Pressburg (ROAN) 10-Q 4 Nov 14 2014 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Sep. 30, 2014	Oct. 31, 2014
Document and Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-14	'
Amendment Flag	'false	'
Entity Registrant Name	'Linn Energy, LLC	'
Entity Central Index Key	'0001326428	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'Yes	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	331,903,326
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$59,161	$52,171
Accounts receivable – trade, net	522,633	488,202
Derivative instruments	337,244	176,130
Assets held for sale	1,865,040	0
Other current assets	165,512	99,437
Total current assets	2,949,590	815,940
Noncurrent assets:	'	'
Oil and natural gas properties (successful efforts method)	18,136,485	17,888,559
Less accumulated depletion and amortization	-3,099,637	-3,546,284
Oil and natural gas properties, successful efforts method, net	15,036,848	14,342,275
Other property and equipment	635,410	647,882
Less accumulated depreciation	-148,815	-110,939
Other property and equipment, net	486,595	536,943
Derivative instruments	305,274	682,002
Other noncurrent assets	148,687	127,804
Noncurrent assets, excluding property, total	453,961	809,806
Total noncurrent assets	15,977,404	15,689,024
Total assets	18,926,994	16,504,964
Current liabilities:	'	'
Accounts payable and accrued expenses	826,976	849,624
Derivative instruments	2,597	28,176
Other accrued liabilities	327,449	163,375
Current portion of long-term debt	1,300,000	211,558
Total current liabilities	2,457,022	1,252,733
Noncurrent liabilities:	'	'
Credit facilities	3,683,175	2,733,175
Term loan	500,000	500,000
Senior notes, net	6,826,971	5,725,483
Derivative instruments	80	4,649
Other noncurrent liabilities	527,613	397,497
Total noncurrent liabilities	11,537,839	9,360,804
Commitments and contingencies (Note 10)	'	'
Unitholders’ capital:	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	5,629,837	6,291,824
Accumulated deficit	-697,704	-400,397
Total unitholders' capital	4,932,133	5,891,427
Total liabilities and unitholders’ capital	$18,926,994	$16,504,964

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical)	Sep. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Unitholders' capital: Units issued	331,820,379	329,661,161
Unitholders' capital: Units outstanding	331,820,379	329,661,161

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$937,458	$537,671	$2,844,185	$1,488,610
Gains (losses) on oil and natural gas derivatives	451,702	-63,931	-198,579	154,432
Marketing revenues	39,836	13,484	100,655	40,558
Other revenues	6,119	7,338	19,392	18,847
Total revenues	1,435,115	494,562	2,765,653	1,702,447
Expenses:	'	'	'	'
Lease operating expenses	191,630	87,076	570,564	259,381
Transportation expenses	53,412	35,637	143,896	92,118
Marketing expenses	31,574	9,962	75,920	26,696
General and administrative expenses	75,384	45,431	221,518	150,302
Exploration costs	7,850	1,588	10,492	4,632
Depreciation, depletion and amortization	290,287	208,892	832,523	604,962
Impairment of long-lived assets	603,250	-4,240	603,250	37,962
Taxes, other than income taxes	66,770	36,457	201,014	108,525
(Gains) losses on sale of assets and other, net	-35,803	827	-27,750	3,040
Total expenses	1,284,354	421,630	2,631,427	1,287,618
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-154,047	-103,806	-422,160	-308,012
Loss on extinguishment of debt	0	-1,117	0	-5,304
Other, net	-1,847	-2,475	-6,699	-6,300
Total other income and (expenses)	-155,894	-107,398	-428,859	-319,616
Income (loss) before income taxes	-5,133	-34,466	-294,633	95,213
Income tax expense (benefit)	-1,033	-4,406	2,674	2,001
Net income (loss)	($4,100)	($30,060)	($297,307)	$93,212
Net income (loss) per unit:	'	'	'	'
Basic (in usd per unit)	($0.02)	($0.13)	($0.92)	$0.38
Diluted (in usd per unit)	($0.02)	($0.13)	($0.92)	$0.38
Weighted average units outstanding:	'	'	'	'
Basic (in units)	329,168	233,552	328,783	233,393
Diluted (in units)	329,168	233,552	328,783	233,765
Distributions declared per unit (in usd per unit)	$0.73	$0.73	$2.17	$2.17

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS' CAPITAL (Unaudited) (USD $)	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2014
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	$5,891,427
Issuance of units	'	11,789
Distributions to unitholders	'	-721,235
Unit-based compensation expenses	'	43,692
Excess tax benefit from unit-based compensation and other	'	3,767
Net loss	-4,100	-297,307
30-Sep-14	4,932,133	4,932,133
Units	'	'
Increase (Decrease) in Unitholders' Capital	'	'
December 31, 2013 (in units)	'	329,661
Issuance of units (in units)	'	2,159
September 30, 2014 (in units)	331,820	331,820
Unitholders' Capital	'	'
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	6,291,824
Issuance of units	'	11,789
Distributions to unitholders	'	-721,235
Unit-based compensation expenses	'	43,692
Excess tax benefit from unit-based compensation and other	'	3,767
Net loss	'	0
30-Sep-14	5,629,837	5,629,837
Accumulated Deficit	'	'
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	-400,397
Issuance of units	'	0
Distributions to unitholders	'	0
Unit-based compensation expenses	'	0
Excess tax benefit from unit-based compensation and other	'	0
Net loss	'	-297,307
30-Sep-14	($697,704)	($697,704)

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Cash flow from operating activities:	'	'	'	'
Net income (loss)	($4,100)	($30,060)	($297,307)	$93,212
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'	'
Depreciation, depletion and amortization	290,287	208,892	832,523	604,962
Impairment of long-lived assets	603,250	-4,240	603,250	37,962
Unit-based compensation expenses	'	'	43,692	29,261
Loss on extinguishment of debt	0	1,117	0	5,304
Amortization and write-off of deferred financing fees	'	'	29,236	16,392
(Gains) losses on sale of assets and other, net	'	'	-33,135	18,744
Deferred income taxes	'	'	2,619	731
Derivatives activities:	'	'	'	'
Total (gains) losses	-451,702	63,931	198,579	-154,432
Cash settlements	10,000	45,000	-12,507	190,368
Changes in assets and liabilities:	'	'	'	'
(Increase) decrease in accounts receivable – trade, net	'	'	-56,014	22,877
Decrease in other assets	'	'	3,284	9,177
Increase in accounts payable and accrued expenses	'	'	112,235	29,445
Increase in other liabilities	'	'	9,355	36,508
Net cash provided by operating activities	'	'	1,435,810	940,511
Cash flow from investing activities:	'	'	'	'
Acquisition of oil and natural gas properties and joint-venture funding	'	'	-2,601,932	-192,871
Development of oil and natural gas properties	'	'	-1,176,478	-767,604
Purchases of other property and equipment	'	'	-50,138	-76,987
Proceeds from sale of properties and equipment and other	'	'	-7,485	210,297
Net cash used in investing activities	'	'	-3,836,033	-827,165
Cash flow from financing activities:	'	'	'	'
Proceeds from borrowings	'	'	5,300,024	1,260,000
Repayments of debt	'	'	-2,156,124	-789,898
Distributions to unitholders	'	'	-721,235	-511,686
Financing fees and other, net	'	'	-19,483	-45,685
Excess tax benefit from unit-based compensation	'	'	4,031	160
Net cash provided by (used in) financing activities	'	'	2,407,213	-87,109
Net increase in cash and cash equivalents	'	'	6,990	26,237
Cash and cash equivalents:	'	'	'	'
Beginning	'	'	52,171	1,243
Ending	$59,161	$27,480	$59,161	$27,480

Basis_of_Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Nature of Business
	Linn Energy, LLC (“LINN Energy” or the “Company”) is an independent oil and natural gas company. LINN Energy’s mission is to acquire, develop and maximize cash flow from a growing portfolio of long-life oil and natural gas assets. The Company’s properties are located in eight operating regions in the United States (“U.S.”), in the Rockies, the Mid-Continent, California, the Hugoton Basin, the Permian Basin, TexLa, Michigan/Illinois and south Texas.
	Principles of Consolidation and Reporting
	The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. The condensed consolidated financial statements also include the accounts of a variable interest entity where the Company is the primary beneficiary of the arrangements. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The Company’s other investment is accounted for at cost.
	The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ capital or cash flows.
	Use of Estimates
	The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
	Recently Issued Accounting Standards
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 2016, and interim periods within those years (early adoption prohibited). The Company is currently evaluating the impact, if any, of the adoption of this ASU on its consolidated financial statements and related disclosures.
	In April 2014, the FASB issued an ASU that changes the criteria for reporting discontinued operations and enhances disclosures in this area. This ASU is effective for annual and interim periods beginning after December 15, 2014, with early adoption permitted for disposals or for assets classified as held for sale that have not been reported in previously issued financial statements. The Company early adopted this ASU on a prospective basis beginning with the third quarter of 2014. The adoption had no effect on the Company’s consolidated financial statements.

Acquisitions_Divestitures_and_

Acquisitions, Divestitures and Joint-Venture Funding	9 Months Ended
	Sep. 30, 2014
Business Combinations [Abstract]	'
Acquisitions, Divestitures and Joint-Venture Funding	'
	Acquisitions, Divestitures and Joint-Venture Funding
	Properties Exchange
	On August 15, 2014, the Company, through two of its wholly owned subsidiaries, completed the trade of a portion of its Permian Basin properties to Exxon Mobil Corporation and its affiliates, including its wholly owned subsidiary XTO Energy Inc., in exchange for properties in the Hugoton Basin. The noncash exchange was accounted for at fair value and the Company recognized a net gain of approximately $45 million, including costs to sell of approximately $3 million. The gain is equal to the difference between the carrying value and the fair value of the assets exchanged less costs to sell, which is included in “(gains) losses on sale of assets and other, net” in the condensed consolidated statements of operations. The fair value measurements were based on inputs that are not observable in the market and therefore represent Level 3 inputs under the fair value hierarchy.
	Acquisitions – 2014
	On September 11, 2014, the Company, through a variable interest entity (“VIE”) (see below), completed the acquisition of certain oil and natural gas properties located in the Hugoton Basin from Pioneer Natural Resources (“Pioneer” and the acquisition, the “Pioneer Assets Acquisition”) for total consideration of approximately $328 million.
	On August 29, 2014, the Company, through a VIE (see below), completed the acquisition of certain oil and natural gas properties located in five operating regions in the U.S. from subsidiaries of Devon Energy Corporation (“Devon” and the acquisition, the “Devon Assets Acquisition”) for total consideration of approximately $2.2 billion.
	The Pioneer Assets Acquisition was initially financed with borrowings under the LINN Credit Facility, and the Devon Assets Acquisition was initially financed with proceeds from the Bridge Loan and borrowings under the VIE Term Loan (see Note 6). The Company intends to use the net proceeds from the pending sales of its Granite Wash assets as well as certain of its Wolfberry properties (see below) to repay the VIE Term Loan in full as well as repay a portion of the borrowings outstanding under the LINN Credit Facility.
	The Pioneer Assets Acquisition and the Devon Assets Acquisition were structured as reverse like-kind exchanges pursuant to Section 1031 of the Internal Revenue Code, as amended (“Reverse 1031 Exchanges”). In connection with the Reverse 1031 Exchanges, the Company, through a subsidiary, assigned the rights to acquire legal title to the oil and natural gas properties from Pioneer and Devon to a VIE formed by an exchange accommodation titleholder. A subsidiary of LINN Energy operates the properties pursuant to management agreements with the VIE. Because the Company is the primary beneficiary of the VIE, the VIE is included in the condensed consolidated financial statements.
	Revenues less certain reimbursable expenses of the VIE are available to LINN Energy with respect to assets attributable to the Pioneer Assets Acquisition, but can only be used to service debt and other obligations of the VIE with respect to assets attributable to the Devon Assets Acquisition. All assets held by the VIE are separate from the collateral pool securing the LINN Credit Facility. Debt obligations of the VIE are nonrecourse to LINN Energy and neither LINN Energy nor the VIE guarantee obligations of the other. The assets currently held by the VIE attributable to the Pioneer Assets Acquisition and the Devon Assets Acquisition will be conveyed to LINN Energy and its subsidiaries, and the VIE structure will terminate, upon the earlier of (i) completion of the Reverse 1031 Exchanges (which the Company expects to occur upon closing of the pending sales of its Granite Wash assets and certain of its Wolfberry properties) or (ii) the expiration of the time allowed by IRS rules and regulations to complete the Reverse 1031 Exchanges.
	During the nine months ended September 30, 2014, the Company also completed other smaller acquisitions of oil and natural gas properties located in its various operating regions. The Company, in the aggregate, paid approximately $9 million in total consideration for these properties.
	These acquisitions and exchange were accounted for under the acquisition method of accounting. Accordingly, the Company conducted assessments of net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated fair values on the acquisition dates, while transaction and integration costs associated with the acquisitions were expensed as incurred. The initial accounting for the business combinations is not complete and adjustments to provisional amounts, or recognition of additional assets acquired or liabilities assumed, may occur as more detailed analyses are completed and additional information is obtained about the facts and circumstances that existed as of the acquisition dates. The results of operations of all acquisitions have been included in the condensed consolidated financial statements since the acquisition dates.
	The following presents the values assigned to the net assets acquired as of the acquisition dates (in thousands):
	Assets:
	Current	$	22,604
	Oil and natural gas properties	2,637,856
	Other property and equipment	83,151
	Total assets acquired	2,743,611
	Liabilities:
	Current	16,074
	Asset retirement obligations	144,645
	Total liabilities assumed	160,719
	Net assets acquired	$	2,582,892
	Current assets include receivables and inventory. Current liabilities include payables and environmental liabilities.
	The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs under the fair value hierarchy. The fair values of oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; (iv) estimated future cash flows; and (v) a market-based weighted average cost of capital rate. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.
	The following unaudited pro forma financial information presents a summary of the Company’s consolidated results of operations for the three months and nine months ended September 30, 2014, and September 30, 2013, assuming the Devon Assets Acquisition and the 2013 acquisition of Berry Petroleum Company, now Berry Petroleum Company, LLC (“Berry”) (see below) had been completed as of January 1, 2013, including adjustments to reflect the values assigned to the net assets acquired. The pro forma financial information has been prepared for informational purposes only and does not purport to represent what the actual results of operations would have been had the transactions been completed as of the date assumed, nor is this information necessarily indicative of future consolidated results of operations. The pro forma financial information does not give effect to the costs of any integration activities or benefits that may result from the realization of future cost savings from operating efficiencies, or any other synergies that may result from the transactions and changes in commodity and share prices.
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014			2013
		(in thousands, except per unit amounts)
	Total revenues and other	1,509,498		902,733		3,117,792			2,978,108
	Total operating expenses	1,331,861		717,032		2,852,327			2,150,170
	Net income (loss)	3		25,262		(257,158		)	334,272
	Net income (loss) per unit:
	Basic	$	—	$	0.08	$	(0.80	)	$	1.01
	Diluted	$	—	$	0.08	$	(0.80	)	$	1.01
	The pro forma condensed combined statements of operations include adjustments to:
	•	Reflect the results of the Devon Assets Acquisition and the Berry acquisition for all periods presented.
	•	Reflect incremental depreciation, depletion and amortization expense, using the units-of-production method, related to oil and natural gas properties acquired and using an estimated useful life of 10 years for the Devon Assets Acquisition and 20 years for the Berry acquisition for other property and equipment.
	•	Reflect accretion expense related to asset retirement obligations on oil and natural gas properties acquired in the Devon Assets Acquisition.
	•	Reflect an increase in interest expense related to incremental debt of $2.3 billion incurred to fund the purchase price of the Devon Assets Acquisition and a reduction in interest expense related to the amortization of the adjustment to fair value of Berry’s debt using the effective interest method.
	•	Reflect incremental amortization of deferred financing fees associated with debt incurred to fund the purchase price of the Devon Assets Acquisition.
	•	Exclude transaction costs related to the Devon Assets Acquisition and the Berry acquisition included in the historical statements of operations as they reflect nonrecurring charges not expected to have a continuing impact on the combined results.
	•	Reflect approximately 93.8 million LINN Energy units assumed to be issued on January 1, 2013, in conjunction with the Berry acquisition.
	Properties Exchange – Pending
	On September 18, 2014, the Company, through two of its wholly owned subsidiaries, entered into a definitive agreement to trade a portion of its Permian Basin properties to Exxon Mobil Corporation in exchange for properties in California’s South Belridge Field. The Company anticipates the transaction will close in the fourth quarter of 2014, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied.
	Divestiture – Subsequent Event
	On October 30, 2014, the Company, through a VIE (see above), completed the sale of its interests in certain non-producing oil and natural gas properties located in the Mid-Continent region. Proceeds received for the Company’s interests in the properties were approximately $44 million. The Company intends to ultimately use the proceeds from the sale to repay a portion of the borrowings outstanding under the LINN Credit Facility.
	Divestitures – Pending
	On October 2, 2014, the Company, through certain of its wholly owned subsidiaries, entered into a definitive purchase and sale agreement to sell its entire position in the Granite Wash and Cleveland plays located in the Texas Panhandle and western Oklahoma to privately held institutional affiliates of EnerVest, Ltd. (“EnerVest”) and its joint venture partner FourPoint Energy, LLC for a contract price of $1.95 billion, subject to closing adjustments.
	On October 1, 2014, the Company, through two of its wholly owned subsidiaries, entered into a definitive purchase and sale agreement to sell certain of its Wolfberry properties in Ector and Midland counties in the Permian Basin to Fleur de Lis Energy, LLC (“Fleur de Lis”) for a contract price of $350 million, subject to closing adjustments.
	The EnerVest and Fleur de Lis sales are anticipated to close in the fourth quarter of 2014, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied. The Company intends to use the net proceeds from these sales to repay the VIE Term Loan in full as well as repay a portion of the borrowings outstanding under the LINN Credit Facility. At September 30, 2014, the Company’s condensed consolidated balance sheet included current assets of approximately $1.9 billion included in “assets held for sale” and current liabilities of approximately $110 million included in “other accrued liabilities” classified as “held for sale” related to these sales.
	Berry Acquisition – 2013
	On December 16, 2013, the Company completed the transactions contemplated by the merger agreement between the Company, LinnCo, LLC (“LinnCo”), an affiliate of LINN Energy, and Berry under which LinnCo acquired all of the outstanding common shares of Berry and the contribution agreement between LinnCo and the Company, under which LinnCo contributed Berry to the Company in exchange for LINN Energy units. Under the merger agreement, as amended, Berry’s shareholders received 1.68 LinnCo common shares for each Berry common share they owned, totaling 93,756,674 LinnCo common shares. Under the contribution agreement, LinnCo contributed Berry to LINN Energy in exchange for 93,756,674 newly issued LINN Energy units, after which Berry became an indirect wholly owned subsidiary of LINN Energy. The transaction was valued at approximately $4.6 billion, including the assumption of approximately $2.3 billion of Berry’s debt and net of cash acquired of approximately $451 million.
	Divestiture – 2013
	On May 31, 2013, the Company, through one of its wholly owned subsidiaries, together with the Company’s partners, Panther Energy, LLC and Red Willow Mid-Continent, LLC, completed the sale of its interests in certain oil and natural gas properties located in the Mid-Continent region (“Panther Operated Cleveland Properties”) to Midstates Petroleum Company, Inc. At March 31, 2013, the carrying value of the Panther Operated Cleveland Properties was reduced to fair value less costs to sell resulting in an impairment charge of approximately $57 million. During the three months ended June 30, 2013, and September 30, 2013, the Company recorded adjustments of approximately $15 million and $4 million, respectively, to reduce the initial impairment charge recorded in March 2013 resulting in a total impairment charge of approximately $38 million for the nine months ended September 30, 2013. Proceeds received for the Company’s portion of its interests in the properties were approximately $218 million, net of costs to sell of approximately $2 million. The Company used the net proceeds from the sale to repay borrowings under the LINN Credit Facility.
	Joint-Venture Funding
	For the nine months ended September 30, 2014, the Company paid approximately $25 million, including interest, to fund the commitment related to the joint-venture agreement it entered into with an affiliate of Anadarko Petroleum Corporation (“Anadarko”) in April 2012. As of February 2014, the Company had fully funded the total commitment of $400 million.

Unitholders_Capital

Unitholders' Capital	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
Unitholders' Capital	'
	Unitholders’ Capital
	Distributions
	Under the Company’s limited liability company agreement, unitholders are entitled to receive a distribution of available cash, which includes cash on hand plus borrowings less any reserves established by the Company’s Board of Directors to provide for the proper conduct of the Company’s business (including reserves for future capital expenditures, including drilling, acquisitions and anticipated future credit needs) or to fund distributions over the next four quarters. Distributions paid by the Company are presented on the condensed consolidated statement of unitholders’ capital and the condensed consolidated statements of cash flows. On October 1, 2014, the Company’s Board of Directors declared a cash distribution of $0.725 per unit with respect to the third quarter of 2014, to be paid in three equal installments of $0.2416 per unit. The first monthly distribution with respect to the third quarter of 2014, totaling approximately $80 million, was paid on October 16, 2014, to unitholders of record as of the close of business on October 13, 2014.

