture and the 2022 Senior Notes receive an investment grade rating from both of two specified ratings agencies. The indenture also provides for customary and other events of default. In the case of an event of default arising from certain events of bankruptcy or insolvency with respect to either of the Issuers, all outstanding 2022 Senior Notes will become due and payable immediately without further action or notice. If any other event of default occurs and is continuing, the trustee or the holders of at least 25% in principal amount of the then outstanding 2022 Senior Notes may declare all the 2022 Senior Notes to be due and payable immediately. The net proceeds from the notes offering of approximately $484.9 million, after deducting the initial purchasers’ discounts and commissions but before estimated offering expenses, were used to repay a portion of the outstanding borrowings under our revolving credit facility and for general partnership purposes. In conjunction with the closing of the offer and sale of the 2022 Senior Notes, the borrowing base under our revolving credit facility was automatically decreased from $1.44 billion to $1.315 billion.
	2014 Equity Offering
	On July 15, 2014, we issued 9,890,000 common units representing limited partner interests in the Partnership (including 1,290,000 common units purchased pursuant to the full exercise of the underwriters’ option to purchase additional common units) to the public at an offering price of $22.25 per unit generating total net proceeds of approximately $220.3 million after deducting underwriting discounts but before offering expenses. The net proceeds from the equity offering, including our general partner’s proportionate capital contribution, were used to repay a portion of the outstanding borrowings under our revolving credit facility.
	Wyoming Acquisition
	On May 5, 2014, we announced that we entered into a definitive purchase and sale agreement with Merit Energy Company, LLC and certain of its affiliates to acquire oil and natural gas liquids properties in Wyoming (the “Wyoming Acquisition”). On May 5, 2014, we paid a deposit of $70.1 million, which is recorded as a component of “Other long-term assets” on our Unaudited Condensed Consolidated and Combined Balance Sheets at June 30, 2014. On July 1, 2014, we consummated the Wyoming Acquisition for an aggregate purchase price of approximately $915.1 million, subject to customary post-closing adjustments. The Wyoming Acquisition has an effective date of April 1, 2014. In conjunction with the closing of the Wyoming Acquisition, the borrowing base under our revolving credit facility increased from $870 million to $1.44 billion. The Wyoming Acquisition was funded with borrowings under our revolving credit facility.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
General	'
	General
	Memorial Production Partners LP (the “Partnership”) is a publicly traded Delaware limited partnership, the common units of which are listed on the NASDAQ Global Market (“NASDAQ”) under the symbol “MEMP.” Unless the context requires otherwise, references to “we,” “us,” “our,” or “the Partnership” are intended to mean the business and operations of Memorial Production Partners LP and its consolidated subsidiaries.
	The Partnership was formed in April 2011 by Memorial Resource Development LLC (“MRD LLC”) to own, acquire and exploit oil and natural gas properties in North America. In January 2014, MRD LLC formed Memorial Resource Development Corp (“MRD”). On June 18, 2014, MRD LLC contributed substantially all of its assets, including its interest in our general partner, to MRD in connection with MRD’s initial public offering. Unless the context requires otherwise, references to “Memorial Resource” refer collectively to MRD and its subsidiaries other than the Partnership. The Partnership is owned 99.9% by its limited partners and 0.1% by its general partner, Memorial Production Partners GP LLC, which is a wholly-owned subsidiary of Memorial Resource. Our general partner is responsible for managing all of the Partnership’s operations and activities.
	We operate in one reportable segment engaged in the acquisition, exploitation, development and production of oil and natural gas properties. Our management evaluates performance based on one reportable business segment as there are not different economic environments within the operation of our oil and natural gas properties. Our business activities are conducted through Memorial Production Operating LLC (“OLLC”), our wholly owned subsidiary, and its wholly-owned subsidiaries. Our assets consist primarily of producing oil and natural gas properties and are located in Texas, Louisiana, Colorado, Wyoming, New Mexico, and offshore Southern California. Most of our oil and natural gas properties are located in large, mature oil and natural gas reservoirs. The Partnership’s properties consist primarily of operated and non-operated working interests in producing and undeveloped leasehold acreage and working interests in identified producing wells (often referred to as wellbore assignments).
	Memorial Production Finance Corporation (“Finance Corp.”), our wholly-owned subsidiary, has no material assets or any liabilities other than as a co-issuer of our debt securities and as a guarantor of certain of our other indebtedness. Its activities will be limited to co-issuing our debt securities and engaging in other activities incidental thereto.
	Memorial Resource was formed by MRD LLC in January 2014 to exploit, develop and acquire natural gas, NGL and oil properties in North America. MRD LLC was a Delaware limited liability company formed in April 2011 by Natural Gas Partners VIII, L.P., Natural Gas Partners IX, L.P. and NGP IX Offshore Holdings, L.P. (collectively, the “Funds”) to own, acquire, exploit and develop oil and natural gas properties and to own our general partner. In June 2014, (i) the Funds contributed all of their interests in MRD LLC to MRD Holdco LLC (“MRD Holdco”), after which MRD Holdco owned 100% of MRD LLC, and (ii) MRD LLC distributed certain assets, including all of our subordinated units, to MRD Holdco. On June 27, 2014, MRD LLC merged into MRD Operating LLC, a subsidiary of MRD. Memorial Resource provides management, administrative, and operations personnel to us and our general partner under an omnibus agreement (see Note 12). The Funds are private equity funds managed by Natural Gas Partners (“NGP”). The Funds collectively indirectly own 50% of our incentive distribution rights (“IDRs”). The remaining IDRs are owned by our general partner.
	References to “the previous owners” for accounting and financial reporting purposes refer collectively to: (i) certain oil and natural gas properties and related assets in East Texas and North Louisiana that the Partnership acquired in March 2013 (the “WHT Properties”) owned by WHT Energy Partners LLC (“WHT”) from February 2, 2011 (inception) through the date of acquisition, and (ii) certain oil and natural gas properties and related assets primarily in the Permian Basin, East Texas and the Rockies that the Partnership acquired through equity and asset transactions on October 1, 2013, which we refer to collectively as the “Cinco Group acquisition,” from MRD LLC and certain affiliates of NGP.
	Each of these acquisitions was accounted for as a transaction between entities under common control, similar to a pooling of interests, whereby the net assets acquired were recorded at historical cost and certain financial and other information has been retrospectively revised to give effect to such acquisitions as if the Partnership owned the assets for periods after common control commenced through their respective acquisition dates. The WHT Properties represent additional working interests in properties that we originally acquired in December 2011 in conjunction with our initial public offering. See Note 12 for additional information regarding these common control transactions.
Basis of Presentation	'
	Basis of Presentation
	Our consolidated results of operations are presented together with the combined results of operations pertaining to the previous owners. The combined financial statements of the previous owners were derived from their historical accounting records and reflect their historical financial position, results of operations and cash flows.
	The ownership interest of the noncontrolling shareholder in the San Pedro Bay Pipeline Company (“SPBPC”), an indirect majority-owned subsidiary of the Partnership, is presented as a noncontrolling interest in the financial statements.
	Our results of operations for the three and six months ended June 30, 2014 are not necessarily indicative of results expected for the full year. In our opinion, the accompanying unaudited condensed consolidated and combined financial statements include all adjustments of a normal recurring nature necessary for fair presentation. Although we believe the disclosures in these financial statements are adequate and make the information presented not misleading, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted pursuant to the rules and regulations of the United States Securities and Exchange Commission (“SEC”). These unaudited condensed consolidated and combined financial statements and the notes thereto should be read in conjunction with the audited consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2013 (the “2013 Form 10-K”).
	All material intercompany transactions and balances have been eliminated in preparation of our consolidated and combined financial statements.
Use of Estimates	'
	Use of Estimates
	The preparation of the accompanying unaudited condensed consolidated and combined financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated and combined financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Significant estimates include, but are not limited to, oil and natural gas reserves; depreciation, depletion, and amortization of proved oil and natural gas properties; future cash flows from oil and natural gas properties; impairment of long-lived assets; fair value of derivatives; fair value of equity compensation; fair values of assets acquired and liabilities assumed in business combinations and asset retirement obligations.
Current Liabilities - Accrued liabilities	'
	Current Liabilities – Accrued liabilities
	Current accrued liabilities consisted of the following at the dates indicated (in thousands):
		June 30,		December 31,
		2014		2013
	Accrued capital expenditures	$	28,627	$	16,193
	Accrued lease operating expense		9,509		10,666
	Accrued general and administrative expenses		688		1,547
	Accrued ad valorem taxes		4,778		1,531
	Accrued interest payable		8,923		8,931
	Environmental liability		698		437
	Other		1,232		542
		$	54,455	$	39,847
New Accounting Pronouncements	'
	New Accounting Pronouncements
	Revenue from Contracts with Customers. In May 2014, the FASB issued a comprehensive new revenue recognition standard for contracts with customers that will supersede most current revenue recognition guidance, including industry-specific guidance. The core principle of this standard is that an entity should recognize 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. To achieve this core principle, the standard provides a five-step analysis of transactions to determine when and how revenue is recognized. Other major provisions include the capitalization and amortization of certain contract costs, ensuring the time value of money is considered in the transaction price, and allowing estimates of variable consideration to be recognized before contingencies are resolved in certain circumstances. This guidance also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from an entity’s contracts with customers. The new standard is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early application is prohibited. The standard permits the use of either the retrospective or cumulative effect transition method. This guidance will be applicable to the Partnership beginning on January 1, 2017. The Partnership is currently assessing the impact that adopting this new accounting guidance will have on its consolidated financial statements and footnote disclosures.
	Reporting Discontinued Operations. In April 2014, the FASB issued an accounting standards update that changes the criteria for determining when disposals can be presented as discontinued operations and modifies discontinued operations disclosures. The new guidance now defines a “discontinued operation” as (i) a disposal of a component or group of components that is disposed of or is classified as held for sale and “represents a strategic shift that has (or will have) a major effect on an entity’s operations and financial results” or (ii) an acquired business or nonprofit activity that is classified as held for sale on the date of acquisition. We will adopt this guidance and apply the disclosure requirements prospectively beginning on January 1, 2015.
	Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Partnership’s financial position, results of operations and cash flows.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Summary of Current Accrued Liabilities	'
	Current accrued liabilities consisted of the following at the dates indicated (in thousands):
		June 30,		December 31,
		2014		2013
	Accrued capital expenditures	$	28,627	$	16,193
	Accrued lease operating expense		9,509		10,666
	Accrued general and administrative expenses		688		1,547
	Accrued ad valorem taxes		4,778		1,531
	Accrued interest payable		8,923		8,931
	Environmental liability		698		437
	Other		1,232		542
		$	54,455	$	39,847

Acquisitions_and_Divestitures_

Acquisitions and Divestitures (Tables)	6 Months Ended
	Jun. 30, 2014
Acquisition-Related Costs	'
	Acquisition-related costs. Acquisition-related costs for both related party and third party transactions are included in general and administrative expenses in the accompanying statements of operations for the periods indicated below (in thousands):
	For the Three Months								For the Six Months
	Ended June 30,								Ended June 30,
	2014				2013				2014				2013
	$	1,093			$	897			$	2,987			$	1,112
Supplemental Pro Forma Information	'
			For the Three Months								For the Six Months
			Ended June 30,								Ended June 30,
			2014				2013				2014				2013
			(In thousands, except per unit amounts)
	Revenues		$	123,310			$	104,050			$	233,553			$	184,911
	Net income (loss)			(114,206)				59,775				(144,054)				61,887
	Basic and diluted earnings per unit			(1.86)				1.20				(2.35)				1.38
Eagle Ford Acquisition [Member]	'
Summary of Fair Value Assessment of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the preliminary fair value assessment of the assets acquired and liabilities assumed as of the acquisition date (in thousands):
			Eagle Ford
			Acquisition
	Oil and gas properties		$	169,656
	Asset retirement obligations			(285)
	Accrued liabilities			(250)
	Total identifiable net assets		$	169,121

Fair_Value_Measurements_of_Fin1

Fair Value Measurements of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Assets and Liabilities Measured at Fair Value on Recurring Basis	'
	The following table presents the gross derivative assets and liabilities that are measured at fair value on a recurring basis at June 30, 2014 and December 31, 2013 for each of the fair value hierarchy levels:
		Fair Value Measurements at June 30, 2014 Using
		Quoted Prices in			Significant Other		Significant		Fair Value
							Unobservable Inputs
		Active Market			Observable Inputs
							(Level 3)
		(Level 1)			(Level 2)
			(In thousands)
	Assets:
	Commodity derivatives		$	--	$	47,256	$	--	$	47,256
	Interest rate derivatives			--		11		--		11
	Total assets			--	$	47,267		--	$	47,267
	Liabilities:
	Commodity derivatives		$	--	$	176,143	$	--	$	176,143
	Interest rate derivatives			--		4,423		--		4,423
	Total liabilities		$	--	$	180,566	$	--	$	180,566
		Fair Value Measurements at December 31, 2013 Using
		Quoted Prices in			Significant Other		Significant		Fair Value
							Unobservable Inputs
		Active Market			Observable Inputs
							(Level 3)
		(Level 1)			(Level 2)
			(In thousands)
	Assets:
	Commodity derivatives		$	--	$	95,926	$	--	$	95,926
	Interest rate derivatives			--		872		--		872
	Total assets		$	--	$	96,798	$	--	$	96,798
	Liabilities:
	Commodity derivatives		$	--	$	55,576	$	--	$	55,576
	Interest rate derivatives			--		4,836		--		4,836
	Total liabilities		$	--	$	60,412	$	--	$	60,412