Oil_and_Natural_Gas_Properties

Oil and Natural Gas Properties	9 Months Ended
	Sep. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Oil and Natural Gas Properties	'
	Oil and Natural Gas Properties
	Oil and Natural Gas Capitalized Costs
	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	13,045,461		$	12,277,089
	Development	3,047,527			3,660,277
	Unproved properties	2,043,497			1,951,193
		18,136,485			17,888,559
	Less accumulated depletion and amortization	(3,099,637		)	(3,546,284		)
		$	15,036,848		$	14,342,275
	Impairment of Proved Properties
	The Company evaluates the impairment of its proved oil and natural gas properties on a field-by-field basis whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of proved properties are reduced to fair value when the expected undiscounted future cash flows are less than net book value. The fair values of proved properties are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount. Significant inputs used to determine the fair values of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.
	Based on the analysis described above, for the three months and nine months ended September 30, 2014, the Company recorded a noncash impairment charge, before and after tax, of approximately $603 million associated with proved oil and natural gas properties in the Permian Basin region. The impairment was due to the divestiture of certain high valued unproved properties in the Midland Basin in which the expected cash flows were previously included in the impairment assessment for the proved oil and natural gas properties. The carrying values of the impaired proved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair-value measurement. The charge is included in “impairment of long-lived assets” on the condensed consolidated statements of operations. The impairment charge recognized for the three months and nine months ended September 30, 2013, was associated with the write-down of the carrying value of the Panther Operated Cleveland Properties sold in May 2013. See Note 2 for additional information.

UnitBased_Compensation

Unit-Based Compensation	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Unit-Based Compensation	'
	Unit-Based Compensation
	During the nine months ended September 30, 2014, the Company granted 1,457,677 restricted units and 214,875 phantom units to employees, primarily as part of its annual review of its employees’ compensation, including executives, with an aggregate fair value of approximately $56 million. The restricted units and phantom units vest over three years. The Company also granted 212,524 performance units (the maximum number of units available to be earned) to certain executive officers, with an aggregate fair value of approximately $5 million. The initial 2014 performance unit awards vest 50% in two years and 50% in three years from the award date. A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	General and administrative expenses	$	9,445	$	8,407	$	37,164	$	25,408
	Lease operating expenses	1,664		1,279		6,528		3,853
	Total unit-based compensation expenses	$	11,109	$	9,686	$	43,692	$	29,261
	Income tax benefit	$	4,105	$	3,579	$	16,144	$	10,812

Debt

Debt	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	The following summarizes the Company’s outstanding debt:
		September 30,			31-Dec-13
		2014
		(in thousands, except percentages)
	LINN credit facility (1)	$	2,510,000		$	1,560,000
	Berry credit facility (2)	1,173,175			1,173,175
	LINN term loan (2)	500,000			500,000
	VIE term loan (3)	1,300,000			—
	10.25% Berry senior notes due June 2014	—			205,257
	6.50% senior notes due May 2019 (4)	1,200,000			750,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,300,000			1,300,000
	6.75% Berry senior notes due November 2020	299,970			300,000
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.50% senior notes due September 2021 (4)	650,000			—
	6.375% Berry senior notes due September 2022	599,163			600,000
	Net unamortized discounts and premiums	(22,162		)	(18,216		)
	Total debt, net	12,310,146			9,170,216
	Less current maturities	(1,300,000		)	(211,558		)
	Total long-term debt, net	$	11,010,146		$	8,958,658
	(1)	Variable interest rates of 2.15% and 1.92% at September 30, 2014, and December 31, 2013, respectively.
	(2)	Variable interest rates of 2.66% and 2.67% at September 30, 2014, and December 31, 2013, respectively.
	(3)	Variable interest rate of 3.15% at September 30, 2014. Incurred on August 29, 2014.
	(4)	$450 million of senior notes due May 2019 and $650 million of senior notes due September 2021 were issued on September 9, 2014.
	Fair Value
	The Company’s debt is recorded at the carrying amount in the condensed consolidated balance sheets. The carrying amounts of the Company’s credit facilities and term loans approximate fair value because the interest rates are variable and reflective of market rates. The Company uses a market approach to determine the fair value of its senior notes using estimates based on prices quoted from third-party financial institutions, which is a Level 2 fair value measurement.
		30-Sep-14						December 31, 2013
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facilities	$	3,683,175		$	3,683,175		$	2,733,175	$	2,733,175
	Term loans	1,800,000			1,800,000			500,000		500,000
	Senior notes, net	6,826,971			6,821,718			5,937,041		6,162,402
	Total debt, net	$	12,310,146		$	12,304,893		$	9,170,216	$	9,395,577
	Credit Facilities
	LINN Credit Facility
	The Company’s Sixth Amended and Restated Credit Agreement (“LINN Credit Facility”) provides for (1) a senior secured revolving credit facility and (2) a $500 million senior secured term loan, in aggregate subject to the then-effective borrowing base. Borrowing capacity under the revolving credit facility is limited to the lesser of (i) the then-effective borrowing base reduced by the $500 million term loan and (ii) the maximum commitment amount of $4.0 billion, and is currently $3.725 billion. At September 30, 2014, the borrowing base under the LINN Credit Facility was $4.225 billion and availability under the revolving credit facility was approximately $1.2 billion, which includes a $5 million reduction for outstanding letters of credit.
	In April 2014, the Company entered into an amendment to the LINN Credit Facility to extend the maturity from April 2018 to April 2019, among other items, and in August 2014 and September 2014, the Company entered into amendments to the LINN Credit Facility to permit the Devon Assets Acquisition and the Pioneer Assets Acquisition, respectively, and the related Reverse 1031 Exchanges (see Note 2). As a result of the debt incurred under the Bridge Loan, as defined below, the borrowing base was reduced by 25% of the gross proceeds from the Bridge Loan, or $250 million, to $4.25 billion, resulting in a reduction of availability under the revolving credit facility of $250 million. Additionally, upon the issuance of an aggregate $1.1 billion of senior notes in the September 2014 offering (see below), the borrowing base was further reduced by $25 million to $4.225 billion, resulting in a further reduction of availability under the revolving credit facility of $25 million.
	Redetermination of the borrowing base under the LINN Credit Facility, based primarily on reserve reports that reflect commodity prices at such time, occurs semi-annually, in April and October. The administrative agent, at the direction of certain of the lenders, has the right to request one interim borrowing base redetermination per year. The Company also has the right to request one interim borrowing base redetermination per year, as well as the right to an additional interim redetermination each year in connection with certain acquisitions. Significant declines in commodity prices may result in a decrease in the borrowing base. The Company’s obligations under the LINN Credit Facility are secured by mortgages on certain of its material subsidiaries’ oil and natural gas properties and other personal property as well as a pledge of all ownership interests in the Company’s direct and indirect material subsidiaries. The Company is required to maintain either: 1) mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on its most recent reserve report, or 2) a Collateral Coverage Ratio of at least 2.5 to 1. Collateral Coverage Ratio is defined as the ratio of the present value of future cash flows from proved reserves from the currently mortgaged properties to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount. Additionally, the obligations under the LINN Credit Facility are guaranteed by all of the Company’s material subsidiaries, other than Berry, and are required to be guaranteed by any future material subsidiaries. The Company is in compliance with all financial and other covenants of the LINN Credit Facility.
	At the Company’s election, interest on borrowings under the LINN Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin between 1.5% and 2.5% per annum (depending on the then-current level of borrowings under the LINN Credit Facility) or the alternate base rate (“ABR”) plus an applicable margin between 0.5% and 1.5% per annum (depending on the then-current level of borrowings under the LINN Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at LIBOR. The Company is required to pay a commitment fee to the lenders under the LINN Credit Facility, which accrues at a rate per annum between 0.375% and 0.5% (depending on the then-current level of borrowings under the LINN Credit Facility) on the average daily unused amount of the maximum commitment amount of the lenders.
	The $500 million term loan has a maturity date of April 2019 and incurs interest based on either the LIBOR plus a margin of 2.5% per annum or the ABR plus a margin of 1.5% per annum, at the Company’s election. Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at LIBOR. The term loan may be repaid at the option of the Company without premium or penalty, subject to breakage costs. While the term loan is outstanding, the Company is required to maintain either: 1) mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on its most recent reserve report, or 2) a Term Loan Collateral Coverage Ratio of at least 2.5 to 1. The Term Loan Collateral Coverage Ratio is defined as the ratio of the present value of future cash flows from proved reserves from the currently mortgaged properties to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount and the aggregate amount of the term loan outstanding. The other terms and conditions of the LINN Credit Facility, including the financial and other restrictive covenants set forth therein, are applicable to the term loan.
	Berry Credit Facility
	Berry’s Second Amended and Restated Credit Agreement (“Berry Credit Facility”) has a borrowing base of $1.4 billion, subject to lender commitments. At September 30, 2014, lender commitments under the facility were $1.2 billion but there was less than $1 million of available borrowing capacity, including outstanding letters of credit. In February 2014, Berry entered into an amendment to the Berry Credit Facility to amend the terms of certain financial and reporting covenants, among other items, and in April 2014, Berry entered into an amendment to the Berry Credit Facility to extend the maturity from May 2016 to April 2019 and to amend the terms of certain financial covenants and definitions, among other items.
	Redetermination of the borrowing base under the Berry Credit Facility, based primarily on reserve reports that reflect commodity prices at such time, occurs semi-annually, in April and October. A super-majority of the lenders under the Berry Credit Facility and Berry also have the right to request interim borrowing base redeterminations once between scheduled redeterminations. Significant declines in commodity prices may result in a decrease in the borrowing base. Berry’s obligations under the Berry Credit Facility are secured by mortgages on its oil and natural gas properties and other personal property. Berry is required to maintain mortgages on properties representing at least 80% of the present value of its oil and natural gas proved reserves.
	Berry is currently in compliance with all financial and other covenants of the Berry Credit Facility. At December 31, 2013, Berry’s Current Ratio (as defined in the Berry Credit Facility), fell short of the requirement under its covenant primarily due to factors related to the transactions between the Company, LinnCo and Berry, including a reassessment of the carrying value of items on Berry’s balance sheet as of the acquisition date and updated accruals as of December 31, 2013. In February 2014, Berry received a waiver of the applicability of that covenant and any noncompliance which may have resulted as of December 31, 2013, and entered into an amendment to its credit facility to address this covenant for future periods. The shortfall and related waiver and amendment had no effect on Berry’s compliance with the indentures governing its outstanding senior notes for the quarter ended December 31, 2013, and Berry was in compliance with all of the covenants under the indentures governing its senior notes at December 31, 2013.
	At Berry’s election, interest on borrowings under the Berry Credit Facility is determined by reference to either the LIBOR plus an applicable margin between 1.5% and 2.5% per annum (depending on the then-current level of borrowings under the Berry Credit Facility) or a Base Rate (as defined in the Berry Credit Facility) plus an applicable margin between 0.5% and 1.5% per annum (depending on the then-current level of borrowings under the Berry Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the Base Rate and at the end of the applicable interest period for loans bearing interest at LIBOR. Berry is required to pay a commitment fee to the lenders under the Berry Credit Facility, which accrues at a rate per annum between 0.375% and 0.5% (depending on the then-current level of utilization under the Berry Credit Facility) on the average daily unused amount of the maximum commitment amount of the lenders.
	The Company refers to the LINN Credit Facility and the Berry Credit Facility, collectively, as the “Credit Facilities.”
	Bridge Loan
	On August 29, 2014, the Company entered into a bridge loan agreement (the “Bridge Loan”) pursuant to which the Company borrowed an aggregate principal amount of $1.0 billion under a term loan. The proceeds from the Bridge Loan were advanced to a VIE and used to partially fund the Devon Assets Acquisition (see Note 2). The Bridge Loan agreement was unsecured and was guaranteed by all of the Company’s material domestic subsidiaries which guarantee the LINN Credit Facility.
	The Bridge Loan had an initial maturity date of August 29, 2015, with interest determined by reference to either (i) LIBOR plus 5.0% plus an applicable margin per annum or (ii) alternate base rate plus 4.0% plus an applicable margin per annum. The applicable margin would have been 0% for the first three months after the funding date and, thereafter, increased by 0.50% at the end of each subsequent three-month period.
	On September 9, 2014, the Company paid in full the outstanding indebtedness under the Bridge Loan using proceeds from the issuance of the New May 2019 Senior Notes and the September 2021 Senior Notes, each as defined below.
	VIE Term Loan
	On August 29, 2014, a subsidiary of the VIE, formed to facilitate the Reverse 1031 Exchange for the Devon Assets Acquisition (see Note 2) entered into a 364-day term loan agreement (the “VIE Term Loan”) pursuant to which it borrowed an aggregate principal amount of $1.3 billion under a term loan. The proceeds from the VIE Term Loan were used to partially fund the Devon Assets Acquisition. The obligations under the VIE Term Loan are required to be secured by certain of the oil and natural gas properties and personal property of the VIE’s subsidiary and its material subsidiaries (if any), as well as a pledge of 100% of the equity interests in the subsidiary. Specifically, the VIE’s subsidiary is required to maintain mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on its most recent reserve report. Additionally, the obligations under the VIE Term Loan are to be guaranteed by all of the material subsidiaries of the VIE’s subsidiary (if any). As of September 30, 2014, there were no guarantors.
	The VIE Term Loan may be repaid at the option of the VIE’s subsidiary without premium or penalty, subject to breakage costs. At the VIE subsidiary’s election, interest on the loans under the VIE Term Loan is determined by reference to either (i) LIBOR plus an applicable margin per annum which is 3.0% for the period beginning on the closing date of the term loan agreement and ending on the day that is 180 days thereafter (the “Initial Period”) or (ii) alternate base rate plus an applicable margin per annum which is 2.0% for the Initial Period; in each case, the applicable margin increases by 0.50% for the three-month period beginning after the Initial Period and, thereafter, increases by an additional 0.25% at the end of each subsequent three-month period. Interest is generally payable quarterly for loans bearing interest based on the alternate base rate and at the end of the applicable interest period for loans bearing interest at LIBOR. The VIE Term Loan is required to be prepaid with 100% of the net cash proceeds from nonordinary course asset sales (subject to certain baskets described in the VIE Term Loan) and 100% of the net cash proceeds from the issuance of nonpermitted indebtedness.
	The VIE Term Loan contains various covenants, including covenants which limit the ability of the VIE’s subsidiary to: (i) incur indebtedness; (ii) enter into commodity and interest rate swaps; (iii) grant certain liens; (iv) make certain loans, acquisitions, capital contributions and other investments; (v) make distributions; and (vi) merge or consolidate, or engage in certain asset dispositions, including a sale of all or substantially all of assets. The VIE Term Loan also contains (i) a financial covenant which requires the VIE’s subsidiary to maintain a minimum ratio of adjusted earnings to interest expense and (ii) customary events of default.
	Senior Notes Due May 2019 and Senior Notes Due September 2021
	On September 9, 2014, the Company issued $1.1 billion in aggregate principal amount of senior notes consisting of $450 million aggregate principal amount of 6.50% senior notes due May 2019 (the “New May 2019 Senior Notes”) at a price of 102% of par and $650 million in aggregate principal amount of 6.50% senior notes due September 2021 (the “September 2021 Senior Notes”) at a price of 98.619% of par. The New May 2019 Senior Notes and the September 2021 Senior Notes were registered under the Securities Act of 1933, as amended (the “Securities Act”), pursuant to a shelf registration statement on Form S-3 filed on September 4, 2014, which was automatically effective upon filing. The Company received net proceeds of approximately $450 million from the issuance of the New May 2019 Senior Notes (after adding the premium of $9 million and deducting offering expenses of approximately $9 million) and approximately $628 million from the issuance of the September 2021 Senior Notes (after deducting the discount of approximately $9 million and offering expenses of approximately $13 million). The Company used the net proceeds from the New May 2019 Senior Notes and the September 2021 Senior Notes to repay all indebtedness outstanding under the Company’s Bridge Loan (see above) and repay a portion of indebtedness outstanding under the LINN Credit Facility. The financing fees and expenses of approximately $22 million incurred in connection with the New May 2019 Senior Notes and the September 2021 Senior Notes will be amortized over the life of the notes. Such amortized expenses, premium and discount are recorded in “interest expense, net of amounts capitalized” on the condensed consolidated statements of operations.
	The New May 2019 Senior Notes were issued as additional notes under an indenture (the “May 2019 Indenture”), dated as of May 13, 2011, mature May 15, 2019, and bear interest at 6.50%. Interest is payable in cash semi-annually in arrears on each May 15 and November 15, with the next interest payment due on November 15, 2014. Interest will be payable to holders of record on the May 1 and November 1 immediately preceding the related interest payment date, and will be computed on the basis of a 360-day year consisting of twelve 30-day months. The May 2019 Senior Notes are general unsecured senior obligations of the Company and are effectively junior in right of payment to any secured indebtedness of the Company to the extent of the collateral securing such indebtedness. Each of the Company’s material subsidiaries, other than Berry, has guaranteed the May 2019 Senior Notes on a senior unsecured basis. The May 2019 Indenture provides that the Company may redeem: (i) prior to May 15, 2015, all or part of the May 2019 Senior Notes at a redemption price equal to the principal amount redeemed, plus a make-whole premium (as defined in the May 2019 Indenture) and accrued and unpaid interest; and (ii) on or after May 15, 2015, all or part of the May 2019 Senior Notes at a redemption price equal to 103.250%, and decreasing percentages thereafter, of the principal amount redeemed, plus accrued and unpaid interest. The May 2019 Indenture also provides that, if a change of control (as defined in the May 2019 Indenture) occurs, the holders have a right to require the Company to repurchase all or part of the May 2019 Senior Notes at a redemption price equal to 101%, plus accrued and unpaid interest.
	The September 2021 Senior Notes were issued under an indenture dated September 9, 2014 (the “September 2021 Indenture”), mature September 15, 2021, and bear interest at 6.50%. Interest is payable in cash semi-annually in arrears on each March 15 and September 15, commencing March 15, 2015. Interest will be payable to holders of record on the March 1 and September 1 immediately preceding the related interest payment date, and will be computed on the basis of a 360-day year consisting of twelve 30-day months. The September 2021 Senior Notes are general unsecured senior obligations of the Company and are effectively junior in right of payment to any secured indebtedness of the Company to the extent of the collateral securing such indebtedness. Each of the Company’s material subsidiaries, other than Berry, has guaranteed the September 2021 Senior Notes on a senior unsecured basis. The September 2021 Indenture provides that the Company may redeem: (i) prior to September 15, 2017, up to 35% of the aggregate principal amount of the September 2021 Senior Notes at a redemption price of 106.500% of the principal amount redeemed, plus accrued and unpaid interest, with the net cash proceeds of one or more equity offerings; (ii) prior to September 15, 2017, all or part of the September 2021 Senior Notes at a redemption price equal to the principal amount redeemed, plus a make-whole premium (as defined in the September 2021 Indenture) and accrued and unpaid interest; and (iii) on or after September 15, 2017, all or part of the September 2021 Senior Notes at a redemption price equal to 103.250%, and decreasing percentages thereafter, of the principal amount redeemed, plus accrued and unpaid interest. The September 2021 Indenture also provides that, if a change of control (as defined in the September 2021 Indenture) occurs, the holders have a right to require the Company to repurchase all or part of the September 2021 Senior Notes at a redemption price equal to 101%, plus accrued and unpaid interest.
	The May 2019 Indenture and the September 2021 Indenture contain covenants that, among other things, limit the Company’s ability and the ability of the Company’s restricted subsidiaries to: (i) pay distributions on, purchase or redeem the Company’s units or redeem its subordinated debt; (ii) make investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create certain liens; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets; (vii) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries.
	Senior Notes Due November 2019
	The Company has $1.8 billion in aggregate principal amount of 6.25% senior notes due November 2019 (the “November 2019 Senior Notes”). In connection with the issuance and sale of the November 2019 Senior Notes, the Company entered into a Registration Rights Agreement (“November 2019 Registration Rights Agreement”) with the initial purchasers. Under the November 2019 Registration Rights Agreement, the Company agreed to use its reasonable efforts to file with the SEC and cause to become effective a registration statement relating to an offer to issue new notes having terms substantially similar to the November 2019 Senior Notes in exchange for outstanding November 2019 Senior Notes within 400 days after the notes were issued. On March 22, 2013, the Company filed a registration statement on Form S-4 to register exchange notes that are substantially similar to the November 2019 Senior Notes. On June 2, 2014, the registration statement was declared effective and the Company commenced an offer to exchange any and all of its $1.8 billion outstanding principal amount of November 2019 Senior Notes for an equal amount of new November 2019 Senior Notes.
	The terms of the new November 2019 Senior Notes are substantially similar in all material respects to those of the outstanding November 2019 Senior Notes, except that the transfer restrictions, registration rights and additional interest provisions relating to the outstanding November 2019 Senior Notes do not apply to the new November 2019 Senior Notes. The exchange offer expired on June 28, 2014. The effective date of the registration statement was past the deadline in the registration rights agreement, and therefore, the Company paid additional interest of approximately $15 million since the deadline.
Senior Notes Due April 2020 and Senior Notes Due February 2021
The Company has $1.3 billion in aggregate principal amount of 8.625% senior notes due April 2020 (the “April 2020 Senior Notes”) and $1.0 billion in aggregate principal amount of 7.75% senior notes due February 2021 (the “February 2021 Senior Notes,” and together with the April 2020 Senior Notes, the “2010 Issued Senior Notes”). The restrictive legends from each of the 2010 Issued Senior Notes have been removed making them freely tradable (other than with respect to persons that are affiliates of the Company), thereby terminating the Company’s obligations under each of the registration rights agreements entered into in connection with the issuance of the 2010 Issued Senior Notes.
Berry Senior Notes Due November 2020
Berry has $300 million in aggregate principal amount of 6.75% senior notes due November 2020 (the “Berry November 2020 Senior Notes”). The Berry November 2020 Senior Notes were recorded at their fair value of approximately $310 million on the Berry acquisition date including a $10 million premium which is being amortized to interest expense over the life of the related notes.
Berry Senior Notes Due September 2022
Berry has $599 million in aggregate principal amount of 6.375% senior notes due September 2022 (the “Berry September 2022 Senior Notes”). The Berry September 2022 Senior Notes were recorded at their fair value of approximately $607 million on the Berry acquisition date including a $7 million premium which is being amortized to interest expense over the life of the related notes.
Repurchases of Berry Senior Notes
In February 2014, in accordance with the indentures related to Berry’s senior notes, the Company repurchased through cash tender offers $321,000, $30,000 and $837,000 of Berry’s 10.25% senior notes due June 2014 (the “Berry June 2014 Senior Notes”), November 2020 Senior Notes and September 2022 Senior Notes, respectively.
Payment of Berry June 2014 Senior Notes
On May 30, 2014, in accordance with the provisions of the indenture related to the Berry June 2014 Senior Notes, the Company paid in full the remaining outstanding principal amount of approximately $205 million.
Senior Notes Covenants
The Company’s senior notes contain covenants that, among other things, may limit its ability to: (i) pay distributions on, purchase or redeem the Company’s units or redeem its subordinated debt; (ii) make investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create certain liens; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets; (vii) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries. The Company is in compliance with all financial and other covenants of its senior notes.
Berry’s senior notes contain covenants that, among other things, may limit its ability to: (i) incur or guarantee additional indebtedness; (ii) pay distributions on Berry’s equity or redeem its subordinated debt; (iii) create certain liens; (iv) enter into agreements that restrict distributions or other payments from Berry’s restricted subsidiaries to Berry; (v) sell assets; (vi) engage in transactions with affiliates; and (vii) consolidate, merge or transfer all or substantially all of Berry’s assets. Berry is in compliance with all financial and other covenants of its senior notes.

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	Derivatives
	Commodity Derivatives
	The Company hedges a significant portion of its forecasted production to reduce exposure to fluctuations in the prices of oil and natural gas and provide long-term cash flow predictability to manage its business, service debt and pay distributions. The current direct NGL hedging market is constrained in terms of price, volume, duration and number of counterparties, which limits the Company’s ability to effectively hedge its NGL production. As a result, currently, the Company directly hedges only its oil and natural gas production. The Company has not entered into any new commodity derivative positions to date in 2014.
	The Company enters into commodity hedging transactions primarily in the form of swap contracts that are designed to provide a fixed price and, from time to time, put options that are designed to provide a fixed price floor with the opportunity for upside. The Company enters into these transactions with respect to a portion of its projected production to provide an economic hedge of the risk related to the future commodity prices received. The Company does not enter into derivative contracts for trading purposes. In connection with the Berry acquisition (see Note 2), the Company assumed certain derivative contracts that Berry had entered into prior to the acquisition date, including oil swaps, oil trade month roll swaps and oil collars through 2014, and oil basis swaps and oil three-way collars through 2015. The Company did not designate any of these contracts as cash flow hedges; therefore, the changes in fair value of these instruments are recorded in current earnings. See Note 8 for fair value disclosures about oil and natural gas commodity derivatives.
	The following table summarizes derivative positions for the periods indicated as of September 30, 2014:
		October 1 - December 31, 2014			2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	24,550			118,041			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.25		$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	20,071			71,854			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	5		$	4.88		$	—
		October 1 - December 31, 2014			2015			2016			2017			2018
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	4,242			11,599			11,465			4,755			—
	Average price ($/Bbl)	$	92.44		$	96.23		$	90.56		$	89.02		$	—
	Collars (NYMEX WTI):
	Hedged volume (MBbls)	184			—			—			—			—
	Average floor price ($/Bbl)	$	90		$	—		$	—		$	—		$	—
	Average ceiling price ($/Bbl)	$	102.87		$	—		$	—		$	—		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	782			1,095			—			—			—
	Short put ($/Bbl)	$	72.11		$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	93.76		$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	109.79		$	101.62		$	—		$	—		$	—
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	998			3,426			3,271			384			—
	Average price ($/Bbl)	$	91.3		$	90		$	90		$	90		$	—
	Three-way collars (ICE Brent):
	Hedged volume (MBbls)	92			—			—			—			—
	Short put ($/Bbl)	$	80		$	—		$	—		$	—		$	—
	Long put ($/Bbl)	$	100		$	—		$	—		$	—		$	—
	Short call ($/Bbl)	$	114.05		$	—		$	—		$	—		$	—
	Natural gas basis differential positions: (2)
	Panhandle basis swaps:
	Hedged volume (MMMBtu)	20,010			87,162			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps:
	Hedged volume (MMMBtu)	10,398			43,292			46,294			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.20	)	$	(0.20	)	$	(0.20	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps:
	Hedged volume (MMMBtu)	2,392			9,344			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.08		$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps:
	Hedged volume (MMMBtu)	1,325			4,891			4,575			3,604			986
	Hedged differential ($/MMBtu)	$	(0.10	)	$	(0.10	)	$	(0.10	)	$	(0.08	)	$	(0.08	)
	Permian basis swaps:
	Hedged volume (MMMBtu)	1,233			5,074			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	Oil basis differential positions:
	ICE Brent - NYMEX WTI basis swaps:
	Hedged volume (MBbls)	920			2,920			—			—			—
	Hedged differential ($/Bbl)	$	11.6		$	11.6		$	—		$	—		$	—
		October 1 - December 31, 2014			2015			2016			2017			2018
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (3)
	Hedged volume (MBbls)	2,289			7,251			7,446			6,486			—
	Hedged differential ($/Bbl)	$	0.24		$	0.24		$	0.25		$	0.25		$	—
	(1)	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
	(2)	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
	(3)	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).
Settled derivatives on natural gas production for the three months and nine months ended September 30, 2014, included volumes of 44,621 MMMBtu and 132,408 MMMBtu, respectively, at an average contract price of $5.14 per MMBtu. Settled derivatives on oil production for the three months and nine months ended September 30, 2014, included volumes of 6,299 MBbls and 18,690 MBbls, respectively, at an average contract price of $92.39 per Bbl. Settled derivatives on natural gas production for the three months and nine months ended September 30, 2013, included volumes of 43,729 MMMBtu and 129,760 MMMBtu, respectively, at an average contract price of $5.29 per MMBtu. Settled derivatives on oil production for the three months and nine months ended September 30, 2013, included volumes of 3,775 MBbls and 11,201 MBbls, respectively, at an average contract price of $95.57 per Bbl. The natural gas derivatives are settled based on the closing price of NYMEX natural gas on the last trading day for the delivery month, which occurs on the third business day preceding the delivery month, or the relevant index prices of natural gas published in Inside FERC’s Gas Market Report on the first business day of the delivery month. The oil derivatives are settled based on the average closing prices of NYMEX WTI and ICE Brent crude oil for each day of the delivery month.
Balance Sheet Presentation
The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed consolidated balance sheets. The following summarizes the fair value of derivatives outstanding on a gross basis:
	September 30,			December 31,
	2014			2013
	(in thousands)
Assets:
Commodity derivatives	$	783,056		$	1,048,212
Liabilities:
Commodity derivatives	$	143,215		$	222,905
By using derivative instruments to economically hedge exposures to changes in commodity prices, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Company, which creates credit risk. The Company’s counterparties are current participants or affiliates of participants in its Credit Facilities or were participants or affiliates of participants in its Credit Facilities at the time it originally entered into the derivatives. The Credit Facilities are secured by the Company’s oil, natural gas and NGL reserves; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties. The maximum amount of loss due to credit risk that the Company would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of financial instruments, was approximately $783 million at September 30, 2014. The Company minimizes the credit risk in derivative instruments by: (i) limiting its exposure to any single counterparty; (ii) entering into derivative instruments only with counterparties that meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity derivatives are subject to counterparty netting under agreements governing such derivatives and therefore the risk of loss due to counterparty nonperformance is somewhat mitigated.
Gains (Losses) on Derivatives
Gains and losses on derivatives were net gains of approximately $452 million for the three months September 30, 2014, and net losses of approximately $199 million for the nine months ended September 30, 2014. Net gains and losses for the three months and nine months ended September 30, 2014, include cash settlement receipts of approximately $10 million and cash settlement payments of approximately $13 million, respectively. Gains and losses on derivatives were net losses of approximately $64 million for the three months ended September 30, 2013, and net gains of approximately $154 million for the nine months ended September 30, 2013. Net gains and losses for the three months and nine months ended September 30, 2013, include cash settlement receipts of approximately $45 million and $190 million, respectively. These amounts are reported on the condensed consolidated statements of operations in “gains (losses) on oil and natural gas derivatives.”

Fair_Value_Measurements_on_a_R

Fair Value Measurements on a Recurring Basis	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements on a Recurring Basis	'
	Fair Value Measurements on a Recurring Basis
	The Company accounts for its commodity derivatives at fair value (see Note 7) on a recurring basis. The Company determines the fair value of its oil and natural gas derivatives utilizing pricing models that use a variety of techniques, including market quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those securities trade in active markets. Assumed credit risk adjustments, based on published credit ratings, public bond yield spreads and credit default swap spreads, are applied to the Company’s commodity derivatives.
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		30-Sep-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	783,056	$	(140,538	)	$	642,518
	Liabilities:
	Commodity derivatives	$	143,215	$	(140,538	)	$	2,677
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	1,048,212	$	(190,080	)	$	858,132
	Liabilities:
	Commodity derivatives	$	222,905	$	(190,080	)	$	32,825
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Asset retirement obligations associated with retiring tangible long-lived assets are recognized as a liability in the period in which a legal obligation is incurred and becomes determinable and are included in “other accrued liabilities” and “other noncurrent liabilities” on the condensed consolidated balance sheets. Accretion expense is included in “depreciation, depletion and amortization” on the condensed consolidated statements of operations. The fair value of additions to the asset retirement obligations is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plug and abandon costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors (2.0% for the nine months ended September 30, 2014); and (iv) a credit-adjusted risk-free interest rate (average of 5.3% for the nine months ended September 30, 2014). These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.
	The following presents a reconciliation of the asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	289,321
	Liabilities added from acquisitions	146,775
	Liabilities added from drilling	8,300
	Liabilities reclassified as held for sale	(15,551		)
	Liabilities associated with assets divested	(2,129		)
	Current year accretion expense	15,203
	Settlements	(10,753		)
	Revision of estimates	9,130
	Asset retirement obligations at September 30, 2014	$	440,296

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	The Company has been named as a defendant in a number of lawsuits, including claims from royalty owners related to disputed royalty payments and royalty valuations. With respect to a certain statewide class action case, the parties in this case are currently engaged in settlement negotiations and based on the current status of those negotiations, the Company estimates a range of possible loss of $1 million to $4.5 million for which an appropriate reserve has been established. For a certain statewide class action royalty payment dispute where a reserve has not yet been established, the Company has denied that it has any liability on the claims and has raised arguments and defenses that, if accepted by the court, will result in no loss to the Company. Briefing and the hearing on class certification are currently scheduled for Summer 2015. The Company is unable to estimate a possible loss, or range of possible loss, if any. In addition, the Company is involved in various other disputes arising in the ordinary course of business. The Company is not currently a party to any litigation or pending claims that it believes would have a material adverse effect on its overall business, financial position, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved.
	Prior to the Company’s acquisition of Berry, Berry became, and continues to be, a defendant in a certain statewide royalty class action case, in which the parties have entered into a settlement agreement to settle past claims for approximately $2.4 million. Subject to approval of the settlement agreement by the court, Berry and the Company anticipate distribution of settlement funds to begin in the fourth quarter of 2014.
	In 2013, several class action complaints were filed and ultimately consolidated in the United States District Court, Southern District of New York (the “Federal Actions”) against LINN Energy, LinnCo, certain of their officers and directors and the various underwriters for LinnCo’s initial public offering. These cases collectively asserted claims based on allegations that LINN Energy made false or misleading statements relating to its (i) hedging strategy, (ii) the cash flow available for distribution to unitholders, and (iii) LINN Energy’s energy production in its Exchange Act filings; and additional claims based on alleged misstatements relating to these issues in the prospectus and registration statement for LinnCo’s initial public offering. Several derivative actions were also filed in federal and state court in Texas, and in the Delaware Court of Chancery (the “Derivative Actions”) asserting derivative claims on behalf of LINN Energy against the individual officers and directors for alleged breaches of fiduciary duty, waste of corporate assets, mismanagement, abuse of control, and unjust enrichment based on factual allegations similar to those in the Federal Actions.
	In July 2014, the Court dismissed the claims of the plaintiffs in the Federal Actions with prejudice, concluding that the plaintiffs failed to demonstrate any material misstatement or omission by LINN Energy or LinnCo, or their officers and directors. The plaintiffs in the Federal Action did not appeal the Court’s dismissal, and the appeals deadline has now passed. The plaintiffs in the Derivative Actions subsequently have dismissed their claims without prejudice.
	During the nine months ended September 30, 2014, and September 30, 2013, the Company made no significant payments to settle any legal, environmental or tax proceedings. The Company regularly analyzes current information and accrues for probable liabilities on the disposition of certain matters as necessary. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.
	In 2008, Lehman Brothers Holdings Inc. and Lehman Brothers Commodity Services Inc. (together “Lehman”), filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code with the U.S. Bankruptcy Court for the Southern District of New York. In March 2011, the Company and Lehman entered into Termination Agreements under which the Company was granted general unsecured claims against Lehman in the amount of $51 million (the “Company Claim”). In December 2011, a Chapter 11 Plan (“Lehman Plan”) was approved by the Bankruptcy Court. Based on the recovery estimates described in the approved disclosure statement relating to the Lehman Plan, the Company expects to ultimately receive a substantial portion of the Company Claim. In April 2014 and April 2013, the Company received approximately $3 million and $5 million, respectively, of the Company Claim of which both amounts are included in “gains (losses) on oil and natural gas derivatives” on the condensed consolidated statements of operations. In the aggregate, the Company has received approximately $42 million of the Company Claim and additional distributions are expected to occur in the future.

Earnings_Per_Unit

Earnings Per Unit	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Unit	'
	Earnings Per Unit
	Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted earnings per unit is computed by adjusting the average number of units outstanding for the dilutive effect, if any, of unit equivalents. The Company uses the treasury stock method to determine the dilutive effect.
	The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net income (loss):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in thousands, except per unit data)
	Net income (loss)	$	(4,100	)	$	(30,060	)	$	(297,307	)	$	93,212
	Allocated to participating securities	(2,097		)	(1,266		)	(6,289		)	(3,796		)
		$	(6,197	)	$	(31,326	)	$	(303,596	)	$	89,416
	Basic net income (loss) per unit	$	(0.02	)	$	(0.13	)	$	(0.92	)	$	0.38
	Diluted net income (loss) per unit	$	(0.02	)	$	(0.13	)	$	(0.92	)	$	0.38
	Basic weighted average units outstanding	329,168			233,552			328,783			233,393
	Dilutive effect of unit equivalents	—			—			—			372
	Diluted weighted average units outstanding	329,168			233,552			328,783			233,765
	Basic units outstanding excludes the effect of weighted average anti-dilutive unit equivalents related to approximately 6 million unit options and warrants for both the three months and nine months ended September 30, 2014, and approximately 4 million and 3 million for the three months and nine months ended September 30, 2013, respectively. All equivalent units were antidilutive for the three months and nine months ended September 30, 2014, and for the three months ended September 30, 2013.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The Company is a limited liability company treated as a partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits of the Company are passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Company’s subsidiaries are Subchapter C-corporations subject to federal and state income taxes. As such, with the exception of the state of Texas and certain subsidiaries, the Company is not a taxable entity, it does not directly pay federal and state income taxes and recognition has not been given to federal and state income taxes for the operations of the Company. Amounts recognized for income taxes are reported in “income tax expense (benefit)” on the condensed consolidated statements of operations.

Supplemental_Disclosures_to_th

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	9 Months Ended
	Sep. 30, 2014
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'
Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	'
	Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows
	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Accrued compensation	$	43,952		$	55,257
	Accrued interest	150,676			93,998
	Asset retirement obligations	12,616			6,270
	Liabilities held for sale	110,241			—
	Other	9,964			7,850
		$	327,449		$	163,375
	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Nine Months Ended
		September 30,
		2014			2013
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	345,687		$	240,261
	Cash payments for income taxes	$	—		$	14
	Noncash investing activities:
	In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:
	Fair value of assets acquired	$	2,743,611		$	47,901
	Cash paid	(2,577,180		)	(28,524		)
	Noncash gain on properties exchange	(48,333		)	—
	Receivables from sellers	42,621			3,654
	Payables to sellers	—			(6,854		)
	Liabilities assumed	$	160,719		$	16,177
	Included in “acquisition of oil and natural gas properties and joint-venture funding” on the condensed consolidated statements of cash flows for the nine months ended September 30, 2014, and September 30, 2013, is approximately $25 million and $112 million, respectively, paid by the Company to fund the commitment related to the joint-venture agreement entered into with Anadarko in April 2012 (see Note 2).
	On August 15, 2014, the Company, through two of its wholly owned subsidiaries, completed a noncash exchange of a portion of its Permian Basin properties to Exxon Mobil Corporation and its affiliates, including its wholly owned subsidiary XTO Energy Inc., for properties in the Hugoton Basin.
	For purposes of the condensed consolidated statements of cash flows, the Company considers all highly liquid short-term investments with original maturities of three months or less to be cash equivalents. Restricted cash of approximately $6 million is included in “other noncurrent assets” on the condensed consolidated balance sheets at September 30, 2014, and December 31, 2013, and primarily represents cash deposited by the Company into a separate account and designated for asset retirement obligations in accordance with contractual agreements.
	The Company manages its working capital and cash requirements to borrow only as needed from its Credit Facilities. At September 30, 2014, and December 31, 2013, net outstanding checks of approximately $85 million and $48 million, respectively, were reclassified and included in “accounts payable and accrued expenses” on the condensed consolidated balance sheets. The Company presents net outstanding checks as cash flows from financing activities on the condensed consolidated statements of cash flows.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	LinnCo
	LinnCo, an affiliate of LINN Energy, was formed on April 30, 2012. LinnCo’s initial sole purpose was to own units in LINN Energy. In connection with the acquisition of Berry, LinnCo amended its limited liability company agreement to permit, among other things, the acquisition and subsequent contribution of assets to LINN Energy. All of LinnCo’s common shares are held by the public. As of September 30, 2014, LinnCo had no significant assets or operations other than those related to its interest in LINN Energy and owned approximately 39% of LINN Energy’s outstanding units.
	LINN Energy has agreed to provide to LinnCo, or to pay on LinnCo’s behalf, any legal, accounting, tax advisory, financial advisory and engineering fees, printing costs or other administrative and out-of-pocket expenses incurred by LinnCo, along with any other expenses incurred in connection with any public offering of shares in LinnCo or incurred as a result of being a publicly traded entity. These expenses include costs associated with annual, quarterly and other reports to holders of LinnCo shares, tax return and Form 1099 preparation and distribution, NASDAQ listing fees, printing costs, independent auditor fees and expenses, legal counsel fees and expenses, limited liability company governance and compliance expenses and registrar and transfer agent fees. In addition, the Company has agreed to indemnify LinnCo and its officers and directors for damages suffered or costs incurred (other than income taxes payable by LinnCo) in connection with carrying out LinnCo’s activities. All expenses and costs paid by LINN Energy on LinnCo’s behalf are accounted for as investment at cost.
	For the three months and nine months ended September 30, 2014, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $644,000 and $2.1 million, respectively, of which approximately $1.9 million had been paid by LINN Energy on LinnCo’s behalf as of September 30, 2014. The expenses for the three months and nine months ended September 30, 2014, include approximately $470,000 and $1.4 million, respectively, related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses. In addition, during the nine months ended September 30, 2014, LINN Energy paid approximately $11 million on LinnCo’s behalf for general and administrative expenses incurred by LinnCo in 2013.
	For the three months and nine months ended September 30, 2013, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $1 million and $15 million, respectively, of which approximately $9 million had been paid by LINN Energy on LinnCo’s behalf as of September 30, 2013. The expenses for the three months and nine months ended September 30, 2013, included approximately $125,000 and $13 million, respectively, of transaction costs related to professional services rendered by third parties in connection with the Berry acquisition. The expenses for the three months and nine months ended September 30, 2013, also included approximately $403,000 and $1 million, respectively, related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses.
	During the three months and nine months ended September 30, 2014, the Company paid approximately $94 million and $280 million, respectively, in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy. During the three months and nine months ended September 30, 2013, the Company paid approximately $25 million and $76 million, respectively, in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy.
	Other
	One of the Company’s directors is the President and Chief Executive Officer of Superior Energy Services, Inc. (“Superior”), which provides oilfield services to the Company. For the three months and nine months ended September 30, 2014, the Company paid approximately $5 million and $17 million, respectively, and for the three months and nine months ended September 30, 2013, the Company paid approximately $7 million and $20 million, respectively, to Superior and its subsidiaries for services rendered to the Company. The transactions associated with these payments were consummated on terms equivalent to those that prevail in arm’s-length transactions.