Risk_Management_and_Derivative1

Risk Management and Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]	'
Open Commodity Positions	'
	At June 30, 2014, we had the following open commodity positions:
		Remaining				2015				2016				2017				2018		2019
		2014
	Natural Gas Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (MMBtu)		2,626,033				2,605,278				2,692,442				2,450,067				2,160,000		1,914,583
	Weighted-average fixed price	$	4.33			$	4.28			$	4.4			$	4.31			$	4.51	$	4.75
	Collar contracts:
	Average Monthly Volume (MMBtu)		340,000				350,000				--				--				--		--
	Weighted-average floor price	$	5			$	4.62			$	--			$	--			$	--	$	--
	Weighted-average ceiling price	$	6.31			$	5.8			$	--			$	--			$	--	$	--
	Call spreads (1):
	Average Monthly Volume (MMBtu)		120,000				80,000				--				--				--		--
	Weighted-average sold strike price	$	5.17			$	5.25			$	--			$	--			$	--	$	--
	Weighted-average bought strike price	$	6.53			$	6.75			$	--			$	--			$	--	$	--
	Basis swaps:
	Average Monthly Volume (MMBtu)		2,875,833				2,940,000				600,000				--				--		--
	Spread	$	-0.09			$	-0.12			$	-0.1			$	--			$	--	$	--
	Crude Oil Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (Bbls)		285,285				314,281				300,313				286,600				272,000		60,000
	Weighted-average fixed price	$	95.8			$	90.96			$	85.44			$	83.96			$	83.24	$	83.33
	Collar contracts:
	Average Monthly Volume (Bbls)		23,000				5,000				--				--				--		--
	Weighted-average floor price	$	82.83			$	80			$	--			$	--			$	--	$	--
	Weighted-average ceiling price	$	105.31			$	94			$	--			$	--			$	--	$	--
	Basis swaps:
	Average Monthly Volume (Bbls)		134,000				97,500				--				--				--		--
	Spread	$	-4.32			$	-7.07			$	--			$	--			$	--	$	--
	NGL Derivative Contracts:
	Fixed price swap contracts:
	Average Monthly Volume (Bbls)		171,000				149,200				--				--				--		--
	Weighted-average fixed price	$	42.96			$	43.02			$	--			$	--			$	--	$	--
	(1)    These transactions were entered into for the purpose of eliminating the ceiling portion of certain collar arrangements, which effectively converted the applicable collars into swaps.
Interest Rate Swap Open Positions	'
	At June 30, 2014, we had the following interest rate swap open positions:
		Remaining				2015				2016
		2014
	Average Monthly Notional (in thousands)		$          236,667				$          280,833				$          150,000
	Weighted-average fixed rate		1.32%				1.42%				1.19%
	Floating rate		1 Month LIBOR				1 Month LIBOR				1 Month LIBOR
Gross Fair Value of Derivative Instruments by Appropriate Balance Sheet	'
	The following table summarizes both: (i) the gross fair value of derivative instruments by the appropriate balance sheet classification even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the balance sheet and (ii) the net recorded fair value as reflected on the balance sheet at June 30, 2014 and December 31, 2013. There was no cash collateral received or pledged associated with our derivative instruments since most of the counterparties, or certain of their affiliates, to our derivative contracts are lenders under our credit agreement.
				Asset Derivatives								Liability Derivatives
				June 30,				December 31,				June 30,				December 31,
	Type	Balance Sheet Location		2014				2013				2014				2013
				(In thousands)
	Commodity contracts	Short-term derivative instruments		$	10,425			$	18,578			$	50,721			$	17,120
	Interest rate swaps	Short-term derivative instruments			--				845				3,456				2,699
	Gross fair value				10,425				19,423				54,177				19,819
	Netting arrangements	Short-term derivative instruments			(8,989)				(11,823)				(8,989)				(11,823)
	Net recorded fair value	Short-term derivative instruments		$	1,436			$	7,600			$	45,188			$	7,996
	Commodity contracts	Long-term derivative instruments		$	36,831			$	77,348			$	125,422			$	38,456
	Interest rate swaps	Long-term derivative instruments			11				27				967				2,137
	Gross fair value				36,842				77,375				126,389				40,593
	Netting arrangements	Long-term derivative instruments			(35,693)				(34,718)				(35,693)				(34,718)
	Net recorded fair value	Long-term derivative instruments		$	1,149			$	42,657			$	90,696			$	5,875
Unrealized and Realized Gains and Losses Related to Derivative Instruments	'
	The following table details the gains and losses related to derivative instruments for the three and six months ended June 30, 2014 and 2013 (in thousands):
				For the Three Months								For the Six Months
				Ended June 30,								Ended June 30,
		Statements of		2014				2013				2014				2013
		Operations Location
	Commodity derivative contracts	(Gain) loss on commodity derivatives		$	138,346			$	(36,079)			$	185,112			$	(23,010)
	Interest rate derivatives	Interest expense, net			776				(1,677)				1,091				(1,670)

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Summary of Changes in Asset Retirement Obligations	'
	The following table presents the changes in the asset retirement obligations for the six months ended June 30, 2014 (in thousands):
	Asset retirement obligations at beginning of period	$	99,619
	Liabilities added from acquisitions or drilling		1,448
	Revisions		66
	Liabilities settled		(343)
	Accretion expense		2,723
	Asset retirement obligations at end of period	$	103,513

Restricted_Investments_Tables

Restricted Investments (Tables)	6 Months Ended
	Jun. 30, 2014
Text Block [Abstract]	'
Restricted Investment Balance	'
	The components of the restricted investment balance consisted of the following at the dates indicated:
		June 30,		December 31,
		2014		2013
		(In thousands)
	BOEM platform abandonment (See Note 13)	$	68,313	$	66,373
	BOEM lease bonds		794		794
	SPBPC Collateral:
	Contractual pipeline and surface facilities abandonment		2,487		2,306
	California State Lands Commission pipeline right-of-way bond		3,005		3,005
	City of Long Beach pipeline facility permit		500		500
	Federal pipeline right-of-way bond		307		307
	Port of Long Beach pipeline license		100		100
	Restricted investments	$	75,506	$	73,385

Long_Term_Debt_Tables

Long Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Consolidated and Combined Debt Obligations	'
	The following table presents our consolidated and combined debt obligations at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	459,000	$	103,000
	2021 Senior Notes, fixed-rate, due May 2021 (1)			700,000		700,000
	Unamortized discounts			(10,194)		(10,933)
	Total long-term debt		$	1,148,806	$	792,067
	(1)	The estimated fair value of our fixed-rate debt was $735.0 million and $721.0 million at June 30, 2014 and December 31, 2013, respectively. The estimated fair value is based on quoted market prices and is classified as Level 2 within the fair value hierarchy.
Borrowing Base Credit Facility	'
	The borrowing base for our credit facility was the following at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	870,000	$	845,000
Summary of Weighted-Average Interest Rates Paid On Variable-Rate Debt Obligations	'
	The following table presents the weighted-average interest rates paid on our consolidated and combined variable-rate debt obligations for the periods presented:
			For the Three Months				For the Six Months
			Ended June 30,				Ended June 30,
			2014		2013		2014		2013
	OLLC revolving credit facility			2.46%		3.31%		2.70%		2.98%
	WHT revolving credit facility			n/a		n/a		n/a		1.11%
	Stanolind revolving credit facility			n/a		3.79%		n/a		3.56%
	Boaz revolving credit facility			n/a		2.89%		n/a		3.07%
	Crown revolving credit facility			n/a		3.50%		n/a		3.41%
	Tanos revolving credit facility			n/a		n/a		n/a		2.12%
	Propel Energy revolving credit facility			n/a		2.89%		n/a		3.08%
Summary of Unamortized Deferred Financing Costs Associated with Consolidated Debt Obligations	'
	Unamortized deferred financing costs associated with our consolidated debt obligations were as follows at the dates indicated:
			June 30,		December 31,
			2014		2013
			(In thousands)
	OLLC $2.0 billion revolving credit facility, variable-rate, due March 2018		$	5,019	$	5,413
	2021 Senior Notes (1)			14,335		15,053
	(1)    Unamortized deferred financing costs are amortized using the straight line method which approximates the effective interest method.
Advances and Repayments	'
	The following table presents borrowings and repayments under our consolidated and combined revolving credit facilities for the periods presented (in thousands):
			OLLC Revolving		Previous Owner		Total
			Credit Facility		Revolving
					Credit Facility
	For the Six Months Ended June 30, 2014:
	Advances on revolving credit facility			$          418,000	$	--	$	418,000
	Payments on revolving credit facility			(62,000)		--		-62,000
	For the Six Months Ended June 30, 2013:
	Advances on revolving credit facility			$          237,000	$	14,250	$	251,250
	Payments on revolving credit facility			(569,000)		-122,702		-691,702

Equity_Distributions_Tables

Equity & Distributions (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Summary of Changes in Number of Outstanding Units	'
	The following table summarizes changes in the number of outstanding units since December 31, 2013:
			Common			Subordinated				General
										Partner
	Balance December 31, 2013			55,877,831			5,360,912				61,300
	Common units issued			--			--				--
	Restricted common units issued			669,898			--				--
	Restricted common units forfeited			(8,863)			--				--
	Restricted common units repurchased (1)			(41,679)			--				--
	General partner units issued			--			--				620
	Balance June 30, 2014			56,497,187			5,360,912				61,920
	(1)    Restricted common units are generally net-settled by unitholders to cover the required withholding tax upon vesting. Unitholders surrendered units with value equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes. Total payments remitted for the employees’ tax obligations to the appropriate taxing authorities were approximately $0.9 million. These net-settlements had the effect of unit repurchases by the Partnership as they reduced the number of units that would have otherwise been outstanding as a result of the vesting and did not represent an expense to the Partnership.
Summary of Quarterly Cash Distribution Rates	'
	The following table summarizes our declared quarterly cash distribution rates with respect to the quarter indicated (dollars in millions, except per unit amounts):
	Quarter		Declaration Date		Record Date	Payable Date		Amount				Aggregate		Distribution
								Per Unit				Distribution		Received by
														Affiliates (2)
	2nd Quarter 2014 (1)		24-Jul-14		5-Aug-14	12-Aug-14		$	0.55			$	39.5	$	3.0
	1st Quarter 2014		24-Apr-14		6-May-14	13-May-14		$	0.55			$	33.8	$	3.0
	4th Quarter 2013		27-Jan-14		6-Feb-14	13-Feb-14		$	0.55			$	33.8	$	3.0
	3rd Quarter 2013		22-Oct-13		1-Nov-13	12-Nov-13		$	0.55			$	33.8	$	6.9
	2nd Quarter 2013		18-Jul-13		1-Aug-13	12-Aug-13		$	0.5125			$	22.9	$	6.4
	1st Quarter 2013		18-Apr-13		1-May-13	13-May-13		$	0.5125			$	22.6	$	6.4
	4th Quarter 2012		15-Jan-13		1-Feb-13	13-Feb-13		$	0.5075			$	17.4	$	6.3
	(1)	Distributions paid on August 12, 2014 will include distributions paid on 9,890,000 common units which were issued on July 15, 2014. See Note 14 for more information regarding the equity offering.
	(2)	In June 2014, MRD LLC distributed all of our subordinated units to MRD Holdco. See Note 1 for additional information.

Earnings_per_Unit_Tables

Earnings per Unit (Tables)	6 Months Ended
	Jun. 30, 2014
Calculation of Earnings (Loss) Per Unit	'
	The following sets forth the calculation of earnings (loss) per unit, or EPU, for the periods indicated (in thousands, except per unit amounts):
		For the Three Months				For the Six Months
		Ended June 30,				Ended June 30,
		2014		2013		2014		2013
	Net income (loss) attributable to Memorial Production Partners LP	$	(114,194)	$	52,597	$	(148,306)	$	48,304
	Less: Previous owners interest in net income (loss)		--		6,418		--		7,147
	Less: General partner’s 0.1% interest in net income (loss)		(114)		46		(148)		41
	Less: IDRs attributable to corresponding period		47		--		87		--
	Net income (loss) available to limited partners	$	(114,127)	$	46,133	$	(148,245)	$	41,116
	Weighted average limited partner units outstanding:
	Common units		56,103		38,870		55,997		34,307
	Subordinated units		5,361		5,361		5,361		5,361
	Total		61,464		44,231		61,358		39,668
	Basic and diluted EPU	$	(1.86)	$	1.04	$	(2.42)	$	1.04
Supplemental EPU [Member]	'
Calculation of Earnings (Loss) Per Unit	'
	The following sets forth the calculation of our supplemental EPU, for the periods indicated (in thousands, except per unit amounts):
		For the Three Months				For the Six Months
		Ended June 30,				Ended June 30,
		2014		2013		2014		2013
	Net income (loss) attributable to Memorial Production Partners LP	$	(114,194)	$	52,597	$	(148,306)	$	48,304
	Less: General partner’s 0.1% interest in net income (loss)		(114)		46		(148)		41
	Less: IDRs attributable to corresponding period		47		--		87		--
	Net income (loss) available to limited partners	$	(114,127)	$	52,551	$	(148,245)	$	48,263
	Weighted average limited partner units outstanding:
	Common units		56,103		38,870		55,997		34,307
	Subordinated units		5,361		5,361		5,361		5,361
	Total		61,464		44,231		61,358		39,668
	Supplemental basic and diluted EPU	$	(1.86)	$	1.19	$	(2.42)	$	1.22

Equitybased_Awards_Tables

Equity-based Awards (Tables)	6 Months Ended
	Jun. 30, 2014
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'
Summary of Information Regarding Restricted Common Unit Awards	'
	The following table summarizes information regarding restricted common unit awards granted under the Memorial Production Partners GP LLC Long-Term Incentive Plan (“LTIP”) for the periods presented:
			Number of Units			Weighted-
						Average Grant
						Date Fair Value
						per Unit (1)
	Restricted common units outstanding at December 31, 2013			706,927		$	18.62
	Granted (2)			669,898		$	22.36
	Forfeited			(8,863)		$	18.57
	Vested			(256,130)		$	18.57
	Restricted common units outstanding at June 30, 2014			1,111,832		$	20.89
	(1)    Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
	(2)    The aggregate grant date fair value of restricted common unit awards issued in 2014 was $15.0 million based on a grant date market price range of $21.99 - $22.37 per unit.
Summary of Amount of Compensation Expense Recognized	'
	The following table summarizes the amount of recognized compensation expense associated with these awards that are reflected in the accompanying statements of operations for the periods presented (in thousands):
	For the Three Months					For the Six Months
	Ended June 30,					Ended June 30,
	2014				2013	2014		2013
	$	1,665			$            663		$  2,960		$1,085

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Schedule of Net Assets Recorded by Partnership	'
	The Partnership recorded the following net assets (in thousands):
	Cash and cash equivalents		$	1,354
	Accounts receivable			3,866
	Short-term derivative instruments, net			1,206
	Prepaid expenses and other current assets			98
	Oil and natural gas properties, net			192,280
	Long-term derivative instruments, net			3,528
	Accrued liabilities			(3,494)
	Asset retirement obligations			(2,753)
	Credit facilities			(89,300)
	Other long-term liabilities			(111)
	Net assets		$	106,674
Omnibus Agreement [Member]	'
Schedule of Amount of General and Administrative Costs and Expenses Recognized	'
	The following table summarizes the amount of general and administrative expenses recognized under the omnibus agreement that are reflected in the accompanying statements of operations for the periods presented (in thousands):
	For the Three Months						For the Six Months
	Ended June 30,						Ended June 30,
	2014				2013		2014		2013
	$	5,411			$	1,766	$	10,259	$	3,251
Double A Acquisition [Member]	'
Schedule of Net Assets Recorded by Partnership	'
	The Partnership recorded the following net assets (in thousands):
			Double A
			Acquisition
	Oil and gas properties, net		$	37,838
	Asset retirement obligations			(908)
	Other current liabilities			(722)
	Total identifiable net assets		$	36,208

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Gross Held-to-Maturity Investments	'
	The following is a summary of the gross held-to-maturity investments held in the trust account less the outside working interest owners share as of June 30, 2014 (in thousands):
	Investment	Amortized
		Cost
	U.S. Bank Money Market Cash Equivalent	$	132,003
	Less: Outside working interest owners share		(63,690)
		$	68,313
Minimum Balances Attributable to Net Working Interest	'
	The trust account must maintain minimum balances attributable to REO’s net working interest as follows (in thousands):
	June 30, 2014	$	68,310
	June 30, 2015	$	72,450
	June 30, 2016	$	76,590
	December 31, 2016	$	78,660

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation - Additional Information (Detail)	Jun. 30, 2014
MRD Holdco [Member]	'
Organization And Basis Of Presentation Textual [Abstract]	'
Affiliate's ownership percentage in our former parent	100.00%
The Funds [Member]	'
Organization And Basis Of Presentation Textual [Abstract]	'
Percentage ownership in incentive distribution rights	50.00%
Limited Partners Common Units [Member]	'
Organization And Basis Of Presentation Textual [Abstract]	'
Partnership ownership percentage	99.90%
General Partner [Member]	'
Organization And Basis Of Presentation Textual [Abstract]	'
Partnership ownership percentage	0.10%
General Partner [Member] | The Funds [Member]	'
Organization And Basis Of Presentation Textual [Abstract]	'
Percentage ownership in incentive distribution rights	50.00%