Subsidiary_Guarantors

Subsidiary Guarantors	9 Months Ended
	Sep. 30, 2014
Condensed Financial Information [Abstract]	'
Subsidiary Guarantors	'
	Subsidiary Guarantors
	LINN Energy, LLC’s May 2019 Senior Notes, November 2019 Senior Notes, September 2021 Senior Notes and 2010 Issued Senior Notes are guaranteed by all of the Company’s material subsidiaries, other than Berry which is an indirect 100% wholly owned subsidiary of the Company. In addition, the Company’s consolidated variable interest entity (“VIE”) is not considered a subsidiary and has not guaranteed any of Linn Energy, LLC’s or Berry Petroleum Company, LLC’s indebtedness; therefore, it is presented separately from the other subsidiaries for these purposes.
	The following condensed consolidating financial information presents the financial information of LINN Energy, LLC, the guarantor subsidiaries, the non-guarantor subsidiary and the non-guarantor VIE in accordance with SEC Regulation S-X Rule 3-10. The condensed consolidating financial information for the co-issuer, Linn Energy Finance Corp., is not presented as it has no assets, operations or cash flows. The financial information may not necessarily be indicative of the financial position or results of operations had the guarantor subsidiaries, non-guarantor subsidiary or non-guarantor VIE operated as independent entities. There are no restrictions on the Company’s ability to obtain cash dividends or other distributions of funds from the guarantor subsidiaries.
	CONDENSED CONSOLIDATING BALANCE SHEETS
	September 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	48		$	11,858		$	6,576		$	40,679		$	—		$	59,161
	Accounts receivable – trade, net	—			343,207			133,775			45,651			—			522,633
	Accounts receivable – affiliates	3,805,769			16,451			—			—			(3,822,220		)	—
	Derivative instruments	—			313,954			23,290			—			—			337,244
	Assets held for sale	—			1,485,270			379,770			—			—			1,865,040
	Other current assets	18			75,817			45,110			44,567			—			165,512
	Total current assets	3,805,835			2,246,557			588,521			130,897			(3,822,220		)	2,949,590
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			10,738,434			4,807,794			2,590,257			—			18,136,485
	Less accumulated depletion and amortization	—			(2,880,850		)	(208,367		)	(10,420		)	—			(3,099,637		)
		—			7,857,584			4,599,427			2,579,837			—			15,036,848
	Other property and equipment	—			508,485			102,496			24,429			—			635,410
	Less accumulated depreciation	—			(142,511		)	(6,024		)	(280		)	—			(148,815		)
		—			365,974			96,472			24,149			—			486,595
	Derivative instruments	—			302,959			2,315			—			—			305,274
	Notes receivable – affiliates	121,500			—			—			—			(121,500		)	—
	Advance to related party	1,285,000			1,285,000			—			—			(2,570,000		)	—
	Investments in consolidated subsidiaries	8,654,255			—			—			—			(8,654,255		)	—
	Other noncurrent assets, net	122,046			11,416			15,225			—			—			148,687
		10,182,801			1,599,375			17,540			—			(11,345,755		)	453,961
	Total noncurrent assets	10,182,801			9,822,933			4,713,439			2,603,986			(11,345,755		)	15,977,404
	Total assets	$	13,988,636		$	12,069,490		$	5,301,960		$	2,734,883		$	(15,167,975	)	$	18,926,994
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	3,656		$	545,494		$	248,181		29,645			$	—		$	826,976
	Accounts payable – affiliates	—			3,805,769			11,228			5,223			(3,822,220		)	—
	Advance from related party	—			1,285,000			—			1,285,000			(2,570,000		)	—
	Derivative instruments	—			1,686			911			—			—			2,597
	Other accrued liabilities	138,877			171,314			17,031			227			—			327,449
	Current portion of long-term debt	—			—			—			1,300,000			—			1,300,000
	Total current liabilities	142,533			5,809,263			277,351			2,620,095			(6,392,220		)	2,457,022
	Noncurrent liabilities:
	Credit facilities	2,510,000			—			1,173,175			—			—			3,683,175
	Term loan	500,000			—			—			—			—			500,000
	Senior notes, net	5,912,739			—			914,232			—			—			6,826,971
	Notes payable – affiliates	—			121,500			—			—			(121,500		)	—
	Derivative instruments	—			80			—			—			—			80
	Other noncurrent liabilities	—			207,082			200,123			120,408			—			527,613
	Total noncurrent liabilities	8,922,739			328,662			2,287,530			120,408			(121,500		)	11,537,839
	Unitholders’ capital:
	Units issued and outstanding	5,621,068			4,833,046			2,483,181			—			(7,307,458		)	5,629,837
	Accumulated income (deficit)	(697,704		)	1,098,519			253,898			(5,620		)	(1,346,797		)	(697,704		)
		4,923,364			5,931,565			2,737,079			(5,620		)	(8,654,255		)	4,932,133
	Total liabilities and unitholders’ capital	$	13,988,636		$	12,069,490		$	5,301,960		$	2,734,883		$	(15,167,975	)	$	18,926,994
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-13
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	52		$	1,078		$	51,041		$	—		$	—		$	52,171
	Accounts receivable – trade, net	—			365,347			122,855			—			—			488,202
Accounts receivable – affiliates	4,212,348			16,950			—			—			(4,229,298		)	—
Derivative instruments	—			170,534			5,596			—			—			176,130
Other current assets	330			68,274			30,833			—			—			99,437
Total current assets	4,212,730			622,183			210,325			—			(4,229,298		)	815,940
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	—			13,074,900			4,813,659			—			—			17,888,559
Less accumulated depletion and amortization	—			(3,535,890		)	(10,394		)	—			—			(3,546,284		)
	—			9,539,010			4,803,265			—			—			14,342,275
Other property and equipment	—			564,756			83,126			—			—			647,882
Less accumulated depreciation	—			(110,706		)	(233		)	—			—			(110,939		)
	—			454,050			82,893			—			—			536,943
Derivative instruments	—			679,491			2,511			—			—			682,002
Notes receivable – affiliates	86,200			—			—			—			(86,200		)	—
Investments in consolidated subsidiaries	8,433,290			—			—			—			(8,433,290		)	—
Other noncurrent assets, net	108,785			10,968			8,051			—			—			127,804
	8,628,275			690,459			10,562			—			(8,519,490		)	809,806
Total noncurrent assets	8,628,275			10,683,519			4,896,720			—			(8,519,490		)	15,689,024
Total assets	$	12,841,005		$	11,305,702		$	5,107,045		$	—		$	(12,748,788	)	$	16,504,964
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	14,529		$	587,774		$	247,321		$	—		$	—		$	849,624
Accounts payable – affiliates	—			4,212,348			16,950			—			(4,229,298		)	—
Derivative instruments	—			7,783			20,393			—			—			28,176
Other accrued liabilities	75,071			59,311			28,993			—			—			163,375
Current portion of long-term debt	—			—			211,558			—			—			211,558
Total current liabilities	89,600			4,867,216			525,215			—			(4,229,298		)	1,252,733
Noncurrent liabilities:
Credit facilities	1,560,000			—			1,173,175			—			—			2,733,175
Term loan	500,000			—			—			—			—			500,000
Senior notes, net	4,809,055			—			916,428			—			—			5,725,483
Notes payable – affiliates	—			86,200			—			—			(86,200		)	—
Derivative instruments	—			—			4,649			—			—			4,649
Other noncurrent liabilities	—			205,406			192,091			—			—			397,497
Total noncurrent liabilities	6,869,055			291,606			2,286,343			—			(86,200		)	9,360,804
Unitholders’ capital:
Units issued and outstanding	6,282,747			4,833,354			2,315,460			—			(7,139,737		)	6,291,824
Accumulated income (deficit)	(400,397		)	1,313,526			(19,973		)	—			(1,293,553		)	(400,397		)
	5,882,350			6,146,880			2,295,487			—			(8,433,290		)	5,891,427
Total liabilities and unitholders’ capital	$	12,841,005		$	11,305,702		$	5,107,045		$	—		$	(12,748,788	)	$	16,504,964
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended September 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	542,535		$	350,863		$	44,060		$	—		$	937,458
Gains on oil and natural gas derivatives	—			406,712			44,990			—			—			451,702
Marketing revenues	—			26,518			13,318			—			—			39,836
Other revenues	—			5,874			245			—			—			6,119
	—			981,639			409,416			44,060			—			1,435,115
Expenses:
Lease operating expenses	—			97,613			83,684			10,333			—			191,630
Transportation expenses	—			36,531			13,326			3,555			—			53,412
Marketing expenses	—			23,871			7,703			—			—			31,574
General and administrative expenses	—			52,580			16,566			6,238			—			75,384
Exploration costs	—			7,850			—			—			—			7,850
Depreciation, depletion and amortization	—			199,360			79,725			11,202			—			290,287
Impairment of long-lived assets	—			603,250			—			—			—			603,250
Taxes, other than income taxes	40			38,598			24,830			3,302			—			66,770
(Gains) losses on sale of assets and other, net	—			(93,257		)	49,011			8,443			—			(35,803		)
	40			966,396			274,845			43,073			—			1,284,354
Other income and (expenses):
Interest expense, net of amounts capitalized	(129,129		)	757			(19,068		)	(6,607		)	—			(154,047		)
Interest expense – affiliates	—			(2,218		)	—			—			2,218			—
Interest income – affiliates	2,218			—			—			—			(2,218		)	—
Equity in earnings from consolidated subsidiaries	124,435			—			—			—			(124,435		)	—
Other, net	(1,584		)	(84		)	(179		)	—			—			(1,847		)
	(4,060		)	(1,545		)	(19,247		)	(6,607		)	(124,435		)	(155,894		)
Income (loss) before income taxes	(4,100		)	13,698			115,324			(5,620		)	(124,435		)	(5,133		)
Income tax expense (benefit)	—			(1,192		)	159			—			—			(1,033		)
Net income (loss)	$	(4,100	)	$	14,890		$	115,165		$	(5,620	)	$	(124,435	)	$	(4,100	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended September 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	537,671		$	—		$	—		$	—		$	537,671
Losses on oil and natural gas derivatives	—			(63,931		)	—			—			—			(63,931		)
Marketing revenues	—			13,484			—			—			—			13,484
Other revenues	—			7,338			—			—			—			7,338
	—			494,562			—			—			—			494,562
Expenses:
Lease operating expenses	—			87,076			—			—			—			87,076
Transportation expenses	—			35,637			—			—			—			35,637
Marketing expenses	—			9,962			—			—			—			9,962
General and administrative expenses	—			45,431			—			—			—			45,431
Exploration costs	—			1,588			—			—			—			1,588
Depreciation, depletion and amortization	—			208,892			—			—			—			208,892
Impairment of long-lived assets	—			(4,240		)	—			—			—			(4,240		)
Taxes, other than income taxes	—			36,457			—			—			—			36,457
Losses on sale of assets and other, net	—			827			—			—			—			827
	—			421,630			—			—			—			421,630
Other income and (expenses):
Interest expense, net of amounts capitalized	(103,252		)	(554		)	—			—			—			(103,806		)
Interest expense – affiliates	—			(1,588		)	—			—			1,588			—
Interest income – affiliates	1,588			—			—			—			(1,588		)	—
Loss on extinguishment of debt	(1,117		)	—			—			—			—			(1,117		)
Equity in earnings from consolidated subsidiaries	75,133			—			—			—			(75,133		)	—
Other, net	(2,412		)	(63		)	—			—			—			(2,475		)
	(30,060		)	(2,205		)	—			—			(75,133		)	(107,398		)
Income (loss) before income taxes	(30,060		)	70,727			—			—			(75,133		)	(34,466		)
Income tax benefit	—			(4,406		)	—			—			—			(4,406		)
Net income (loss)	$	(30,060	)	$	75,133		$	—		$	—		$	(75,133	)	$	(30,060	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Nine Months Ended September 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	1,755,766		$	1,044,359		$	44,060		$	—		$	2,844,185
Gains (losses) on oil and natural gas derivatives	—			(221,472		)	22,893			—			—			(198,579		)
Marketing revenues	—			60,088			40,567			—			—			100,655
Other revenues	—			19,154			238			—			—			19,392
	—			1,613,536			1,108,057			44,060			—			2,765,653
Expenses:
Lease operating expenses	—			293,162			267,069			10,333			—			570,564
Transportation expenses	—			111,539			28,802			3,555			—			143,896
Marketing expenses	—			47,511			28,409			—			—			75,920
General and administrative expenses	—			126,901			88,379			6,238			—			221,518
Exploration costs	—			10,492			—			—			—			10,492
Depreciation, depletion and amortization	—			595,212			226,109			11,202			—			832,523
Impairment of long-lived assets	—			603,250			—			—			—			603,250
Taxes, other than income taxes	40			126,334			71,338			3,302			—			201,014
(Gains) losses on sale of assets and other, net	—			(92,828		)	56,635			8,443			—			(27,750		)
	40			1,821,573			766,741			43,073			—			2,631,427
Other income and (expenses):
Interest expense, net of amounts capitalized	(350,382		)	1,384			(66,555		)	(6,607		)	—			(422,160		)
Interest expense – affiliates	—			(5,627		)	—			—			5,627			—
Interest income – affiliates	5,627			—			—			—			(5,627		)	—
Equity in earnings from consolidated subsidiaries	53,244			—			—			—			(53,244		)	—
Other, net	(5,756		)	(130		)	(813		)	—			—			(6,699		)
	(297,267		)	(4,373		)	(67,368		)	(6,607		)	(53,244		)	(428,859		)
Income (loss) before income taxes	(297,307		)	(212,410		)	273,948			(5,620		)	(53,244		)	(294,633		)
Income tax expense	—			2,597			77			—			—			2,674
Net income (loss)	$	(297,307	)	$	(215,007	)	$	273,871		$	(5,620	)	$	(53,244	)	$	(297,307	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Nine Months Ended September 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	1,488,610		$	—		$	—		$	—		$	1,488,610
Gains on oil and natural gas derivatives	—			154,432			—			—			—			154,432
Marketing revenues	—			40,558			—			—			—			40,558
Other revenues	—			18,847			—			—			—			18,847
	—			1,702,447			—			—			—			1,702,447
Expenses:
Lease operating expenses	—			259,381			—			—			—			259,381
Transportation expenses	—			92,118			—			—			—			92,118
Marketing expenses	—			26,696			—			—			—			26,696
General and administrative expenses	—			150,302			—			—			—			150,302
Exploration costs	—			4,632			—			—			—			4,632
Depreciation, depletion and amortization	—			604,962			—			—			—			604,962
Impairment of long-lived assets	—			37,962			—			—			—			37,962
Taxes, other than income taxes	—			108,525			—			—			—			108,525
Losses on sale of assets and other, net	724			2,316			—			—			—			3,040
	724			1,286,894			—			—			—			1,287,618
Other income and (expenses):
Interest expense, net of amounts capitalized	(307,316		)	(696		)	—			—			—			(308,012		)
Interest expense – affiliates	—			(4,142		)	—			—			4,142			—
Interest income – affiliates	4,142			—			—			—			(4,142		)	—
Loss on extinguishment of debt	(5,304		)	—			—			—			—			(5,304		)
Equity in earnings from consolidated subsidiaries	408,602			—			—			—			(408,602		)	—
Other, net	(6,188		)	(112		)	—			—			—			(6,300		)
	93,936			(4,950		)	—			—			(408,602		)	(319,616		)
Income before income taxes	93,212			410,603			—			—			(408,602		)	95,213
Income tax expense	—			2,001			—			—			—			2,001
Net income	$	93,212		$	408,602		$	—		$	—		$	(408,602	)	$	93,212
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Cash flow from operating activities:
Net income (loss)	$	(297,307	)	$	(215,007	)	$	273,871		$	(5,620	)	$	(53,244	)	$	(297,307	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	—			595,212			226,109			11,202			—			832,523
Impairment of long-lived assets	—			603,250			—			—			—			603,250
Unit-based compensation expenses	—			43,692			—			—			—			43,692
Amortization and write-off of deferred financing fees	31,564			—			(5,174		)	2,846			—			29,236
(Gains) losses on sale of assets and other, net	—			(81,492		)	48,357			—			—			(33,135		)
Equity in earnings from consolidated subsidiaries	(53,244		)	—			—			—			53,244			—
Deferred income taxes	—			2,542			77			—			—			2,619
Derivatives activities:
Total (gains) losses	—			221,472			(22,893		)	—			—			198,579
Cash settlements	—			5,623			(18,130		)	—			—			(12,507		)
Changes in assets and liabilities:
Increase in accounts receivable – trade, net	—			(1,343		)	(10,611		)	(44,060		)	—			(56,014		)
Decrease in accounts receivable – affiliates	469,499			16,950			—			—			(486,449		)	—
(Increase) decrease in other assets	312			(10,723		)	4,551			9,144			—			3,284
(Increase) decrease in accounts payable and accrued expenses	18			107,673			(10,619		)	15,163			—			112,235
Decrease in accounts payable and accrued expenses – affiliates	—			(468,896		)	(5,722		)	(11,831		)	486,449			—
Increase (decrease) in other liabilities	63,806			(18,053		)	(36,626		)	228			—			9,355
Net cash provided by (used in) operating activities	214,648			800,900			443,190			(22,928		)	—			1,435,810
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(76,627		)	(3,912		)	(2,521,393		)	—			(2,601,932		)
Development of oil and natural gas properties	—			(750,450		)	(426,028		)	—			—			(1,176,478		)
Purchases of other property and equipment	—			(41,822		)	(8,316		)	—			—			(50,138		)
Investment in affiliates	(167,721		)	—			—			—			167,721			—
Change in notes receivable with affiliate	(35,300		)	—			—			—			35,300			—
Advance to related party	(1,285,000		)	(1,285,000		)	—			—			2,570,000			—
Proceeds from sale of properties and equipment and other	(13,188		)	5,447			256			—			—			(7,485		)
Net cash used in investing activities	(1,501,209		)	(2,148,452		)	(438,000		)	(2,521,393		)	2,773,021			(3,836,033		)
Cash flow from financing activities:
Proceeds from borrowings	4,000,024			—			—			1,300,000			—			5,300,024
Repayments of debt	(1,950,000		)	—			(206,124		)	—			—			(2,156,124		)
Distributions to unitholders	(721,235		)	—			—			—			—			(721,235		)
Financing fees and other, net	(46,263		)	38,032			(11,252		)	—			—			(19,483		)
Change in notes payable with affiliate	—			35,300			—			—			(35,300		)	—
Advance from related party	—			1,285,000			—			1,285,000			(2,570,000		)	—
Capital contributions – affiliates	—			—			167,721			—			(167,721		)	—
Excess tax benefit from unit-based compensation	4,031			—			—			—			—			4,031
Net cash provided by (used in) financing activities	1,286,557			1,358,332			(49,655		)	2,585,000			(2,773,021		)	2,407,213
Net increase (decrease) in cash and cash equivalents	(4		)	10,780			(44,465		)	40,679			—			6,990
Cash and cash equivalents:
Beginning	52			1,078			51,041			—			—			52,171
Ending	$	48		$	11,858		$	6,576		$	40,679		$	—		$	59,161
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Cash flow from operating activities:
Net income	$	93,212		$	408,602		$	—		—			$	(408,602	)	$	93,212
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	—			604,962			—			—			—			604,962
Impairment of long-lived assets	—			37,962			—			—			—			37,962
Unit-based compensation expenses	—			29,261			—			—			—			29,261
Loss on extinguishment of debt	5,304			—			—			—			—			5,304
Amortization and write-off of deferred financing fees	16,392			—			—			—			—			16,392
Losses on sale of assets and other, net	—			18,744			—			—			—			18,744
Equity in earnings from consolidated subsidiaries	(408,602		)	—			—			—			408,602			—
Deferred income taxes	—			731			—			—			—			731
Derivatives activities:
Total gains	—			(154,432		)	—			—			—			(154,432		)
Cash settlements	—			190,368			—			—			—			190,368
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	—			22,877			—			—			—			22,877
Decrease in accounts receivable – affiliates	341,730			—			—			—			(341,730		)	—
(Increase) decrease in other assets	(330		)	9,507			—			—			—			9,177
Increase in accounts payable and accrued expenses	—			29,445			—			—			—			29,445
Decrease in accounts payable and accrued expenses – affiliates	—			(341,730		)	—			—			341,730			—
Increase (decrease) in other liabilities	51,069			(14,561		)	—			—			—			36,508
Net cash provided by operating activities	98,775			841,736			—			—			—			940,511
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(192,871		)	—			—			—			(192,871		)
Development of oil and natural gas properties	—			(767,604		)	—			—			—			(767,604		)
Purchases of other property and equipment	—			(76,987		)	—			—			—			(76,987		)
Change in notes receivable with affiliate	(38,200		)	—			—			—			38,200			—
Proceeds from sale of properties and equipment and other	(9,044		)	219,341			—			—			—			210,297
Net cash used in investing activities	(47,244		)	(818,121		)	—			—			38,200			(827,165		)
Cash flow from financing activities:
Proceeds from borrowings	1,260,000			—			—			—			—			1,260,000
Repayments of debt	(789,898		)	—			—			—			—			(789,898		)
Distributions to unitholders	(511,686		)	—			—			—			—			(511,686		)
Financing fees and other, net	(13,490		)	(32,195		)	—			—			—			(45,685		)
Change in notes payable with affiliate	—			38,200			—			—			(38,200		)	—
Excess tax benefit from unit-based compensation	—			160			—			—			—			160
Net cash provided by (used in) financing activities	(55,074		)	6,165			—			—			(38,200		)	(87,109		)
Net increase (decrease) in cash and cash equivalents	(3,543		)	29,780			—			—			—			26,237
Cash and cash equivalents:
Beginning	107			1,136			—			—			—			1,243
Ending	$	(3,436	)	$	30,916		$	—		$	—		$	—		$	27,480

SEC_Inquiry

SEC Inquiry	9 Months Ended
	Sep. 30, 2014
SEC Inquiry [Abstract]	'
SEC Inquiry	'
	SEC Inquiry
	As disclosed on July 1, 2013, the Company and its affiliate, LinnCo, have been notified by the staff of the SEC that its Fort Worth Regional Office has commenced an inquiry regarding LINN Energy and LinnCo (the “SEC inquiry”). The SEC staff is investigating whether any violations of federal securities laws have occurred. The SEC staff has stated that the fact of the inquiry should not be construed as an indication that the SEC or its staff has a negative view of any entity, individual or security. Both LINN Energy and LinnCo are cooperating fully with the SEC in this matter. LINN Energy and LinnCo are unable to predict the timing or outcome of the SEC inquiry or estimate the nature or amount of any possible sanction the SEC could seek to impose, which could include a fine, penalty, or court or administrative order prohibiting specific conduct, or a potential restatement of LINN Energy’s or LinnCo’s financial statements, any of which could be material. No provision for losses has been recorded for this exposure.