Summary_of_Significant_Account2

Summary of Significant Accounting Policies - Summary of Current Accrued Liabilities (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accrued Liabilities Current [Abstract]	'	'
Accrued capital expenditures	$28,627	$16,193
Accrued lease operating expense	9,509	10,666
Accrued general and administrative expenses	688	1,547
Accrued ad valorem taxes	4,778	1,531
Accrued interest payable	8,923	8,931
Environmental liability	698	437
Other	1,232	542
Accrued liabilities, Total	$54,455	$39,847

Acquisitions_and_Divestitures_1

Acquisitions and Divestitures - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended	3 Months Ended	6 Months Ended	0 Months Ended			6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2013	Jan. 01, 2013	Jan. 01, 2013	Jan. 01, 2013	Jun. 30, 2013
	Eagle Ford [Member]	Eagle Ford [Member]	Eagle Ford [Member]	Eagle Ford [Member]	Hendrick Field [Member]	Tanos [Member]	Tanos [Member]	Tanos [Member]	Tanos [Member]
				Leasehold [Member]	Oil and Gas Properties [Member]			Minimum [Member]	Non Operated Oil And Gas Properties [Member]
Business Acquisition And Divestiture [Line Items]	'	'	'	'	'	'	'	'	'
Purchase price	'	$169.10	'	'	$6.30	'	'	'	'
Percentage of leasehold interest acquired	'	'	'	30.00%	'	'	'	'	'
Revenue recorded in statement of operations	13.4	'	14.4	'	'	'	'	'	'
Earnings recorded in statement of operations	7.4	'	8	'	'	'	'	'	'
Assets sold	'	'	'	'	'	'	'	1.5	'
Maximum allowable additional proceeds	'	'	'	'	'	'	2	'	'
Aggregate gain of acquisition	'	'	'	'	'	1.4	'	'	1.4
Contingent consideration	'	'	'	'	'	'	0.4	'	'
Asset sold	'	'	'	'	'	'	'	'	$2.90

Acquisitions_and_Divestitures_2

Acquisitions and Divestitures - Summary of Fair Value of Assets Acquired and Liabilities Assumed in Eagle Ford Acquisition (Detail) (Eagle Ford Acquisition [Member], USD $)	Mar. 31, 2014
In Thousands, unless otherwise specified
Eagle Ford Acquisition [Member]	'
Business Acquisition [Line Items]	'
Oil and gas properties	$169,656
Asset retirement obligations	-285
Accrued liabilities	-250
Total identifiable net assets	$169,121

Acquisitions_and_Divestitures_3

Acquisitions and Divestitures - Acquisition-Related Costs (Detail) (General and Administrative Expenses [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
General and Administrative Expenses [Member]	'	'	'	'
Acquisitions And Divestitures Textual [Abstract]	'	'	'	'
Acquisition-related costs	$1,093	$897	$2,987	$1,112

Acquisitions_and_Divestitures_4

Acquisitions and Divestitures - Supplemental Pro Forma Information (Detail) (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
Business Acquisition Pro Forma Information [Abstract]	'	'	'	'
Revenues	$123,310	$104,050	$233,553	$184,911
Net income (loss)	($114,206)	$59,775	($144,054)	$61,887
Basic and diluted earnings per unit	($1.86)	$1.20	($2.35)	$1.38

Fair_Value_Measurements_of_Fin2

Fair Value Measurements of Financial Instruments - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (Fair Value [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	$47,267	$96,798
Liabilities	180,566	60,412
Interest rate derivatives [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	11	872
Liabilities	4,423	4,836
Quoted Prices in Active Market (Level 1) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	0	0
Quoted Prices in Active Market (Level 1) [Member] | Interest rate derivatives [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	0	0
Significant Other Observable Inputs (Level 2) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	47,267	96,798
Liabilities	180,566	60,412
Significant Other Observable Inputs (Level 2) [Member] | Interest rate derivatives [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	11	872
Liabilities	4,423	4,836
Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	0	0
Significant Unobservable Inputs (Level 3) [Member] | Interest rate derivatives [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	0	0
Commodity derivatives [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	47,256	95,926
Liabilities	176,143	55,576
Commodity derivatives [Member] | Quoted Prices in Active Market (Level 1) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	0	0
Commodity derivatives [Member] | Significant Other Observable Inputs (Level 2) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	47,256	95,926
Liabilities	176,143	55,576
Commodity derivatives [Member] | Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]	'	'
Assets	0	0
Liabilities	$0	$0

Risk_Management_and_Derivative2

Risk Management and Derivative Instruments - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Concentration Risks, Types, No Concentration Percentage [Abstract]	'
Conditional rights of set-off under ISDA Master Agreement reduce the maximum amount of loss due to credit risk	$1.70

Risk_Management_and_Derivative3

Risk Management and Derivative Instruments - Open Commodity Positions (Detail)	6 Months Ended
	Jun. 30, 2014
	MMBTU
Remaining 2014 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,626,033
Weighted-average fixed price	4.33
Remaining 2014 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	340,000
Weighted-average floor price	5
Weighted-average ceiling price	6.31
Remaining 2014 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	120,000
Weighted-average sold strike price	5.17
Weighted-average bought strike price	6.53
Remaining 2014 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,875,833
Spread	-0.09
Remaining 2014 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	285,285
Weighted-average fixed price	95.8
Remaining 2014 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	23,000
Weighted-average floor price	82.83
Weighted-average ceiling price	105.31
Remaining 2014 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	134,000
Spread	-4.32
Remaining 2014 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	171,000
Weighted-average fixed price	42.96
2015 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,605,278
Weighted-average fixed price	4.28
2015 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	350,000
Weighted-average floor price	4.62
Weighted-average ceiling price	5.8
2015 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	80,000
Weighted-average sold strike price	5.25
Weighted-average bought strike price	6.75
2015 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,940,000
Spread	-0.12
2015 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	314,281
Weighted-average fixed price	90.96
2015 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	5,000
Weighted-average floor price	80
Weighted-average ceiling price	94
2015 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	97,500
Spread	-7.07
2015 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	149,200
Weighted-average fixed price	43.02
2016 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,692,442
Weighted-average fixed price	4.4
2016 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2016 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average sold strike price	0
Weighted-average bought strike price	0
2016 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	600,000
Spread	-0.1
2016 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	300,313
Weighted-average fixed price	85.44
2016 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2016 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Spread	0
2016 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average fixed price	0
2017 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,450,067
Weighted-average fixed price	4.31
2017 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2017 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average sold strike price	0
Weighted-average bought strike price	0
2017 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Spread	0
2017 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	286,600
Weighted-average fixed price	83.96
2017 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2017 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Spread	0
2017 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average fixed price	0
2018 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	2,160,000
Weighted-average fixed price	4.51
2018 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2018 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average sold strike price	0
Weighted-average bought strike price	0
2018 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Spread	0
2018 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	272,000
Weighted-average fixed price	83.24
2018 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2018 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Spread	0
2018 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average fixed price	0
2019 [Member] | Natural Gas Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	1,914,583
Weighted-average fixed price	4.75
2019 [Member] | Natural Gas Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2019 [Member] | Natural Gas Derivative Contracts Call Spreads [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Weighted-average sold strike price	0
Weighted-average bought strike price	0
2019 [Member] | Natural Gas Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (MMBtu)	0
Spread	0
2019 [Member] | Crude Oil Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	60,000
Weighted-average fixed price	83.33
2019 [Member] | Crude Oil Derivative Contracts Collar Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average floor price	0
Weighted-average ceiling price	0
2019 [Member] | Crude Oil Derivative Contracts Basis Swaps [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Spread	0
2019 [Member] | NGL Derivative Contracts Fixed Price Swap Contracts [Member]	'
Combination Of Commodity Derivatives To Manage Exposure To Commodity Price Volatility [Abstract]	'
Average Monthly Volume (Bbls)	0
Weighted-average fixed price	0