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Principles of Consolidation and Reporting	'
	Principles of Consolidation and Reporting
	The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. The condensed consolidated financial statements also include the accounts of a variable interest entity where the Company is the primary beneficiary of the arrangements. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The Company’s other investment is accounted for at cost.
	The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ capital or cash flows.
Use of Estimates	'
	Use of Estimates
	The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
Recently Issued Accounting Standards	'
	Recently Issued Accounting Standards
	In May 2014, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 2016, and interim periods within those years (early adoption prohibited). The Company is currently evaluating the impact, if any, of the adoption of this ASU on its consolidated financial statements and related disclosures.
	In April 2014, the FASB issued an ASU that changes the criteria for reporting discontinued operations and enhances disclosures in this area. This ASU is effective for annual and interim periods beginning after December 15, 2014, with early adoption permitted for disposals or for assets classified as held for sale that have not been reported in previously issued financial statements. The Company early adopted this ASU on a prospective basis beginning with the third quarter of 2014. The adoption had no effect on the Company’s consolidated financial statements.

Acquisitions_Divestitures_and_1

Acquisitions, Divestitures and Joint-Venture Funding (Tables)	9 Months Ended
	Sep. 30, 2014
Business Combinations [Abstract]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	'
	The following presents the values assigned to the net assets acquired as of the acquisition dates (in thousands):
	Assets:
	Current	$	22,604
	Oil and natural gas properties	2,637,856
	Other property and equipment	83,151
	Total assets acquired	2,743,611
	Liabilities:
	Current	16,074
	Asset retirement obligations	144,645
	Total liabilities assumed	160,719
	Net assets acquired	$	2,582,892
Schedule of Pro Forma Results of Business Combination	'
	The pro forma financial information does not give effect to the costs of any integration activities or benefits that may result from the realization of future cost savings from operating efficiencies, or any other synergies that may result from the transactions and changes in commodity and share prices.
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014			2013
		(in thousands, except per unit amounts)
	Total revenues and other	1,509,498		902,733		3,117,792			2,978,108
	Total operating expenses	1,331,861		717,032		2,852,327			2,150,170
	Net income (loss)	3		25,262		(257,158		)	334,272
	Net income (loss) per unit:
	Basic	$	—	$	0.08	$	(0.80	)	$	1.01
	Diluted	$	—	$	0.08	$	(0.80	)	$	1.01
	The pro forma condensed combined statements of operations include adjustments to:
	•	Reflect the results of the Devon Assets Acquisition and the Berry acquisition for all periods presented.
	•	Reflect incremental depreciation, depletion and amortization expense, using the units-of-production method, related to oil and natural gas properties acquired and using an estimated useful life of 10 years for the Devon Assets Acquisition and 20 years for the Berry acquisition for other property and equipment.
	•	Reflect accretion expense related to asset retirement obligations on oil and natural gas properties acquired in the Devon Assets Acquisition.
	•	Reflect an increase in interest expense related to incremental debt of $2.3 billion incurred to fund the purchase price of the Devon Assets Acquisition and a reduction in interest expense related to the amortization of the adjustment to fair value of Berry’s debt using the effective interest method.
	•	Reflect incremental amortization of deferred financing fees associated with debt incurred to fund the purchase price of the Devon Assets Acquisition.
	•	Exclude transaction costs related to the Devon Assets Acquisition and the Berry acquisition included in the historical statements of operations as they reflect nonrecurring charges not expected to have a continuing impact on the combined results.
	•	Reflect approximately 93.8 million LINN Energy units assumed to be issued on January 1, 2013, in conjunction with the Berry acquisition.

Oil_and_Natural_Gas_Properties1

Oil and Natural Gas Properties (Tables)	9 Months Ended
	Sep. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities	'
	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	13,045,461		$	12,277,089
	Development	3,047,527			3,660,277
	Unproved properties	2,043,497			1,951,193
		18,136,485			17,888,559
	Less accumulated depletion and amortization	(3,099,637		)	(3,546,284		)
		$	15,036,848		$	14,342,275

UnitBased_Compensation_Tables

Unit-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Employee Service Share-Based Compensation Expense	'
	A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	General and administrative expenses	$	9,445	$	8,407	$	37,164	$	25,408
	Lease operating expenses	1,664		1,279		6,528		3,853
	Total unit-based compensation expenses	$	11,109	$	9,686	$	43,692	$	29,261
	Income tax benefit	$	4,105	$	3,579	$	16,144	$	10,812

Debt_Tables

Debt (Tables)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Summary of Outstanding Debt	'
	The following summarizes the Company’s outstanding debt:
		September 30,			31-Dec-13
		2014
		(in thousands, except percentages)
	LINN credit facility (1)	$	2,510,000		$	1,560,000
	Berry credit facility (2)	1,173,175			1,173,175
	LINN term loan (2)	500,000			500,000
	VIE term loan (3)	1,300,000			—
	10.25% Berry senior notes due June 2014	—			205,257
	6.50% senior notes due May 2019 (4)	1,200,000			750,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,300,000			1,300,000
	6.75% Berry senior notes due November 2020	299,970			300,000
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.50% senior notes due September 2021 (4)	650,000			—
	6.375% Berry senior notes due September 2022	599,163			600,000
	Net unamortized discounts and premiums	(22,162		)	(18,216		)
	Total debt, net	12,310,146			9,170,216
	Less current maturities	(1,300,000		)	(211,558		)
	Total long-term debt, net	$	11,010,146		$	8,958,658
	(1)	Variable interest rates of 2.15% and 1.92% at September 30, 2014, and December 31, 2013, respectively.
	(2)	Variable interest rates of 2.66% and 2.67% at September 30, 2014, and December 31, 2013, respectively.
	(3)	Variable interest rate of 3.15% at September 30, 2014. Incurred on August 29, 2014.
	(4)	$450 million of senior notes due May 2019 and $650 million of senior notes due September 2021 were issued on September 9, 2014.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	'
		30-Sep-14						December 31, 2013
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facilities	$	3,683,175		$	3,683,175		$	2,733,175	$	2,733,175
	Term loans	1,800,000			1,800,000			500,000		500,000
	Senior notes, net	6,826,971			6,821,718			5,937,041		6,162,402
	Total debt, net	$	12,310,146		$	12,304,893		$	9,170,216	$	9,395,577

Derivatives_Tables

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments	'
	The following table summarizes derivative positions for the periods indicated as of September 30, 2014:
		October 1 - December 31, 2014			2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	24,550			118,041			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.25		$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	20,071			71,854			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	5		$	4.88		$	—
		October 1 - December 31, 2014			2015			2016			2017			2018
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	4,242			11,599			11,465			4,755			—
	Average price ($/Bbl)	$	92.44		$	96.23		$	90.56		$	89.02		$	—
	Collars (NYMEX WTI):
	Hedged volume (MBbls)	184			—			—			—			—
	Average floor price ($/Bbl)	$	90		$	—		$	—		$	—		$	—
	Average ceiling price ($/Bbl)	$	102.87		$	—		$	—		$	—		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	782			1,095			—			—			—
	Short put ($/Bbl)	$	72.11		$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	93.76		$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	109.79		$	101.62		$	—		$	—		$	—
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	998			3,426			3,271			384			—
	Average price ($/Bbl)	$	91.3		$	90		$	90		$	90		$	—
	Three-way collars (ICE Brent):
	Hedged volume (MBbls)	92			—			—			—			—
	Short put ($/Bbl)	$	80		$	—		$	—		$	—		$	—
	Long put ($/Bbl)	$	100		$	—		$	—		$	—		$	—
	Short call ($/Bbl)	$	114.05		$	—		$	—		$	—		$	—
	Natural gas basis differential positions: (2)
	Panhandle basis swaps:
	Hedged volume (MMMBtu)	20,010			87,162			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps:
	Hedged volume (MMMBtu)	10,398			43,292			46,294			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.20	)	$	(0.20	)	$	(0.20	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps:
	Hedged volume (MMMBtu)	2,392			9,344			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.08		$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps:
	Hedged volume (MMMBtu)	1,325			4,891			4,575			3,604			986
	Hedged differential ($/MMBtu)	$	(0.10	)	$	(0.10	)	$	(0.10	)	$	(0.08	)	$	(0.08	)
	Permian basis swaps:
	Hedged volume (MMMBtu)	1,233			5,074			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	Oil basis differential positions:
	ICE Brent - NYMEX WTI basis swaps:
	Hedged volume (MBbls)	920			2,920			—			—			—
	Hedged differential ($/Bbl)	$	11.6		$	11.6		$	—		$	—		$	—
		October 1 - December 31, 2014			2015			2016			2017			2018
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (3)
	Hedged volume (MBbls)	2,289			7,251			7,446			6,486			—
	Hedged differential ($/Bbl)	$	0.24		$	0.24		$	0.25		$	0.25		$	—
	(1)	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
	(2)	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
	(3)	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).
Fair Value of Derivatives Outstanding on a Gross Basis by Location on the Balance Sheet	'
	The following summarizes the fair value of derivatives outstanding on a gross basis:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Assets:
	Commodity derivatives	$	783,056		$	1,048,212
	Liabilities:
	Commodity derivatives	$	143,215		$	222,905

Fair_Value_Measurements_on_a_R1

Fair Value Measurements on a Recurring Basis (Tables)	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Recurring Basis	'
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		30-Sep-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	783,056	$	(140,538	)	$	642,518
	Liabilities:
	Commodity derivatives	$	143,215	$	(140,538	)	$	2,677
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	1,048,212	$	(190,080	)	$	858,132
	Liabilities:
	Commodity derivatives	$	222,905	$	(190,080	)	$	32,825
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations Reconciliation	'
	The following presents a reconciliation of the asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	289,321
	Liabilities added from acquisitions	146,775
	Liabilities added from drilling	8,300
	Liabilities reclassified as held for sale	(15,551		)
	Liabilities associated with assets divested	(2,129		)
	Current year accretion expense	15,203
	Settlements	(10,753		)
	Revision of estimates	9,130
	Asset retirement obligations at September 30, 2014	$	440,296

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Reconciliation of numerators and denominators of the basic and diluted per unit computations for net income (loss)	'
	The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net income (loss):
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in thousands, except per unit data)
	Net income (loss)	$	(4,100	)	$	(30,060	)	$	(297,307	)	$	93,212
	Allocated to participating securities	(2,097		)	(1,266		)	(6,289		)	(3,796		)
		$	(6,197	)	$	(31,326	)	$	(303,596	)	$	89,416
	Basic net income (loss) per unit	$	(0.02	)	$	(0.13	)	$	(0.92	)	$	0.38
	Diluted net income (loss) per unit	$	(0.02	)	$	(0.13	)	$	(0.92	)	$	0.38
	Basic weighted average units outstanding	329,168			233,552			328,783			233,393
	Dilutive effect of unit equivalents	—			—			—			372
	Diluted weighted average units outstanding	329,168			233,552			328,783			233,765

Supplemental_Disclosures_to_th1

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Tables)	9 Months Ended
	Sep. 30, 2014
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'
Other Accrued Liabilities	'
	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Accrued compensation	$	43,952		$	55,257
	Accrued interest	150,676			93,998
	Asset retirement obligations	12,616			6,270
	Liabilities held for sale	110,241			—
	Other	9,964			7,850
		$	327,449		$	163,375
Supplemental Disclosures to the Condensed Conslidated Statements of Cash Flow	'
	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Nine Months Ended
		September 30,
		2014			2013
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	345,687		$	240,261
	Cash payments for income taxes	$	—		$	14
	Noncash investing activities:
	In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:
	Fair value of assets acquired	$	2,743,611		$	47,901
	Cash paid	(2,577,180		)	(28,524		)
	Noncash gain on properties exchange	(48,333		)	—
	Receivables from sellers	42,621			3,654
	Payables to sellers	—			(6,854		)
	Liabilities assumed	$	160,719		$	16,177