Risk_Management_and_Derivative4

Risk Management and Derivative Instruments - Interest Rate Swap Open Positions (Detail) (Interest rate swaps [Member], USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Remaining 2014 [Member]	'
Derivative [Line Items]	'
Average Monthly Notional	$236,667
Weighted-average fixed rate	1.32%
Floating rate	'1 Month LIBOR
2015 [Member]	'
Derivative [Line Items]	'
Average Monthly Notional	280,833
Weighted-average fixed rate	1.42%
Floating rate	'1 Month LIBOR
2016 [Member]	'
Derivative [Line Items]	'
Average Monthly Notional	$150,000
Weighted-average fixed rate	1.19%
Floating rate	'1 Month LIBOR

Risk_Management_and_Derivative5

Risk Management and Derivative Instruments - Gross Fair Value of Derivative Instruments by Appropriate Balance Sheet (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Net recorded fair value	$1,436	$7,600
Asset Derivatives, Net recorded fair value	1,149	42,657
Liability Derivatives, Net recorded fair value	45,188	7,996
Liability Derivatives, Net recorded fair value	90,696	5,875
Short-Term Derivative Instruments [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	10,425	19,423
Asset Derivatives, Netting arrangements	-8,989	-11,823
Asset Derivatives, Net recorded fair value	1,436	7,600
Liability Derivatives, Gross fair value	54,177	19,819
Liability Derivatives, Netting arrangements	-8,989	-11,823
Liability Derivatives, Net recorded fair value	45,188	7,996
Short-Term Derivative Instruments [Member] | Commodity derivative contracts [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	10,425	18,578
Liability Derivatives, Gross fair value	50,721	17,120
Short-Term Derivative Instruments [Member] | Interest rate swaps [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	0	845
Liability Derivatives, Gross fair value	3,456	2,699
Long-Term Derivative Instruments [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	36,842	77,375
Asset Derivatives, Netting arrangements	-35,693	-34,718
Asset Derivatives, Net recorded fair value	1,149	42,657
Liability Derivatives, Gross fair value	126,389	40,593
Liability Derivatives, Netting arrangements	-35,693	-34,718
Liability Derivatives, Net recorded fair value	90,696	5,875
Long-Term Derivative Instruments [Member] | Commodity derivative contracts [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	36,831	77,348
Liability Derivatives, Gross fair value	125,422	38,456
Long-Term Derivative Instruments [Member] | Interest rate swaps [Member]	'	'
Derivative Instruments and Hedges, Assets [Abstract]	'	'
Asset Derivatives, Gross fair value	11	27
Liability Derivatives, Gross fair value	$967	$2,137

Risk_Management_and_Derivative6

Risk Management and Derivative Instruments - Unrealized and Realized Gains and Losses Related to Derivative Instruments (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Gain (Loss) on Derivative Instruments, Net, Pretax [Abstract]	'	'	'	'
(Gain) loss on commodity derivatives	$138,346	($36,079)	$185,112	($23,010)
Interest expense, net	18,036	7,931	34,114	14,473
Commodity derivative contracts [Member]	'	'	'	'
Gain (Loss) on Derivative Instruments, Net, Pretax [Abstract]	'	'	'	'
(Gain) loss on commodity derivatives	138,346	-36,079	185,112	-23,010
Interest rate derivatives [Member]	'	'	'	'
Gain (Loss) on Derivative Instruments, Net, Pretax [Abstract]	'	'	'	'
Interest expense, net	$776	($1,677)	$1,091	($1,670)

Asset_Retirement_Obligations_S

Asset Retirement Obligations - Summary of Changes in Asset Retirement Obligations (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Asset Retirement Obligation Roll Forward Analysis [Roll Forward]	'	'	'	'
Asset retirement obligations at beginning of period	'	'	$99,619	'
Liabilities added from acquisitions or drilling	'	'	1,448	'
Revisions	'	'	66	'
Liabilities settled	'	'	-343	'
Accretion expense	1,366	1,148	2,723	2,293
Asset retirement obligations at end of period	$103,513	'	$103,513	'

Restricted_Investments_Restric

Restricted Investments - Restricted Investment Balance (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	$75,506	$73,385
BOEM platform abandonment [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	68,313	66,373
BOEM lease bonds [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	794	794
SPBPC Collateral Contractual pipeline and surface facilities abandonment [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	2,487	2,306
SPBPC Collateral California State Lands Commission pipeline right-of-way bond [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	3,005	3,005
SPBPC Collateral City of Long Beach pipeline facility permit [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	500	500
SPBPC Collateral Federal pipeline right-of-way bond [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	307	307
SPBPC Collateral Port of Long Beach pipeline license [Member]	'	'
Restricted Cash and Investments [Abstract]	'	'
Restricted investments	$100	$100

Long_Term_Debt_Consolidated_an

Long Term Debt - Consolidated and Combined Debt Obligations (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Obligations [Abstract]	'	'
Unamortized discounts	($10,194)	($10,933)
Total long-term debt	1,148,806	792,067
OLLC $2.0 billion revolving credit facility [Member]	'	'
Debt Obligations [Abstract]	'	'
Revolving credit facility	459,000	103,000
Secured Senior Notes Due 2021 [Member]	'	'
Debt Obligations [Abstract]	'	'
2021 Senior Notes, fixed-rate, due May 2021	$700,000	$700,000

Long_Term_Debt_Consolidated_an1

Long Term Debt - Consolidated and Combined Debt Obligations (Parenthetical) (Detail) (USD $)	0 Months Ended
	Jun. 30, 2014	Dec. 31, 2013
Debt Obligations [Abstract]	'	'
Senior Notes maturity date	'May 2021	'
Estimated fair value of fixed rate debt	$735,000,000	$721,000,000
OLLC $2.0 billion revolving credit facility [Member]	'	'
Debt Obligations [Abstract]	'	'
Revolving credit facility	$2,000,000,000	'

Long_Term_Debt_Additional_Info

Long Term Debt - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Oct. 10, 2013	23-May-13	Apr. 17, 2013	Jun. 30, 2014
	Secured Senior Notes Due 2021 [Member]	Private Placement of Debt [Member]	Private Placement of Debt [Member]	Private Placement of Debt [Member]	Universal Shelf Registration Statement [Member]
		Secured Senior Notes Due 2021 [Member]	Secured Senior Notes Due 2021 [Member]	Secured Senior Notes Due 2021 [Member]
Line of Credit Facility [Line Items]	'	'	'	'	'
Universal shelf guarantor subsidiaries ownership percentage	'	'	'	'	100.00%
7.625% senior unsecured notes maturity period	1-May-21	'	'	'	'
Face amount of 7.625% Senior Notes due 2021 at time of issuance	'	$300	$100	$300	'
Other events of default minimum note holder percentage to accelerate	25.00%	'	'	'	'
Senior notes	7.63%	'	'	'	'

Long_Term_Debt_Borrowing_Base_

Long Term Debt - Borrowing Base Credit Facility (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Line of Credit Facility [Line Items]	'	'
Borrowing Base	$870,000	'
OLLC $2.0 billion revolving credit facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Borrowing Base	$870,000	$845,000

Long_Term_Debt_Borrowing_Base_1

Long Term Debt - Borrowing Base Credit Facility (Parenthetical) (Detail) (OLLC $2.0 billion revolving credit facility [Member], USD $)	Jun. 30, 2014
In Billions, unless otherwise specified
OLLC $2.0 billion revolving credit facility [Member]	'
Line of Credit Facility [Line Items]	'
Revolving credit facility	$2

Long_Term_Debt_Summary_of_Weig

Long Term Debt - Summary of Weighted-Average Interest Rates Paid on Variable-Rate Debt Obligations (Detail)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
OLLC Revolving Credit Facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	2.46%	3.31%	2.70%	2.98%
WHT revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	'	'	1.11%
Stanolind revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	3.79%	'	3.56%
Boaz revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	2.89%	'	3.07%
Crown revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	3.50%	'	3.41%
Tanos revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	'	'	2.12%
Propel Energy revolving credit facility [Member]	'	'	'	'
Credit Facilities [Line Items]	'	'	'	'
Revolving credit facility, weighted-average interest rates	'	2.89%	'	3.08%

Long_Term_Debt_Summary_of_Unam

Long Term Debt - Summary of Unamortized Deferred Financing Costs Associated with Consolidated Debt Obligations (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
OLLC $2.0 billion revolving credit facility [Member]	'	'
Credit Facilities [Line Items]	'	'
Unamortized deferred financing costs	$5,019	$5,413
Senior Notes [Member]	'	'
Credit Facilities [Line Items]	'	'
Unamortized deferred financing costs	$14,335	$15,053

Long_Term_Debt_Summary_of_Unam1

Long Term Debt - Summary of Unamortized Deferred Financing Costs Associated with Consolidated Debt Obligations (Parenthetical) (Detail) (OLLC $2.0 billion revolving credit facility [Member], USD $)	Jun. 30, 2014
In Billions, unless otherwise specified
OLLC $2.0 billion revolving credit facility [Member]	'
Credit Facilities [Line Items]	'
Revolving credit facility	$2

Long_Term_Debt_Advances_and_Re

Long Term Debt - Advances and Repayments (Detail) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Credit Facilities [Line Items]	'	'
Advances on revolving credit facility	$418,000	$251,250
Payments on revolving credit facility	-62,000	-691,702
OLLC Revolving Credit Facility [Member]	'	'
Credit Facilities [Line Items]	'	'
Advances on revolving credit facility	418,000	237,000
Payments on revolving credit facility	-62,000	-569,000
Previous Owners Revolving Credit Facility [Member]	'	'
Credit Facilities [Line Items]	'	'
Advances on revolving credit facility	'	14,250
Payments on revolving credit facility	'	($122,702)

Equity_Distributions_Additiona

Equity & Distributions - Additional Information (Detail) (USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 25, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
		Memorial Resource [Member]	The Funds [Member]	General Partner [Member]	General Partner [Member]	General Partner [Member]	Subordinated Units [Member]
					Memorial Resource [Member]	The Funds [Member]	MRD Holdco [Member]
Equity And Distributions Textual [Abstract]	'	'	'	'	'	'	'
Number of common units issued in public offering	9,775,000	'	'	'	'	'	'
Number of over-allotment common units issued by Partnership	1,275,000	'	'	'	'	'	'
Public offering price per common unit	$18.35	'	'	'	'	'	'
Net cash proceeds from public offering	$171.80	'	'	'	'	'	'
Partnership ownership percentage	'	'	'	0.10%	100.00%	'	100.00%
Percentage ownership in incentive distribution rights	'	50.00%	50.00%	'	'	50.00%	'

Equity_Distributions_Summary_o

Equity & Distributions - Summary of Changes in Number of Outstanding Units (Detail)	6 Months Ended
	Jun. 30, 2014
Summary Of Changes In Number Of Outstanding Units [Abstract]	'
Beginning balance, General Partner	61,300
Common units issued	'
General partner units issued	620
Ending balance, General Partner	61,920
Limited Partners Common Units [Member]	'
Summary Of Changes In Number Of Outstanding Units [Abstract]	'
Beginning balance	55,877,831
Common units issued	'
Restricted common units issued	669,898
Restricted common units forfeited	-8,863
Restricted common units repurchased	-41,679
Ending balance	56,497,187
Subordinated Units [Member]	'
Summary Of Changes In Number Of Outstanding Units [Abstract]	'
Beginning balance	5,360,912
Common units issued	'
Ending balance	5,360,912

Equity_Distributions_Summary_o1

Equity & Distributions - Summary of Changes in Number of Outstanding Units (Parenthetical) (Detail) (Maximum [Member], USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Maximum [Member]	'
Summary Of Changes In Number Of Outstanding Units [Abstract]	'
Withholding tax withheld and paid related to vesting of restricted common units	$0.90

Equity_Distributions_Summary_o2

Equity & Distributions - Summary of Quarterly Cash Distribution Rates (Detail) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012
Equity [Abstract]	'	'	'	'	'	'	'
Distribution made to member or limited partner, date of declaration	24-Jul-14	24-Apr-14	27-Jan-14	22-Oct-13	18-Jul-13	18-Apr-13	15-Jan-13
Distribution made to member or limited partner, date of record	5-Aug-14	6-May-14	6-Feb-14	1-Nov-13	1-Aug-13	1-May-13	1-Feb-13
Distribution made to member or limited partner, date of distribution	12-Aug-14	13-May-14	13-Feb-14	12-Nov-13	12-Aug-13	13-May-13	13-Feb-13
Distribution per unit	$0.55	$0.55	$0.55	$0.55	$0.51	$0.51	$0.51
Aggregate Distribution	$39.50	$33.80	$33.80	$33.80	$22.90	$22.60	$17.40
Distribution Received by Affiliates	$3	$3	$3	$6.90	$6.40	$6.40	$6.30

Equity_Distributions_Summary_o3

Equity & Distributions - Summary of Quarterly Cash Distribution Rates (Parenthetical) (Detail)	0 Months Ended
	Mar. 25, 2013	Jul. 15, 2014
		Subsequent Event [Member]
Distribution Made to Limited Liability Company (LLC) Member [Line Items]	'	'
Number of common units issued in public offering	9,775,000	9,890,000

Earnings_Per_Unit_Calculation_

Earnings Per Unit - Calculation of Earnings (Loss) Per Unit (Detail) (USD $)	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
Earnings Per Share [Line Items]	'	'	'	'
Net income (loss) attributable to Memorial Production Partners LP	($114,194)	$52,597	($148,306)	$48,304
Less: Previous owners interest in net income (loss)	'	6,418	'	7,147
Less: General partner's 0.1% interest in net income (loss)	-114	46	-148	41
Less: IDRs attributable to corresponding period	47	'	87	'
Net income (loss) available to limited partners	-114,127	46,133	-148,245	41,116
Weighted average limited partner units outstanding:	'	'	'	'
Common units	56,103	38,870	55,997	34,307
Subordinated units	5,361	5,361	5,361	5,361
Total	61,464	44,231	61,358	39,668
Basic and diluted EPU	($1.86)	$1.04	($2.42)	$1.04
Supplemental EPU [Member]	'	'	'	'
Earnings Per Share [Line Items]	'	'	'	'
Net income (loss) attributable to Memorial Production Partners LP	-114,194	52,597	-148,306	48,304
Less: General partner's 0.1% interest in net income (loss)	-114	46	-148	41
Less: IDRs attributable to corresponding period	47	'	87	'
Net income (loss) available to limited partners	($114,127)	$52,551	($148,245)	$48,263
Weighted average limited partner units outstanding:	'	'	'	'
Common units	56,103	38,870	55,997	34,307
Subordinated units	5,361	5,361	5,361	5,361
Total	61,464	44,231	61,358	39,668
Basic and diluted EPU	($1.86)	$1.19	($2.42)	$1.22