Subsidiary_Guarantors_Tables

Subsidiary Guarantors (Tables)	9 Months Ended
	Sep. 30, 2014
Condensed Financial Information [Abstract]	'
Condensed Consolidating Balance Sheets	'
	CONDENSED CONSOLIDATING BALANCE SHEETS
	September 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	48		$	11,858		$	6,576		$	40,679		$	—		$	59,161
	Accounts receivable – trade, net	—			343,207			133,775			45,651			—			522,633
	Accounts receivable – affiliates	3,805,769			16,451			—			—			(3,822,220		)	—
	Derivative instruments	—			313,954			23,290			—			—			337,244
	Assets held for sale	—			1,485,270			379,770			—			—			1,865,040
	Other current assets	18			75,817			45,110			44,567			—			165,512
	Total current assets	3,805,835			2,246,557			588,521			130,897			(3,822,220		)	2,949,590
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			10,738,434			4,807,794			2,590,257			—			18,136,485
	Less accumulated depletion and amortization	—			(2,880,850		)	(208,367		)	(10,420		)	—			(3,099,637		)
		—			7,857,584			4,599,427			2,579,837			—			15,036,848
	Other property and equipment	—			508,485			102,496			24,429			—			635,410
	Less accumulated depreciation	—			(142,511		)	(6,024		)	(280		)	—			(148,815		)
		—			365,974			96,472			24,149			—			486,595
	Derivative instruments	—			302,959			2,315			—			—			305,274
	Notes receivable – affiliates	121,500			—			—			—			(121,500		)	—
	Advance to related party	1,285,000			1,285,000			—			—			(2,570,000		)	—
	Investments in consolidated subsidiaries	8,654,255			—			—			—			(8,654,255		)	—
	Other noncurrent assets, net	122,046			11,416			15,225			—			—			148,687
		10,182,801			1,599,375			17,540			—			(11,345,755		)	453,961
	Total noncurrent assets	10,182,801			9,822,933			4,713,439			2,603,986			(11,345,755		)	15,977,404
	Total assets	$	13,988,636		$	12,069,490		$	5,301,960		$	2,734,883		$	(15,167,975	)	$	18,926,994
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	3,656		$	545,494		$	248,181		29,645			$	—		$	826,976
	Accounts payable – affiliates	—			3,805,769			11,228			5,223			(3,822,220		)	—
	Advance from related party	—			1,285,000			—			1,285,000			(2,570,000		)	—
	Derivative instruments	—			1,686			911			—			—			2,597
	Other accrued liabilities	138,877			171,314			17,031			227			—			327,449
	Current portion of long-term debt	—			—			—			1,300,000			—			1,300,000
	Total current liabilities	142,533			5,809,263			277,351			2,620,095			(6,392,220		)	2,457,022
	Noncurrent liabilities:
	Credit facilities	2,510,000			—			1,173,175			—			—			3,683,175
	Term loan	500,000			—			—			—			—			500,000
	Senior notes, net	5,912,739			—			914,232			—			—			6,826,971
	Notes payable – affiliates	—			121,500			—			—			(121,500		)	—
	Derivative instruments	—			80			—			—			—			80
	Other noncurrent liabilities	—			207,082			200,123			120,408			—			527,613
	Total noncurrent liabilities	8,922,739			328,662			2,287,530			120,408			(121,500		)	11,537,839
	Unitholders’ capital:
	Units issued and outstanding	5,621,068			4,833,046			2,483,181			—			(7,307,458		)	5,629,837
	Accumulated income (deficit)	(697,704		)	1,098,519			253,898			(5,620		)	(1,346,797		)	(697,704		)
		4,923,364			5,931,565			2,737,079			(5,620		)	(8,654,255		)	4,932,133
	Total liabilities and unitholders’ capital	$	13,988,636		$	12,069,490		$	5,301,960		$	2,734,883		$	(15,167,975	)	$	18,926,994
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-13
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	52		$	1,078		$	51,041		$	—		$	—		$	52,171
	Accounts receivable – trade, net	—			365,347			122,855			—			—			488,202
	Accounts receivable – affiliates	4,212,348			16,950			—			—			(4,229,298		)	—
	Derivative instruments	—			170,534			5,596			—			—			176,130
	Other current assets	330			68,274			30,833			—			—			99,437
Total current assets	4,212,730			622,183			210,325			—			(4,229,298		)	815,940
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	—			13,074,900			4,813,659			—			—			17,888,559
Less accumulated depletion and amortization	—			(3,535,890		)	(10,394		)	—			—			(3,546,284		)
	—			9,539,010			4,803,265			—			—			14,342,275
Other property and equipment	—			564,756			83,126			—			—			647,882
Less accumulated depreciation	—			(110,706		)	(233		)	—			—			(110,939		)
	—			454,050			82,893			—			—			536,943
Derivative instruments	—			679,491			2,511			—			—			682,002
Notes receivable – affiliates	86,200			—			—			—			(86,200		)	—
Investments in consolidated subsidiaries	8,433,290			—			—			—			(8,433,290		)	—
Other noncurrent assets, net	108,785			10,968			8,051			—			—			127,804
	8,628,275			690,459			10,562			—			(8,519,490		)	809,806
Total noncurrent assets	8,628,275			10,683,519			4,896,720			—			(8,519,490		)	15,689,024
Total assets	$	12,841,005		$	11,305,702		$	5,107,045		$	—		$	(12,748,788	)	$	16,504,964
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	14,529		$	587,774		$	247,321		$	—		$	—		$	849,624
Accounts payable – affiliates	—			4,212,348			16,950			—			(4,229,298		)	—
Derivative instruments	—			7,783			20,393			—			—			28,176
Other accrued liabilities	75,071			59,311			28,993			—			—			163,375
Current portion of long-term debt	—			—			211,558			—			—			211,558
Total current liabilities	89,600			4,867,216			525,215			—			(4,229,298		)	1,252,733
Noncurrent liabilities:
Credit facilities	1,560,000			—			1,173,175			—			—			2,733,175
Term loan	500,000			—			—			—			—			500,000
Senior notes, net	4,809,055			—			916,428			—			—			5,725,483
Notes payable – affiliates	—			86,200			—			—			(86,200		)	—
Derivative instruments	—			—			4,649			—			—			4,649
Other noncurrent liabilities	—			205,406			192,091			—			—			397,497
Total noncurrent liabilities	6,869,055			291,606			2,286,343			—			(86,200		)	9,360,804
Unitholders’ capital:
Units issued and outstanding	6,282,747			4,833,354			2,315,460			—			(7,139,737		)	6,291,824
Accumulated income (deficit)	(400,397		)	1,313,526			(19,973		)	—			(1,293,553		)	(400,397		)
	5,882,350			6,146,880			2,295,487			—			(8,433,290		)	5,891,427
Total liabilities and unitholders’ capital	$	12,841,005		$	11,305,702		$	5,107,045		$	—		$	(12,748,788	)	$	16,504,964
Condensed Consolidating Statements of Operations	'
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Nine Months Ended September 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	1,755,766		$	1,044,359		$	44,060		$	—		$	2,844,185
	Gains (losses) on oil and natural gas derivatives	—			(221,472		)	22,893			—			—			(198,579		)
	Marketing revenues	—			60,088			40,567			—			—			100,655
	Other revenues	—			19,154			238			—			—			19,392
		—			1,613,536			1,108,057			44,060			—			2,765,653
	Expenses:
	Lease operating expenses	—			293,162			267,069			10,333			—			570,564
	Transportation expenses	—			111,539			28,802			3,555			—			143,896
	Marketing expenses	—			47,511			28,409			—			—			75,920
	General and administrative expenses	—			126,901			88,379			6,238			—			221,518
	Exploration costs	—			10,492			—			—			—			10,492
	Depreciation, depletion and amortization	—			595,212			226,109			11,202			—			832,523
	Impairment of long-lived assets	—			603,250			—			—			—			603,250
	Taxes, other than income taxes	40			126,334			71,338			3,302			—			201,014
	(Gains) losses on sale of assets and other, net	—			(92,828		)	56,635			8,443			—			(27,750		)
		40			1,821,573			766,741			43,073			—			2,631,427
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(350,382		)	1,384			(66,555		)	(6,607		)	—			(422,160		)
	Interest expense – affiliates	—			(5,627		)	—			—			5,627			—
	Interest income – affiliates	5,627			—			—			—			(5,627		)	—
	Equity in earnings from consolidated subsidiaries	53,244			—			—			—			(53,244		)	—
	Other, net	(5,756		)	(130		)	(813		)	—			—			(6,699		)
		(297,267		)	(4,373		)	(67,368		)	(6,607		)	(53,244		)	(428,859		)
	Income (loss) before income taxes	(297,307		)	(212,410		)	273,948			(5,620		)	(53,244		)	(294,633		)
	Income tax expense	—			2,597			77			—			—			2,674
	Net income (loss)	$	(297,307	)	$	(215,007	)	$	273,871		$	(5,620	)	$	(53,244	)	$	(297,307	)
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Nine Months Ended September 30, 2013
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	1,488,610		$	—		$	—		$	—		$	1,488,610
	Gains on oil and natural gas derivatives	—			154,432			—			—			—			154,432
	Marketing revenues	—			40,558			—			—			—			40,558
	Other revenues	—			18,847			—			—			—			18,847
		—			1,702,447			—			—			—			1,702,447
	Expenses:
	Lease operating expenses	—			259,381			—			—			—			259,381
	Transportation expenses	—			92,118			—			—			—			92,118
	Marketing expenses	—			26,696			—			—			—			26,696
	General and administrative expenses	—			150,302			—			—			—			150,302
	Exploration costs	—			4,632			—			—			—			4,632
	Depreciation, depletion and amortization	—			604,962			—			—			—			604,962
	Impairment of long-lived assets	—			37,962			—			—			—			37,962
	Taxes, other than income taxes	—			108,525			—			—			—			108,525
	Losses on sale of assets and other, net	724			2,316			—			—			—			3,040
		724			1,286,894			—			—			—			1,287,618
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(307,316		)	(696		)	—			—			—			(308,012		)
	Interest expense – affiliates	—			(4,142		)	—			—			4,142			—
	Interest income – affiliates	4,142			—			—			—			(4,142		)	—
	Loss on extinguishment of debt	(5,304		)	—			—			—			—			(5,304		)
	Equity in earnings from consolidated subsidiaries	408,602			—			—			—			(408,602		)	—
	Other, net	(6,188		)	(112		)	—			—			—			(6,300		)
		93,936			(4,950		)	—			—			(408,602		)	(319,616		)
	Income before income taxes	93,212			410,603			—			—			(408,602		)	95,213
Income tax expense	—			2,001			—			—			—			2,001
Net income	$	93,212		$	408,602		$	—		$	—		$	(408,602	)	$	93,212
Condensed Consolidating Statements of Cash Flows	'
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Nine Months Ended September 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	Cash flow from operating activities:
	Net income (loss)	$	(297,307	)	$	(215,007	)	$	273,871		$	(5,620	)	$	(53,244	)	$	(297,307	)
	Adjustments to reconcile net income (loss) to net cash provided by operating activities:
	Depreciation, depletion and amortization	—			595,212			226,109			11,202			—			832,523
	Impairment of long-lived assets	—			603,250			—			—			—			603,250
	Unit-based compensation expenses	—			43,692			—			—			—			43,692
	Amortization and write-off of deferred financing fees	31,564			—			(5,174		)	2,846			—			29,236
	(Gains) losses on sale of assets and other, net	—			(81,492		)	48,357			—			—			(33,135		)
	Equity in earnings from consolidated subsidiaries	(53,244		)	—			—			—			53,244			—
	Deferred income taxes	—			2,542			77			—			—			2,619
	Derivatives activities:
	Total (gains) losses	—			221,472			(22,893		)	—			—			198,579
	Cash settlements	—			5,623			(18,130		)	—			—			(12,507		)
	Changes in assets and liabilities:
	Increase in accounts receivable – trade, net	—			(1,343		)	(10,611		)	(44,060		)	—			(56,014		)
	Decrease in accounts receivable – affiliates	469,499			16,950			—			—			(486,449		)	—
	(Increase) decrease in other assets	312			(10,723		)	4,551			9,144			—			3,284
	(Increase) decrease in accounts payable and accrued expenses	18			107,673			(10,619		)	15,163			—			112,235
	Decrease in accounts payable and accrued expenses – affiliates	—			(468,896		)	(5,722		)	(11,831		)	486,449			—
	Increase (decrease) in other liabilities	63,806			(18,053		)	(36,626		)	228			—			9,355
	Net cash provided by (used in) operating activities	214,648			800,900			443,190			(22,928		)	—			1,435,810
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	Cash flow from investing activities:
	Acquisition of oil and natural gas properties and joint-venture funding	—			(76,627		)	(3,912		)	(2,521,393		)	—			(2,601,932		)
	Development of oil and natural gas properties	—			(750,450		)	(426,028		)	—			—			(1,176,478		)
	Purchases of other property and equipment	—			(41,822		)	(8,316		)	—			—			(50,138		)
	Investment in affiliates	(167,721		)	—			—			—			167,721			—
	Change in notes receivable with affiliate	(35,300		)	—			—			—			35,300			—
	Advance to related party	(1,285,000		)	(1,285,000		)	—			—			2,570,000			—
	Proceeds from sale of properties and equipment and other	(13,188		)	5,447			256			—			—			(7,485		)
	Net cash used in investing activities	(1,501,209		)	(2,148,452		)	(438,000		)	(2,521,393		)	2,773,021			(3,836,033		)
	Cash flow from financing activities:
	Proceeds from borrowings	4,000,024			—			—			1,300,000			—			5,300,024
	Repayments of debt	(1,950,000		)	—			(206,124		)	—			—			(2,156,124		)
	Distributions to unitholders	(721,235		)	—			—			—			—			(721,235		)
	Financing fees and other, net	(46,263		)	38,032			(11,252		)	—			—			(19,483		)
	Change in notes payable with affiliate	—			35,300			—			—			(35,300		)	—
	Advance from related party	—			1,285,000			—			1,285,000			(2,570,000		)	—
	Capital contributions – affiliates	—			—			167,721			—			(167,721		)	—
	Excess tax benefit from unit-based compensation	4,031			—			—			—			—			4,031
	Net cash provided by (used in) financing activities	1,286,557			1,358,332			(49,655		)	2,585,000			(2,773,021		)	2,407,213
	Net increase (decrease) in cash and cash equivalents	(4		)	10,780			(44,465		)	40,679			—			6,990
	Cash and cash equivalents:
	Beginning	52			1,078			51,041			—			—			52,171
	Ending	$	48		$	11,858		$	6,576		$	40,679		$	—		$	59,161
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Nine Months Ended September 30, 2013
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
								Guarantor Subsidiary			Guarantor VIE
		(in thousands)
	Cash flow from operating activities:
	Net income	$	93,212		$	408,602		$	—		—			$	(408,602	)	$	93,212
	Adjustments to reconcile net income to net cash provided by operating activities:
	Depreciation, depletion and amortization	—			604,962			—			—			—			604,962
	Impairment of long-lived assets	—			37,962			—			—			—			37,962
	Unit-based compensation expenses	—			29,261			—			—			—			29,261
Loss on extinguishment of debt	5,304			—			—			—			—			5,304
Amortization and write-off of deferred financing fees	16,392			—			—			—			—			16,392
Losses on sale of assets and other, net	—			18,744			—			—			—			18,744
Equity in earnings from consolidated subsidiaries	(408,602		)	—			—			—			408,602			—
Deferred income taxes	—			731			—			—			—			731
Derivatives activities:
Total gains	—			(154,432		)	—			—			—			(154,432		)
Cash settlements	—			190,368			—			—			—			190,368
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	—			22,877			—			—			—			22,877
Decrease in accounts receivable – affiliates	341,730			—			—			—			(341,730		)	—
(Increase) decrease in other assets	(330		)	9,507			—			—			—			9,177
Increase in accounts payable and accrued expenses	—			29,445			—			—			—			29,445
Decrease in accounts payable and accrued expenses – affiliates	—			(341,730		)	—			—			341,730			—
Increase (decrease) in other liabilities	51,069			(14,561		)	—			—			—			36,508
Net cash provided by operating activities	98,775			841,736			—			—			—			940,511
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Non-			Eliminations			Consolidated
							Guarantor Subsidiary			Guarantor VIE
	(in thousands)
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(192,871		)	—			—			—			(192,871		)
Development of oil and natural gas properties	—			(767,604		)	—			—			—			(767,604		)
Purchases of other property and equipment	—			(76,987		)	—			—			—			(76,987		)
Change in notes receivable with affiliate	(38,200		)	—			—			—			38,200			—
Proceeds from sale of properties and equipment and other	(9,044		)	219,341			—			—			—			210,297
Net cash used in investing activities	(47,244		)	(818,121		)	—			—			38,200			(827,165		)
Cash flow from financing activities:
Proceeds from borrowings	1,260,000			—			—			—			—			1,260,000
Repayments of debt	(789,898		)	—			—			—			—			(789,898		)
Distributions to unitholders	(511,686		)	—			—			—			—			(511,686		)
Financing fees and other, net	(13,490		)	(32,195		)	—			—			—			(45,685		)
Change in notes payable with affiliate	—			38,200			—			—			(38,200		)	—
Excess tax benefit from unit-based compensation	—			160			—			—			—			160
Net cash provided by (used in) financing activities	(55,074		)	6,165			—			—			(38,200		)	(87,109		)
Net increase (decrease) in cash and cash equivalents	(3,543		)	29,780			—			—			—			26,237
Cash and cash equivalents:
Beginning	107			1,136			—			—			—			1,243
Ending	$	(3,436	)	$	30,916		$	—		$	—		$	—		$	27,480

Acquisitions_Divestitures_and_2

Acquisitions, Divestitures and Joint-Venture Funding Acquisitions, Divestitures and Joint-Venture Funding (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Oct. 01, 2014

Sep. 30, 2014

Apr. 03, 2012

Sep. 30, 2014

Sep. 30, 2014

Dec. 17, 2013

Jun. 27, 2014

Dec. 17, 2013

Dec. 17, 2013

Dec. 16, 2013

Dec. 17, 2013

Oct. 02, 2014

Oct. 31, 2014

Permian Basin Divestiture [Member]

XOM I Exchange [Member]

Business Acquisition Anadarko [Member]

Business Acquisition Anadarko [Member]

Business Acquisition, Various [Member]

Business Acquisition Devon [Member] [Member]

Business Acquisition Devon [Member] [Member]

Business Acquisition Pioneer [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

LinnCo [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Business Acquisition, Berry [Member]

Business Acquisition, Berry [Member]

Business Acquisition, Berry [Member]

Granite Wash Divestiture [Member]

STACK acreage divestiture [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Divestiture Contract Price

'

'

'

'

'

'

'

$350,000,000

'

'

'

'

'

'

'

'

'

'

$1,950,000,000

'

Gain (Loss) on Disposition of Assets

'

'

'

'

'

'

'

'

45,000,000

'

'

'

'

'

'

'

'

'

'

'

Future Funding Commitment Of Joint Venture Consideration Transferred

'

'

'

'

'

'

'

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

Future Funding Of Joint Venture Agreement

'

'

'

'

'

'

'

'

'

400,000,000

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred

'

'

'

'

'

'

'

'

'

'

'

9,000,000

2,240,000,000

'

328,000,000

'

'

'

'

'

Assets held for sale

1,865,040,000

'

'

'

1,865,040,000

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities held for sale

110,241,000

'

'

'

110,241,000

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Business acquisition interim financing

'

'

'

'

'

'

'

'

'

'

'

'

'

2,300,000,000

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Exchange Ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

168.00%

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

93,756,674

'

93,756,674

'

'

Business Acqusition, Preliminary Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,600,000,000

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

451,000,000

'

'

'

Impairment of Long-Lived Assets to be Disposed of

'

-4,000,000

15,000,000

57,000,000

'

38,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment of long-lived assets

603,250,000

-4,240,000

'

'

603,250,000

37,962,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Sale of Property Held-for-sale

'

218,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

44,000,000

Costs Associated With Sale of Oil and Gas Property and Equipment

'

$2,000,000

'

'

'

'

'

'

$3,000,000

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_Divestitures_and_3

Acquisitions, Divestitures and Joint-Venture Funding Acquisition Purchase Price Allocation (Details) (Business Acquisition, Various [Member], USD $)	Sep. 30, 2014
In Thousands, unless otherwise specified
Business Acquisition, Various [Member]	'
Assets:	'
Current	$22,604
Oil and natural gas properties	2,637,856
Other property and equipment	83,151
Total assets acquired	2,743,611
Liabilities:	'
Current	16,074
Asset retirement obligations	144,645
Total liabilities assumed	160,719
Net assets acquired	$2,582,892

Acquisitions_Divestitures_and_4

Acquisitions, Divestitures and Joint-Venture Funding Pro Forma Financial Information (Details) (USD $)	3 Months Ended		9 Months Ended				9 Months Ended	0 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2013	Jun. 27, 2014	Sep. 30, 2013	Dec. 17, 2013
					Business Acquisition Devon [Member] [Member]	Business Acquisition Devon [Member] [Member]	Business Acquisition, Berry [Member]	Linn Energy, LLC [Member]
								Business Acquisition, Berry [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]	'	'	'	'	'	'	'	'
Business acquisition interim financing	'	'	'	'	'	$2,300,000,000	'	'
Property, Plant and Equipment, Useful Life	'	'	'	'	'10 years	'	'20 years	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	'	'	'	'	'	'	'	93,756,674
Business Acquisition, Pro Forma Information [Abstract]	'	'	'	'	'	'	'	'
Total revenues and other	1,509,498,000	902,733,000	3,117,792,000	2,978,108,000	'	'	'	'
Total operating expenses	1,331,861,000	717,032,000	2,852,327,000	2,150,170,000	'	'	'	'
Net income	$3,000	$25,262,000	($257,158,000)	$334,272,000	'	'	'	'
Net income per unit:	'	'	'	'	'	'	'	'
Basic	$0	$0.08	($0.80)	$1.01	'	'	'	'
Diluted	$0	$0.08	($0.80)	$1.01	'	'	'	'

Unitholders_Capital_Details

Unitholders' Capital (Details) (USD $)	3 Months Ended		9 Months Ended		1 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Oct. 31, 2014	Oct. 31, 2014
					Dividend Declared [Member]	Dividend Paid [Member]
					Subsequent Event [Member]	Subsequent Event [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'
Per unit cash dividend declared (in usd per unit)	$0.73	$0.73	$2.17	$2.17	$0.73	'
Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit	'	'	'	'	$0.24	'
Distributions to unitholders	'	'	$721,235	$511,686	'	$80,000

Oil_and_Natural_Gas_Properties2

Oil and Natural Gas Properties (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'	'	'	'	'
Impairment of long-lived assets	$603,250	($4,240)	$603,250	$37,962	'
Proved properties:	'	'	'	'	'
Leasehold acquisition	13,045,461	'	13,045,461	'	12,277,089
Development	3,047,527	'	3,047,527	'	3,660,277
Unproved properties	2,043,497	'	2,043,497	'	1,951,193
Oil and natural gas properties (successful efforts method)	18,136,485	'	18,136,485	'	17,888,559
Less accumulated depletion and amortization	-3,099,637	'	-3,099,637	'	-3,546,284
Oil and natural gas properties, successful efforts method, net	$15,036,848	'	$15,036,848	'	$14,342,275

UnitBased_Compensation_Narrati

Unit-Based Compensation (Narrative) (Details) (USD $)	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014
Restricted Stock Units (RSUs) [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units granted to employees	1,457,677
Phantom Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units granted to employees	214,875
Share Based Compensation Arrangement Award [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Aggregate fair value of grants issued to employees	56
Vesting period of grants issued to employees	'3 years
Performance Shares [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units granted to employees	212,524
Aggregate fair value of grants issued to employees	5
Share-based Compensation Award, Tranche One [Member] | Performance Shares [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	50.00%
Vesting period of grants issued to employees	'2 years
Share-based Compensation Award, Tranche Two [Member] | Performance Shares [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	50.00%
Vesting period of grants issued to employees	'3 years

UnitBased_Compensation_Compens

Unit-Based Compensation (Compensation Expenses) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	$11,109	$9,686	$43,692	$29,261
Income tax benefit	4,105	3,579	16,144	10,812
General and administrative expenses	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	9,445	8,407	37,164	25,408
Lease operating expenses	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	$1,664	$1,279	$6,528	$3,853

Debt_Details

Debt (Details) (USD $)

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

3 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Mar. 31, 2012

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Sep. 30, 2014

Dec. 16, 2013

Sep. 30, 2014

Dec. 16, 2013

Sep. 30, 2014

Sep. 09, 2014

Aug. 29, 2014

Apr. 30, 2012

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 09, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Aug. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Aug. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 09, 2014

Sep. 30, 2014

Sep. 09, 2014

Sep. 30, 2014

Mar. 31, 2012

Sep. 30, 2014

Sep. 30, 2014

Credit Facility

Credit Facility

Subordinated Debt [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entity, Primary Beneficiary [Member]

2014 [Member]

2014 [Member]

2014 [Member]

2014 [Member]

2014 [Member]

After May 15, 2015 [Member]

Prior to September 15, 2017 [Member]

Prior to September 15, 2017 [Member]

After September 15, 2017 [Member]

Senior Notes Due November 2019

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Senior Notes Due 2014 [Member]

Senior Notes Due 2014 [Member]

Senior Notes Due 2014 [Member]

Senior Notes Due 2020

Senior Notes Due 2020

Senior Notes Due 2022 [Member]

Senior Notes Due 2022 [Member]

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Senior Notes Due September 2021 [Member]

Senior Notes Due September 2021 [Member]

Senior Notes Due September 2021 [Member]

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Senior Notes Due May 2019

Senior Notes Due November 2019

Senior Notes Due 2020

Senior Notes Due 2021

London Interbank Offered Rate (LIBOR) [Member]

ABR

ABR

Senior Notes [Member]

Senior Notes [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Minimum

Maximum

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

ABR

ABR

Minimum

Maximum

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

ABR

ABR

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

ABR

ABR

Senior Notes Due September 2021 and May 2019 [Member]

Senior Notes Due May 2019

Senior Notes Due September 2021 and May 2019 [Member]

Senior Notes Due May 2019

Senior Notes Due May 2019

Senior Notes Due May 2019

Senior Notes Due September 2021 [Member]

Senior Notes Due September 2021 [Member]

Senior Notes Due September 2021 [Member]

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

Maximum

Maximum

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent Reduction of Borrowing Base Under Credit Facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of Borrowing Base Under Line of Credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$25,000,000

$250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate at Period End (in hundredths)

'

'

2.66%

2.67%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.15%

1.92%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.15%

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, redetermined borrowing base

'

'

'

'

'

1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

4,225,000,000

4,225,000,000

4,250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of Maximum Borrowing Capacity Under Line of Credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,000,000

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

3,725,000,000

'

'

4,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term loans

1,800,000,000

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

[1]

500,000,000

[1]

'

'

'

'

'

'

'

'

'

'

1,300,000,000

[2]

0

[2]

'

'

'

'

'

'

'

'

'

'

'

'

Equity in Subsidiaries Pledged to Secure Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of Credit Outstanding, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

The percentage of properties that the company is required to maintain mortgages on (in hundredths)

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80.00%

'

80.00%

'

'

'

'

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Line Of Credit Facility Collateral Coverage Ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

1.50%

2.50%

0.50%

1.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

2.50%

0.50%

1.50%

'

'

'

'

'

0.00%

'

5.00%

2.50%

4.00%

1.50%

'

'

'

'

'

'

3.00%

2.00%

'

'

'

'

'

'

'

'

'

'

Initial Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Increase in Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

Debt Instrument, Additional Increase in Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

Cash proceeds required to be used to repay loans

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Bridge Loan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

599,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

650,000,000

650,000,000

'

'

'

'

'

'

'

'

'

'

1,800,000,000

1,300,000,000

1,000,000,000

'

'

'

'

'

1,100,000,000

[3]

450,000,000

'

450,000,000

'

'

'

'

'

Additional interest paid due to late registration

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, interest rate, stated percentage (in hundredths)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.25%

6.75%

'

6.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

6.50%

6.50%

'

'

'

'

'

'

'

'

'

6.50%

6.25%

8.63%

7.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Fair Value

12,304,893,000

9,395,577,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

310,000,000

'

607,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum Percentage Of November 2019 Senior Notes Redeemable On Before 2017

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

'

'

Debt Instrument, redemption price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

103.25%

'

106.50%

103.25%

Redemption Price of Senior Notes for Change of Control

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issue Price Of Debt Instruments As Percentage Of Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98.62%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

102.00%

'

'

'

'

Proceeds from Debt, Net of Issuance Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

628,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

450,000,000

'

'

'

'

'

Debt Instrument, Unamortized Discount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number Of Days For Effective Registration Statement

'

'

'

'

'400 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

'

321,000,000

'

'

30,000,000

'

837,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

Debt Instrument Financing Fees And Expense Incurred Related To Issuing Long Term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,000,000

'

9,000,000

'

'

'

'

Repayments of Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

$205,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Variable interest rates of 2.66% and 2.67% at September 30, 2014, and December 31, 2013, respectively.

[2]

Variable interest rate of 3.15% at September 30, 2014. Incurred on August 29, 2014.

[3]

$450 million of senior notes due May 2019 and $650 million of senior notes due September 2021 were issued on September 9, 2014.

Debt_Schedule_of_Long_Term_Deb

Debt Schedule of Long Term Debt (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'		'
Credit facilities	$3,683,175		$2,733,175
Term loans	1,800,000		500,000
Senior Notes	6,826,971		5,937,041
Total debt, net	12,310,146		9,170,216
Less current maturities	1,300,000		211,558
Total long-term debt, net	11,010,146		8,958,658
Senior Notes [Member]	'		'
Debt Instrument [Line Items]	'		'
Net unamortized discounts and premiums	-22,162		-18,216
Linn Energy, LLC [Member] | Line of Credit	'		'
Debt Instrument [Line Items]	'		'
Credit facilities	2,510,000	[1]	1,560,000	[1]
Linn Energy, LLC [Member] | Loans Payable [Member]	'		'
Debt Instrument [Line Items]	'		'
Term loans	500,000	[2]	500,000	[2]
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due May 2019	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	1,200,000	[3]	750,000	[3]
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	1,800,000		1,800,000
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due 2020	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	1,300,000		1,300,000
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due September 2021 [Member]	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	650,000	[3]	0	[3]
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due February 2021 [Member]	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	1,000,000		1,000,000
Variable Interest Entity, Primary Beneficiary [Member] | Loans Payable [Member]	'		'
Debt Instrument [Line Items]	'		'
Term loans	1,300,000	[4]	0	[4]
Berry [Member] | Line of Credit	'		'
Debt Instrument [Line Items]	'		'
Credit facilities	1,173,175	[2]	1,173,175	[2]
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2014 [Member]	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	0		205,257
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2020	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	299,970		300,000
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2022 [Member]	'		'
Debt Instrument [Line Items]	'		'
Senior Notes	$599,163		$600,000
[1]	Variable interest rates of 2.15% and 1.92% at September 30, 2014, and December 31, 2013, respectively.
[2]	Variable interest rates of 2.66% and 2.67% at September 30, 2014, and December 31, 2013, respectively.
[3]	$450 million of senior notes due May 2019 and $650 million of senior notes due September 2021 were issued on September 9, 2014.
[4]	Variable interest rate of 3.15% at September 30, 2014. Incurred on August 29, 2014.

Debt_Debt_Fair_Value_Disclosur

Debt Debt Fair Value Disclosure (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Credit facilities	$3,683,175	$2,733,175
Credit Facilities, Fair Value Disclosure	3,683,175	2,733,175
Term loans	1,800,000	500,000
Term Loans, Fair Value Disclosure	1,800,000	500,000
Senior Notes, net	6,826,971	5,937,041
Senior Notes, Fair Value	6,821,718	6,162,402
Total debt, net	12,310,146	9,170,216
Total Debt, Fair Value	$12,304,893	$9,395,577

Derivatives_Commodity_Derivati

Derivatives (Commodity Derivatives) (Details)	Sep. 30, 2014
	MMMBTU
2014 | Natural Gas Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	24,550
Average Price (in usd per energy unit)	5.25
2014 | Natural Gas Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	20,071	[1]
Average Price (in usd per energy unit)	5	[1]
2014 | Oil Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,242	[2]
Average Price (in usd per energy unit)	92.44	[2]
2014 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	184	[2]
Derivative, Floor Price	90	[2]
Derivative, Cap Price	102.87	[2]
2014 | Oil Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	998	[2]
Average Price (in usd per energy unit)	91.3	[2]
2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	782	[2]
2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	92	[2]
2014 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	20,010	[3]
Hedged Differential (in usd per energy unit)	-0.33	[3]
2014 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	10,398	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2014 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	2,392	[3]
Hedged Differential (in usd per energy unit)	0.08	[3]
2014 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	1,325	[3]
Hedged Differential (in usd per energy unit)	-0.1	[3]
2014 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	1,233	[3]
Hedged Differential (in usd per energy unit)	-0.21	[3]
2014 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	920
Hedged Differential (in usd per energy unit)	11.6
2014 | Oil Timing Differential Positions | Trade month roll swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	2,289	[3]
Hedged Differential (in usd per energy unit)	0.24	[3]
2015 | Natural Gas Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	118,041
Average Price (in usd per energy unit)	5.19
2015 | Natural Gas Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	71,854	[1]
Average Price (in usd per energy unit)	5	[1]
2015 | Oil Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	11,599	[2]
Average Price (in usd per energy unit)	96.23	[2]
2015 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
2015 | Oil Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	3,426	[2]
Average Price (in usd per energy unit)	90	[2]
2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	1,095	[2]
2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2015 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	87,162	[3]
Hedged Differential (in usd per energy unit)	-0.33	[3]
2015 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	43,292	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2015 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	9,344	[3]
Hedged Differential (in usd per energy unit)	0.06	[3]
2015 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,891	[3]
Hedged Differential (in usd per energy unit)	-0.1	[3]
2015 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	5,074	[3]
Hedged Differential (in usd per energy unit)	-0.21	[3]
2015 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	2,920
Hedged Differential (in usd per energy unit)	11.6
2015 | Oil Timing Differential Positions | Trade month roll swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	7,251	[3]
Hedged Differential (in usd per energy unit)	0.24	[3]
2016 | Natural Gas Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	121,841
Average Price (in usd per energy unit)	4.2
2016 | Natural Gas Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	76,269	[1]
Average Price (in usd per energy unit)	5	[1]
2016 | Oil Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	11,465	[2]
Average Price (in usd per energy unit)	90.56	[2]
2016 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
2016 | Oil Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	3,271	[2]
Average Price (in usd per energy unit)	90	[2]
2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2016 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	59,954	[3]
Hedged Differential (in usd per energy unit)	-0.32	[3]
2016 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	46,294	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2016 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	7,768	[3]
Hedged Differential (in usd per energy unit)	0.05	[3]
2016 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,575	[3]
Hedged Differential (in usd per energy unit)	-0.1	[3]
2016 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,219	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2016 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0
Hedged Differential (in usd per energy unit)	0
2016 | Oil Timing Differential Positions | Trade month roll swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	7,446	[3]
Hedged Differential (in usd per energy unit)	0.25	[3]
2017 | Natural Gas Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	120,122
Average Price (in usd per energy unit)	4.26
2017 | Natural Gas Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	66,886	[1]
Average Price (in usd per energy unit)	4.88	[1]
2017 | Oil Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,755	[2]
Average Price (in usd per energy unit)	89.02	[2]
2017 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
2017 | Oil Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	384	[2]
Average Price (in usd per energy unit)	90	[2]
2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2017 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'
Derivative [Line Items]	'
Average Price (in usd per energy unit)	100
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384
2017 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	59,138	[3]
Hedged Differential (in usd per energy unit)	-0.33	[3]
2017 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	38,880	[3]
Hedged Differential (in usd per energy unit)	-0.19	[3]
2017 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	7,437	[3]
Hedged Differential (in usd per energy unit)	0.05	[3]
2017 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	3,604	[3]
Hedged Differential (in usd per energy unit)	-0.08	[3]
2017 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	4,819	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2017 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0
Hedged Differential (in usd per energy unit)	0
2017 | Oil Timing Differential Positions | Trade month roll swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	6,486	[3]
Hedged Differential (in usd per energy unit)	0.25	[3]
2018 | Natural Gas Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	36,500
Average Price (in usd per energy unit)	5
2018 | Natural Gas Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[1]
Average Price (in usd per energy unit)	0	[1]
2018 | Oil Derivative Instruments | Fixed price swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Average Price (in usd per energy unit)	0	[2]
2018 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
2018 | Oil Derivative Instruments | Puts	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
Average Price (in usd per energy unit)	0	[2]
2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[2]
2018 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'
Derivative [Line Items]	'
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384
2018 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	16,425	[3]
Hedged Differential (in usd per energy unit)	-0.33	[3]
2018 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	10,804	[3]
Hedged Differential (in usd per energy unit)	-0.19	[3]
2018 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	2,044	[3]
Hedged Differential (in usd per energy unit)	0.05	[3]
2018 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	986	[3]
Hedged Differential (in usd per energy unit)	-0.08	[3]
2018 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	1,314	[3]
Hedged Differential (in usd per energy unit)	-0.2	[3]
2018 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0
Hedged Differential (in usd per energy unit)	0
2018 | Oil Timing Differential Positions | Trade month roll swaps	'
Derivative [Line Items]	'
Hedged Volume (in energy unit)	0	[3]
Hedged Differential (in usd per energy unit)	0	[3]
2019 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'
Derivative [Line Items]	'
Average Price (in usd per energy unit)	90
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384
Short [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	72.11	[2]
Derivative, Cap Price	109.79	[2]
Short [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	80	[2]
Derivative, Cap Price	114.05	[2]
Short [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	70	[2]
Derivative, Cap Price	101.62	[2]
Short [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Short [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Derivative, Cap Price	0	[2]
Long [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	93.76	[2]
Long [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	100	[2]
Long [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	90	[2]
Long [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
Long [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	0	[2]
[1]	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
[2]	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
[3]	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).

Derivatives_Balance_Sheet_Pres

Derivatives (Balance Sheet Presentation) (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$783,000,000	'
Assets:	'	'
Commodity derivatives	783,056,000	1,048,212,000
Liabilities:	'	'
Commodity derivatives	$143,215,000	$222,905,000

Derivatives_Gains_Losses_On_De

Derivatives (Gains (Losses) On Derivatives) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
	MBbls	MBbls	MBbls	MMMBTU
	MMMBTU	MMMBTU	MMMBTU	MBbls
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'	'
Volume Of Natural Gas Production On Settled Derivatives	44,621	43,729	132,408	129,760
Gains (losses) on oil and natural gas derivatives	$451,702	($63,931)	($198,579)	$154,432
Cash settlements	$10,000	$45,000	($12,507)	$190,368
Average Contract Price On Natural Gas Settled Derivatives Per Unit	5.14	5.29	'	'
Volume Of Oil On Settled Derivatives	6,299	3,775	18,690	11,201
Average Contract Price On Oil Settled Derivatives Per Unit	92.39	95.57	'	'

Fair_Value_Measurements_on_a_R2

Fair Value Measurements on a Recurring Basis (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Assets:	'		'
Commodity derivatives	$783,056		$1,048,212
Commodity derivatives	-140,538	[1]	-190,080	[1]
Commodity derivatives	642,518		858,132
Liabilities:	'		'
Commodity derivatives	143,215		222,905
Commodity derivatives	-140,538	[1]	-190,080	[1]
Commodity derivatives	$2,677		$32,825
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Future inflation factor used in the calculation of the asset retirement obligations	2.00%
Credit adjusted risk-free interest rate for the calculation of the asset retirement obligations	5.30%
Asset retirement obligations rollforward	'
Asset retirement obligations at December 31, 2013	$289,321
Liabilities added from acquisitions	146,775
Liabilities added from drilling	8,300
Liabilities reclassified as held for sale	-15,551
Liabilities associated with assets divested	-2,129
Current year accretion expense	15,203
Settlements	-10,753
Revision of estimates	9,130
Asset retirement obligations at September 30, 2014	$440,296

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	1 Months Ended			9 Months Ended		29 Months Ended
	Apr. 30, 2014	Apr. 30, 2013	Mar. 31, 2011	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014
Loss Contingency, Estimate [Abstract]	'	'	'	'	'	'
Litigation Settlement, Amount	'	'	'	$2,400,000	'	'
Payments for Legal Settlements	'	'	'	0	0	'
General Unsecured Claims Amount From Termination Agreement	'	'	51,000,000	'	'	'
Distribution Under Termination Agreement	3,000,000	5,000,000	'	'	'	42,000,000
Pending Litigation [Member]	'	'	'	'	'	'
Loss Contingency, Estimate [Abstract]	'	'	'	'	'	'
Loss Contingency, Range of Possible Loss, Minimum	'	'	'	1,000,000	'	1,000,000
Loss Contingency, Range of Possible Loss, Maximum	'	'	'	$4,500,000	'	$4,500,000

Earnings_Per_Unit_Details

Earnings Per Unit (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net income (loss)	($4,100)	($30,060)	($297,307)	$93,212
Allocated to participating securities	-2,097	-1,266	-6,289	-3,796
Net income (loss) available to common unitholders, basic	($6,197)	($31,326)	($303,596)	$89,416
Earnings per share reconciliation	'	'	'	'
Basic loss per unit (in usd per unit)	($0.02)	($0.13)	($0.92)	$0.38
Diluted loss per unit (in usd per unit)	($0.02)	($0.13)	($0.92)	$0.38
Weighted average units outstanding	'	'	'	'
Basic weighted average units outstanding	329,168,000	233,552,000	328,783,000	233,393,000
Dilutive effect of unit equivalents	0	0	0	372,000
Diluted weighted average units outstanding	329,168,000	233,552,000	328,783,000	233,765,000
Unit options and warrants	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'	'
Weighted average anti-dilutive unit equivalents excluded from computation of earnings per unit (in units)	6,000,000	4,000,000	6,000,000	3,000,000

Supplemental_Disclosures_to_th2

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Balance Sheets) (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'	'
Restricted cash	$6,000,000	$6,000,000
Net Outstanding Checks	85,000,000	48,000,000
Accrued Liabilities and Other Liabilities [Abstract]	'	'
Accrued compensation	43,952,000	55,257,000
Accrued interest	150,676,000	93,998,000
Asset retirement obligations	12,616,000	6,270,000
Liabilities held for sale	110,241,000	0
Other	9,964,000	7,850,000
Other accrued liabilities	$327,449,000	$163,375,000

Supplemental_Disclosures_to_th3

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Cash Flows) (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Supplemental Cash Flow Information [Abstract]	'	'
Cash payments for interest, net of amounts capitalized	$345,687,000	$240,261,000
Cash payments for income taxes	0	14,000
In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:	'	'
Fair value of assets acquired	2,743,611,000	47,901,000
Cash paid	-2,577,180,000	-28,524,000
Gain (Loss) on Disposition of Oil and Gas Property	48,333,000	0
Receivables from sellers	42,621,000	3,654,000
Payables to sellers	0	-6,854,000
Liabilities assumed	160,719,000	16,177,000
Joint-venture funding	25,000,000	112,000,000
Net Outstanding Checks	$85,000,000	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses	$75,384,000	$45,431,000	$221,518,000	$150,302,000
Distributions to unitholders	'	'	721,235,000	511,686,000
LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Ownership percentage	39.00%	'	39.00%	'
General and administrative expenses	644,000	'	2,100,000	'
General and Administrative Expenses and Offering Costs	'	1,000,000	'	15,000,000
Related Party Transaction, Expenses from Transactions with Related Party	470,000	403,000	1,400,000	1,000,000
Director [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Related party transaction, amounts of transaction	5,000,000	7,000,000	17,000,000	20,000,000
FY 2014 [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses paid on behalf of LinnCo	'	'	1,900,000	9,000,000
FY 2013 [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses paid on behalf of LinnCo	'	'	11,000,000	'
Business Acquisition, Berry [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and Administrative Expenses and Offering Costs	'	125,000	'	13,000,000
Dividend Paid [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Distributions to unitholders	$94,000,000	$25,000,000	$280,000,000	$76,000,000