Earnings_Per_Unit_Calculation_1

Earnings Per Unit - Calculation of Earnings (Loss) Per Unit (Parenthetical) (Detail)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Share [Line Items]	'	'	'	'
General partner's interest in net income, percentage	0.10%	0.10%	0.10%	0.10%
Supplemental EPU [Member]	'	'	'	'
Earnings Per Share [Line Items]	'	'	'	'
General partner's interest in net income, percentage	0.10%	0.10%	0.10%	0.10%

Equitybased_Awards_Summary_of_

Equity-based Awards - Summary of Information Regarding Restricted Common Unit Awards (Detail) (Restricted Stock [Member], USD $)	6 Months Ended
	Jun. 30, 2014
Restricted Stock [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Restricted common units outstanding, Beginning Balance	706,927
Granted, Number of Units	669,898
Forfeited, Number of Units	-8,863
Vested, Number of Units	-256,130
Restricted common units outstanding, Ending Balance	1,111,832
Restricted common units outstanding, Weighted Average Grant Date Fair Value per unit, Beginning balance	$18.62
Granted, Weighted-Average Grant Date Fair Value per Unit	$22.36
Forfeited, Weighted-Average Grant Date Fair Value per Unit	$18.57
Vested, Weighted-Average Grant Date Fair Value per Unit	$18.57
Restricted common units outstanding, Weighted Average Grant Date Fair Value per unit, Ending balance	$20.89

Equitybased_Awards_Summary_of_1

Equity-based Awards - Summary of Information Regarding Restricted Common Unit Awards (Parenthetical) (Detail) (USD $)	Jun. 30, 2014
In Millions, except Per Share data, unless otherwise specified
Restricted Stock [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Aggregate grant date fair value of restricted common unit awards issued	$15
Minimum [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Range of grant date market price	$21.99
Maximum [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Range of grant date market price	$22.37

Equitybased_Awards_Summary_of_2

Equity-based Awards - Summary of Amount of Compensation Expense Recognized (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]	'	'	'	'
Compensation expense	$1,665	$663	$2,960	$1,085

Equitybased_Awards_Additional_

Equity-based Awards - Additional Information (Detail) (Restricted Common Units [Member], USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Restricted Common Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Unrecognized compensation cost	$21.70
Weighted-average period of unrecognized compensation cost	'2 years 6 months

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	0 Months Ended	6 Months Ended			6 Months Ended
In Millions, unless otherwise specified	Mar. 28, 2013	Jun. 30, 2014	Jun. 30, 2014	Mar. 28, 2013	Jun. 30, 2014	Apr. 30, 2014	Jun. 30, 2014
			WHT Acquisition [Member]	WHT Acquisition [Member]	Double A Acquisition [Member]	Double A Acquisition [Member]	Memorial Resource [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'	'
Common Control Acquisition Purchase Price	'	'	'	$200	'	$33.30	'
Date of acquisition common control	'	'	28-Mar-13	'	30-Apr-14	'	'
Working capital and other customary adjustments	'	'	'	4	'	'	'
Effective date of common control acquisition	'	1-Jan-13	'	'	'	'	'
Amount receivable under management agreement	'	'	'	'	'	'	0.4
Management fee per month	$0.20	'	'	'	'	'	'

Related_Party_Transactions_Sum

Related Party Transactions - Summary of Fair Value Assessment of Assets Acquired and Liabilities Assumed in Double A Acquisition (Detail) (Double A Acquisition [Member], USD $)	Apr. 30, 2014
In Thousands, unless otherwise specified
Double A Acquisition [Member]	'
Related Party Transaction [Line Items]	'
Oil and gas properties, net	$37,838
Asset retirement obligations	-908
Other current liabilities	-722
Net assets	$36,208

Related_Party_Transactions_Sch

Related Party Transactions - Schedule of Net Assets Recorded by Partnership (Detail) (WHT Acquisition [Member], USD $)	Mar. 28, 2013
In Thousands, unless otherwise specified
WHT Acquisition [Member]	'
Related Party Transaction [Line Items]	'
Cash and cash equivalents	$1,354
Accounts receivable	3,866
Short-term derivative instruments, net	1,206
Prepaid expenses and other current assets	98
Oil and natural gas properties, net	192,280
Long-term derivative instruments, net	3,528
Accrued liabilities	-3,494
Asset retirement obligations	-2,753
Credit facilities	-89,300
Other long-term liabilities	-111
Net assets	$106,674

Related_Party_Transactions_Sch1

Related Party Transactions - Schedule of Amount of General and Administrative Costs and Expenses Recognized (Detail) (Omnibus Agreement [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Omnibus Agreement [Member]	'	'	'	'
Related Party Transaction Due From To Related Party [Line Items]	'	'	'	'
General and administrative costs and expenses under omnibus agreement	$5,411	$1,766	$10,259	$3,251

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Commitments And Contingencies Disclosure [Abstract]	'	'
Environmental reserves, total	$2.50	$0.40
Estimated environmental remediation expenses	2.9	'
Maximum remaining obligation	$10.30	'

Commitments_and_Contingencies_2

Commitments and Contingencies - Gross Held-to-Maturity Investments (Detail) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
Held-to-maturity Securities [Abstract]	'
Less: Outside working interest owners share	($63,690)
Amortized Cost	68,313
U.S. Bank Money Market Cash Equivalent [Member]	'
Held-to-maturity Securities [Abstract]	'
Amortized Cost	$132,003

Commitments_and_Contingencies_3

Commitments and Contingencies - Minimum Balances Attributable to Net Working Interest (Detail) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
June 30, 2014 [Member]	'
Asset retirement obligations	'
Minimum balances attributable to REO's net working interest	$68,310
June 30, 2015 [Member]	'
Asset retirement obligations	'
Minimum balances attributable to REO's net working interest	72,450
June 30, 2016 [Member]	'
Asset retirement obligations	'
Minimum balances attributable to REO's net working interest	76,590
December 31, 2016 [Member]	'
Asset retirement obligations	'
Minimum balances attributable to REO's net working interest	$78,660

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	0 Months Ended	6 Months Ended	0 Months Ended						0 Months Ended
	Mar. 25, 2013	Jun. 30, 2014	5-May-14	Jul. 15, 2014	Jul. 01, 2014	Jul. 01, 2014	Jul. 17, 2014	Jul. 01, 2014	Jul. 17, 2014	Jul. 17, 2014
			Deposits [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]
							Revolving Credit Facility [Member]	Revolving Credit Facility [Member]	6.875% Senior Notes [Member]	Private Placement of Debt [Member]
										6.875% Senior Notes [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'	'	'
Face amount of 6.875% senior unsecured notes due in 2022 at time of issuance	'	'	'	'	'	'	'	'	'	$500,000,000
Senior notes	'	'	'	'	'	'	'	'	'	6.88%
Senior notes issued at par	'	'	'	'	'	'	'	'	'	98.49%
Other events of default minimum note holder percentage to accelerate	'	'	'	'	'	'	'	'	25.00%	'
Net proceeds from notes offering	'	'	'	'	'	'	'	'	484,900,000	'
Borrowing Base	'	870,000,000	'	'	'	'	1,315,000,000	1,440,000,000	'	'
Number of common units issued in public offering	9,775,000	'	'	9,890,000	'	'	'	'	'	'
Number of over-allotment common units issued by Partnership	1,275,000	'	'	1,290,000	'	'	'	'	'	'
Public offering price per common unit	$18.35	'	'	$22.25	'	'	'	'	'	'
Net cash proceeds from public offering	171,800,000	'	'	220,300,000	'	'	'	'	'	'
Deposits for property acquisitions	'	70,125,000	70,100,000	'	'	'	'	'	'	'
Purchase price of Wyoming acquisition	'	'	'	'	'	$915,100,000	'	'	'	'
Effective date of acquisition	'	'	'	'	1-Apr-14	'	'	'	'	'