Subsidiary_Guarantors_Condense

Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'	'	'
Cash and cash equivalents	$59,161	$52,171	$27,480	$1,243
Accounts receivable – trade, net	522,633	488,202	'	'
Accounts receivable – affiliates	0	0	'	'
Derivative instruments	337,244	176,130	'	'
Assets held for sale	1,865,040	0	'	'
Other current assets	165,512	99,437	'	'
Total current assets	2,949,590	815,940	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	18,136,485	17,888,559	'	'
Less accumulated depletion and amortization	-3,099,637	-3,546,284	'	'
Oil and natural gas properties, successful efforts method, net	15,036,848	14,342,275	'	'
Other property and equipment	635,410	647,882	'	'
Less accumulated depreciation	-148,815	-110,939	'	'
Other property and equipment, net	486,595	536,943	'	'
Derivative instruments	305,274	682,002	'	'
Notes receivable – affiliates	0	0	'	'
Advance to related party	0	'	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	148,687	127,804	'	'
Noncurrent assets, excluding property, total	453,961	809,806	'	'
Total noncurrent assets	15,977,404	15,689,024	'	'
Total assets	18,926,994	16,504,964	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	826,976	849,624	'	'
Accounts payable – affiliates	0	0	'	'
Advance from related party	0	'	'	'
Derivative instruments	2,597	28,176	'	'
Other accrued liabilities	327,449	163,375	'	'
Current portion of long-term debt	1,300,000	211,558	'	'
Total current liabilities	2,457,022	1,252,733	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	3,683,175	2,733,175	'	'
Term loan	500,000	500,000	'	'
Senior notes, net	6,826,971	5,725,483	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	80	4,649	'	'
Other noncurrent liabilities	527,613	397,497	'	'
Total noncurrent liabilities	11,537,839	9,360,804	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	5,629,837	6,291,824	'	'
Accumulated deficit	-697,704	-400,397	'	'
Total unitholders' capital	4,932,133	5,891,427	'	'
Total liabilities and unitholders’ capital	18,926,994	16,504,964	'	'
Reportable Legal Entities [Member] | Parent Company [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	48	52	-3,436	107
Accounts receivable – trade, net	0	0	'	'
Accounts receivable – affiliates	3,805,769	4,212,348	'	'
Derivative instruments	0	0	'	'
Assets held for sale	0	'	'	'
Other current assets	18	330	'	'
Total current assets	3,805,835	4,212,730	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	0	0	'	'
Less accumulated depletion and amortization	0	0	'	'
Oil and natural gas properties, successful efforts method, net	0	0	'	'
Other property and equipment	0	0	'	'
Less accumulated depreciation	0	0	'	'
Other property and equipment, net	0	0	'	'
Derivative instruments	0	0	'	'
Notes receivable – affiliates	121,500	86,200	'	'
Advance to related party	1,285,000	'	'	'
Investments in consolidated subsidiaries	8,654,255	8,433,290	'	'
Other noncurrent assets	122,046	108,785	'	'
Noncurrent assets, excluding property, total	10,182,801	8,628,275	'	'
Total noncurrent assets	10,182,801	8,628,275	'	'
Total assets	13,988,636	12,841,005	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	3,656	14,529	'	'
Accounts payable – affiliates	0	0	'	'
Advance from related party	0	'	'	'
Derivative instruments	0	0	'	'
Other accrued liabilities	138,877	75,071	'	'
Current portion of long-term debt	0	0	'	'
Total current liabilities	142,533	89,600	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	2,510,000	1,560,000	'	'
Term loan	500,000	500,000	'	'
Senior notes, net	5,912,739	4,809,055	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	0	0	'	'
Other noncurrent liabilities	0	0	'	'
Total noncurrent liabilities	8,922,739	6,869,055	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	5,621,068	6,282,747	'	'
Accumulated deficit	-697,704	-400,397	'	'
Total unitholders' capital	4,923,364	5,882,350	'	'
Total liabilities and unitholders’ capital	13,988,636	12,841,005	'	'
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	11,858	1,078	30,916	1,136
Accounts receivable – trade, net	343,207	365,347	'	'
Accounts receivable – affiliates	16,451	16,950	'	'
Derivative instruments	313,954	170,534	'	'
Assets held for sale	1,485,270	'	'	'
Other current assets	75,817	68,274	'	'
Total current assets	2,246,557	622,183	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	10,738,434	13,074,900	'	'
Less accumulated depletion and amortization	-2,880,850	-3,535,890	'	'
Oil and natural gas properties, successful efforts method, net	7,857,584	9,539,010	'	'
Other property and equipment	508,485	564,756	'	'
Less accumulated depreciation	-142,511	-110,706	'	'
Other property and equipment, net	365,974	454,050	'	'
Derivative instruments	302,959	679,491	'	'
Notes receivable – affiliates	0	0	'	'
Advance to related party	1,285,000	'	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	11,416	10,968	'	'
Noncurrent assets, excluding property, total	1,599,375	690,459	'	'
Total noncurrent assets	9,822,933	10,683,519	'	'
Total assets	12,069,490	11,305,702	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	545,494	587,774	'	'
Accounts payable – affiliates	3,805,769	4,212,348	'	'
Advance from related party	1,285,000	'	'	'
Derivative instruments	1,686	7,783	'	'
Other accrued liabilities	171,314	59,311	'	'
Current portion of long-term debt	0	0	'	'
Total current liabilities	5,809,263	4,867,216	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	0	0	'	'
Term loan	0	0	'	'
Senior notes, net	0	0	'	'
Notes payable – affiliates	121,500	86,200	'	'
Derivative instruments	80	0	'	'
Other noncurrent liabilities	207,082	205,406	'	'
Total noncurrent liabilities	328,662	291,606	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	4,833,046	4,833,354	'	'
Accumulated deficit	1,098,519	1,313,526	'	'
Total unitholders' capital	5,931,565	6,146,880	'	'
Total liabilities and unitholders’ capital	12,069,490	11,305,702	'	'
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	6,576	51,041	0	0
Accounts receivable – trade, net	133,775	122,855	'	'
Accounts receivable – affiliates	0	0	'	'
Derivative instruments	23,290	5,596	'	'
Assets held for sale	379,770	'	'	'
Other current assets	45,110	30,833	'	'
Total current assets	588,521	210,325	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	4,807,794	4,813,659	'	'
Less accumulated depletion and amortization	-208,367	-10,394	'	'
Oil and natural gas properties, successful efforts method, net	4,599,427	4,803,265	'	'
Other property and equipment	102,496	83,126	'	'
Less accumulated depreciation	-6,024	-233	'	'
Other property and equipment, net	96,472	82,893	'	'
Derivative instruments	2,315	2,511	'	'
Notes receivable – affiliates	0	0	'	'
Advance to related party	0	'	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	15,225	8,051	'	'
Noncurrent assets, excluding property, total	17,540	10,562	'	'
Total noncurrent assets	4,713,439	4,896,720	'	'
Total assets	5,301,960	5,107,045	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	248,181	247,321	'	'
Accounts payable – affiliates	11,228	16,950	'	'
Advance from related party	0	'	'	'
Derivative instruments	911	20,393	'	'
Other accrued liabilities	17,031	28,993	'	'
Current portion of long-term debt	0	211,558	'	'
Total current liabilities	277,351	525,215	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	1,173,175	1,173,175	'	'
Term loan	0	0	'	'
Senior notes, net	914,232	916,428	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	0	4,649	'	'
Other noncurrent liabilities	200,123	192,091	'	'
Total noncurrent liabilities	2,287,530	2,286,343	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	2,483,181	2,315,460	'	'
Accumulated deficit	253,898	-19,973	'	'
Total unitholders' capital	2,737,079	2,295,487	'	'
Total liabilities and unitholders’ capital	5,301,960	5,107,045	'	'
Reportable Legal Entities [Member] | Variable Interest Entity, Primary Beneficiary [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	40,679	0	0	0
Accounts receivable – trade, net	45,651	0	'	'
Accounts receivable – affiliates	0	0	'	'
Derivative instruments	0	0	'	'
Assets held for sale	0	'	'	'
Other current assets	44,567	0	'	'
Total current assets	130,897	0	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	2,590,257	0	'	'
Less accumulated depletion and amortization	-10,420	0	'	'
Oil and natural gas properties, successful efforts method, net	2,579,837	0	'	'
Other property and equipment	24,429	0	'	'
Less accumulated depreciation	-280	0	'	'
Other property and equipment, net	24,149	0	'	'
Derivative instruments	0	0	'	'
Notes receivable – affiliates	0	0	'	'
Advance to related party	0	'	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	0	0	'	'
Noncurrent assets, excluding property, total	0	0	'	'
Total noncurrent assets	2,603,986	0	'	'
Total assets	2,734,883	0	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	29,645	0	'	'
Accounts payable – affiliates	5,223	0	'	'
Advance from related party	1,285,000	'	'	'
Derivative instruments	0	0	'	'
Other accrued liabilities	227	0	'	'
Current portion of long-term debt	1,300,000	0	'	'
Total current liabilities	2,620,095	0	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	0	0	'	'
Term loan	0	0	'	'
Senior notes, net	0	0	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	0	0	'	'
Other noncurrent liabilities	120,408	0	'	'
Total noncurrent liabilities	120,408	0	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	0	0	'	'
Accumulated deficit	-5,620	0	'	'
Total unitholders' capital	-5,620	0	'	'
Total liabilities and unitholders’ capital	2,734,883	0	'	'
Consolidation, Eliminations [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	0	0	0	0
Accounts receivable – trade, net	0	0	'	'
Accounts receivable – affiliates	-3,822,220	-4,229,298	'	'
Derivative instruments	0	0	'	'
Assets held for sale	0	'	'	'
Other current assets	0	0	'	'
Total current assets	-3,822,220	-4,229,298	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	0	0	'	'
Less accumulated depletion and amortization	0	0	'	'
Oil and natural gas properties, successful efforts method, net	0	0	'	'
Other property and equipment	0	0	'	'
Less accumulated depreciation	0	0	'	'
Other property and equipment, net	0	0	'	'
Derivative instruments	0	0	'	'
Notes receivable – affiliates	-121,500	-86,200	'	'
Advance to related party	-2,570,000	'	'	'
Investments in consolidated subsidiaries	-8,654,255	-8,433,290	'	'
Other noncurrent assets	0	0	'	'
Noncurrent assets, excluding property, total	-11,345,755	-8,519,490	'	'
Total noncurrent assets	-11,345,755	-8,519,490	'	'
Total assets	-15,167,975	-12,748,788	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	0	0	'	'
Accounts payable – affiliates	-3,822,220	-4,229,298	'	'
Advance from related party	-2,570,000	'	'	'
Derivative instruments	0	0	'	'
Other accrued liabilities	0	0	'	'
Current portion of long-term debt	0	0	'	'
Total current liabilities	-6,392,220	-4,229,298	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	0	0	'	'
Term loan	0	0	'	'
Senior notes, net	0	0	'	'
Notes payable – affiliates	-121,500	-86,200	'	'
Derivative instruments	0	0	'	'
Other noncurrent liabilities	0	0	'	'
Total noncurrent liabilities	-121,500	-86,200	'	'
Unitholders’ capital:	'	'	'	'
331,820,379 units and 329,661,161 units issued and outstanding at September 30, 2014, and December 31, 2013, respectively	-7,307,458	-7,139,737	'	'
Accumulated deficit	-1,346,797	-1,293,553	'	'
Total unitholders' capital	-8,654,255	-8,433,290	'	'
Total liabilities and unitholders’ capital	($15,167,975)	($12,748,788)	'	'

Subsidiary_Guarantors_Condense1

Subsidiary Guarantors Condensed Consolidating Statements of Operations (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$937,458	$537,671	$2,844,185	$1,488,610
Gains (losses) on oil and natural gas derivatives	451,702	-63,931	-198,579	154,432
Marketing revenues	39,836	13,484	100,655	40,558
Other revenues	6,119	7,338	19,392	18,847
Total revenues	1,435,115	494,562	2,765,653	1,702,447
Expenses:	'	'	'	'
Lease operating expenses	191,630	87,076	570,564	259,381
Transportation expenses	53,412	35,637	143,896	92,118
Marketing expenses	31,574	9,962	75,920	26,696
General and administrative expenses	75,384	45,431	221,518	150,302
Exploration costs	7,850	1,588	10,492	4,632
Depreciation, depletion and amortization	290,287	208,892	832,523	604,962
Impairment of long-lived assets	603,250	-4,240	603,250	37,962
Taxes, other than income taxes	66,770	36,457	201,014	108,525
(Gains) losses on sale of assets and other, net	-35,803	827	-27,750	3,040
Total expenses	1,284,354	421,630	2,631,427	1,287,618
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-154,047	-103,806	-422,160	-308,012
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	0	-1,117	0	-5,304
Equity in earnings from consolidated subsidiaries	0	0	0	0
Other, net	-1,847	-2,475	-6,699	-6,300
Total other income and (expenses)	-155,894	-107,398	-428,859	-319,616
Income (loss) before income taxes	-5,133	-34,466	-294,633	95,213
Income tax expense (benefit)	-1,033	-4,406	2,674	2,001
Net income (loss)	-4,100	-30,060	-297,307	93,212
Reportable Legal Entities [Member] | Parent Company [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	0	0	0	0
Gains (losses) on oil and natural gas derivatives	0	0	0	0
Marketing revenues	0	0	0	0
Other revenues	0	0	0	0
Total revenues	0	0	0	0
Expenses:	'	'	'	'
Lease operating expenses	0	0	0	0
Transportation expenses	0	0	0	0
Marketing expenses	0	0	0	0
General and administrative expenses	0	0	0	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment of long-lived assets	0	0	0	0
Taxes, other than income taxes	40	0	40	0
(Gains) losses on sale of assets and other, net	0	0	0	724
Total expenses	40	0	40	724
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-129,129	-103,252	-350,382	-307,316
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	2,218	1,588	5,627	4,142
Loss on extinguishment of debt	'	-1,117	'	-5,304
Equity in earnings from consolidated subsidiaries	124,435	75,133	53,244	408,602
Other, net	-1,584	-2,412	-5,756	-6,188
Total other income and (expenses)	-4,060	-30,060	-297,267	93,936
Income (loss) before income taxes	-4,100	-30,060	-297,307	93,212
Income tax expense (benefit)	0	0	0	0
Net income (loss)	-4,100	-30,060	-297,307	93,212
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	542,535	537,671	1,755,766	1,488,610
Gains (losses) on oil and natural gas derivatives	406,712	-63,931	-221,472	154,432
Marketing revenues	26,518	13,484	60,088	40,558
Other revenues	5,874	7,338	19,154	18,847
Total revenues	981,639	494,562	1,613,536	1,702,447
Expenses:	'	'	'	'
Lease operating expenses	97,613	87,076	293,162	259,381
Transportation expenses	36,531	35,637	111,539	92,118
Marketing expenses	23,871	9,962	47,511	26,696
General and administrative expenses	52,580	45,431	126,901	150,302
Exploration costs	7,850	1,588	10,492	4,632
Depreciation, depletion and amortization	199,360	208,892	595,212	604,962
Impairment of long-lived assets	603,250	-4,240	603,250	37,962
Taxes, other than income taxes	38,598	36,457	126,334	108,525
(Gains) losses on sale of assets and other, net	-93,257	827	-92,828	2,316
Total expenses	966,396	421,630	1,821,573	1,286,894
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	757	-554	1,384	-696
Interest expense – affiliates	-2,218	-1,588	-5,627	-4,142
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	'	0	'	0
Equity in earnings from consolidated subsidiaries	0	0	0	0
Other, net	-84	-63	-130	-112
Total other income and (expenses)	-1,545	-2,205	-4,373	-4,950
Income (loss) before income taxes	13,698	70,727	-212,410	410,603
Income tax expense (benefit)	-1,192	-4,406	2,597	2,001
Net income (loss)	14,890	75,133	-215,007	408,602
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	350,863	0	1,044,359	0
Gains (losses) on oil and natural gas derivatives	44,990	0	22,893	0
Marketing revenues	13,318	0	40,567	0
Other revenues	245	0	238	0
Total revenues	409,416	0	1,108,057	0
Expenses:	'	'	'	'
Lease operating expenses	83,684	0	267,069	0
Transportation expenses	13,326	0	28,802	0
Marketing expenses	7,703	0	28,409	0
General and administrative expenses	16,566	0	88,379	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	79,725	0	226,109	0
Impairment of long-lived assets	0	0	0	0
Taxes, other than income taxes	24,830	0	71,338	0
(Gains) losses on sale of assets and other, net	49,011	0	56,635	0
Total expenses	274,845	0	766,741	0
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-19,068	0	-66,555	0
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	'	0	'	0
Equity in earnings from consolidated subsidiaries	0	0	0	0
Other, net	-179	0	-813	0
Total other income and (expenses)	-19,247	0	-67,368	0
Income (loss) before income taxes	115,324	0	273,948	0
Income tax expense (benefit)	159	0	77	0
Net income (loss)	115,165	0	273,871	0
Reportable Legal Entities [Member] | Variable Interest Entity, Primary Beneficiary [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	44,060	0	44,060	0
Gains (losses) on oil and natural gas derivatives	0	0	0	0
Marketing revenues	0	0	0	0
Other revenues	0	0	0	0
Total revenues	44,060	0	44,060	0
Expenses:	'	'	'	'
Lease operating expenses	10,333	0	10,333	0
Transportation expenses	3,555	0	3,555	0
Marketing expenses	0	0	0	0
General and administrative expenses	6,238	0	6,238	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	11,202	0	11,202	0
Impairment of long-lived assets	0	0	0	0
Taxes, other than income taxes	3,302	0	3,302	0
(Gains) losses on sale of assets and other, net	8,443	0	8,443	0
Total expenses	43,073	0	43,073	0
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-6,607	0	-6,607	0
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	'	0	'	0
Equity in earnings from consolidated subsidiaries	0	0	0	0
Other, net	0	0	0	0
Total other income and (expenses)	-6,607	0	-6,607	0
Income (loss) before income taxes	-5,620	0	-5,620	0
Income tax expense (benefit)	0	0	0	0
Net income (loss)	-5,620	0	-5,620	0
Consolidation, Eliminations [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	0	0	0	0
Gains (losses) on oil and natural gas derivatives	0	0	0	0
Marketing revenues	0	0	0	0
Other revenues	0	0	0	0
Total revenues	0	0	0	0
Expenses:	'	'	'	'
Lease operating expenses	0	0	0	0
Transportation expenses	0	0	0	0
Marketing expenses	0	0	0	0
General and administrative expenses	0	0	0	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment of long-lived assets	0	0	0	0
Taxes, other than income taxes	0	0	0	0
(Gains) losses on sale of assets and other, net	0	0	0	0
Total expenses	0	0	0	0
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	0	0	0	0
Interest expense – affiliates	2,218	1,588	5,627	4,142
Interest income – affiliates	-2,218	-1,588	-5,627	-4,142
Loss on extinguishment of debt	'	0	'	0
Equity in earnings from consolidated subsidiaries	-124,435	-75,133	-53,244	-408,602
Other, net	0	0	0	0
Total other income and (expenses)	-124,435	-75,133	-53,244	-408,602
Income (loss) before income taxes	-124,435	-75,133	-53,244	-408,602
Income tax expense (benefit)	0	0	0	0
Net income (loss)	($124,435)	($75,133)	($53,244)	($408,602)

Subsidiary_Guarantors_Condense2

Subsidiary Guarantors Condensed Consolidating Statements of Cash Flow (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Cash flow from operating activities:	'	'
Net loss	($297,307)	$93,212
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	832,523	604,962
Impairment of long-lived assets	603,250	37,962
Unit-based compensation expenses	43,692	29,261
Loss on extinguishment of debt	0	5,304
Amortization and write-off of deferred financing fees	29,236	16,392
(Gains) losses on sale of assets and other, net	-33,135	18,744
Equity in earnings from consolidated subsidiaries	0	0
Deferred income taxes	2,619	731
Derivatives activities:	'	'
Total (gains) losses	198,579	-154,432
Cash settlements	-12,507	190,368
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-56,014	22,877
Decrease in accounts receivable – affiliates	0	0
Decrease in other assets	3,284	9,177
Increase in accounts payable and accrued expenses	112,235	29,445
Decrease in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	9,355	36,508
Net cash provided by operating activities	1,435,810	940,511
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-2,601,932	-192,871
Development of oil and natural gas properties	-1,176,478	-767,604
Purchases of other property and equipment	-50,138	-76,987
Investment in affiliates	0	'
Change in notes receivable with affiliate	0	0
Advance to related party	0	'
Proceeds from sale of properties and equipment and other	-7,485	210,297
Net cash used in investing activities	-3,836,033	-827,165
Cash flow from financing activities:	'	'
Proceeds from borrowings	5,300,024	1,260,000
Repayments of debt	-2,156,124	-789,898
Distributions to unitholders	-721,235	-511,686
Financing fees and other, net	-19,483	-45,685
Change in notes payable with affiliate	0	0
Advance from related party	0	'
Capital contributions – affiliates	0	'
Excess tax benefit from unit-based compensation	4,031	160
Net cash provided by (used in) financing activities	2,407,213	-87,109
Net increase in cash and cash equivalents	6,990	26,237
Cash and cash equivalents:	'	'
Beginning	52,171	1,243
Ending	59,161	27,480
Reportable Legal Entities [Member] | Parent Company [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-297,307	93,212
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	5,304
Amortization and write-off of deferred financing fees	31,564	16,392
(Gains) losses on sale of assets and other, net	0	0
Equity in earnings from consolidated subsidiaries	-53,244	-408,602
Deferred income taxes	0	0
Derivatives activities:	'	'
Total (gains) losses	0	0
Cash settlements	0	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	0	0
Decrease in accounts receivable – affiliates	469,499	341,730
Decrease in other assets	312	-330
Increase in accounts payable and accrued expenses	18	0
Decrease in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	63,806	51,069
Net cash provided by operating activities	214,648	98,775
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	0	0
Development of oil and natural gas properties	0	0
Purchases of other property and equipment	0	0
Investment in affiliates	-167,721	'
Change in notes receivable with affiliate	-35,300	-38,200
Advance to related party	-1,285,000	'
Proceeds from sale of properties and equipment and other	-13,188	-9,044
Net cash used in investing activities	-1,501,209	-47,244
Cash flow from financing activities:	'	'
Proceeds from borrowings	4,000,024	1,260,000
Repayments of debt	-1,950,000	-789,898
Distributions to unitholders	-721,235	-511,686
Financing fees and other, net	-46,263	-13,490
Change in notes payable with affiliate	0	0
Advance from related party	0	'
Capital contributions – affiliates	0	'
Excess tax benefit from unit-based compensation	4,031	0
Net cash provided by (used in) financing activities	1,286,557	-55,074
Net increase in cash and cash equivalents	-4	-3,543
Cash and cash equivalents:	'	'
Beginning	52	107
Ending	48	-3,436
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-215,007	408,602
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	595,212	604,962
Impairment of long-lived assets	603,250	37,962
Unit-based compensation expenses	43,692	29,261
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	0	0
(Gains) losses on sale of assets and other, net	-81,492	18,744
Equity in earnings from consolidated subsidiaries	0	0
Deferred income taxes	2,542	731
Derivatives activities:	'	'
Total (gains) losses	221,472	-154,432
Cash settlements	5,623	190,368
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-1,343	22,877
Decrease in accounts receivable – affiliates	16,950	0
Decrease in other assets	-10,723	9,507
Increase in accounts payable and accrued expenses	107,673	29,445
Decrease in accounts payable and accrued expenses – affiliates	-468,896	-341,730
Increase in other liabilities	-18,053	-14,561
Net cash provided by operating activities	800,900	841,736
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-76,627	-192,871
Development of oil and natural gas properties	-750,450	-767,604
Purchases of other property and equipment	-41,822	-76,987
Investment in affiliates	0	'
Change in notes receivable with affiliate	0	0
Advance to related party	-1,285,000	'
Proceeds from sale of properties and equipment and other	5,447	219,341
Net cash used in investing activities	-2,148,452	-818,121
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and other, net	38,032	-32,195
Change in notes payable with affiliate	35,300	38,200
Advance from related party	1,285,000	'
Capital contributions – affiliates	0	'
Excess tax benefit from unit-based compensation	0	160
Net cash provided by (used in) financing activities	1,358,332	6,165
Net increase in cash and cash equivalents	10,780	29,780
Cash and cash equivalents:	'	'
Beginning	1,078	1,136
Ending	11,858	30,916
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	273,871	0
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	226,109	0
Impairment of long-lived assets	0	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	-5,174	0
(Gains) losses on sale of assets and other, net	48,357	0
Equity in earnings from consolidated subsidiaries	0	0
Deferred income taxes	77	0
Derivatives activities:	'	'
Total (gains) losses	-22,893	0
Cash settlements	-18,130	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-10,611	0
Decrease in accounts receivable – affiliates	0	0
Decrease in other assets	4,551	0
Increase in accounts payable and accrued expenses	-10,619	0
Decrease in accounts payable and accrued expenses – affiliates	-5,722	0
Increase in other liabilities	-36,626	0
Net cash provided by operating activities	443,190	0
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-3,912	0
Development of oil and natural gas properties	-426,028	0
Purchases of other property and equipment	-8,316	0
Investment in affiliates	0	'
Change in notes receivable with affiliate	0	0
Advance to related party	0	'
Proceeds from sale of properties and equipment and other	256	0
Net cash used in investing activities	-438,000	0
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	-206,124	0
Distributions to unitholders	0	0
Financing fees and other, net	-11,252	0
Change in notes payable with affiliate	0	0
Advance from related party	0	'
Capital contributions – affiliates	167,721	'
Excess tax benefit from unit-based compensation	0	0
Net cash provided by (used in) financing activities	-49,655	0
Net increase in cash and cash equivalents	-44,465	0
Cash and cash equivalents:	'	'
Beginning	51,041	0
Ending	6,576	0
Reportable Legal Entities [Member] | Variable Interest Entity, Primary Beneficiary [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-5,620	0
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	11,202	0
Impairment of long-lived assets	0	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	2,846	0
(Gains) losses on sale of assets and other, net	0	0
Equity in earnings from consolidated subsidiaries	0	0
Deferred income taxes	0	0
Derivatives activities:	'	'
Total (gains) losses	0	0
Cash settlements	0	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-44,060	0
Decrease in accounts receivable – affiliates	0	0
Decrease in other assets	9,144	0
Increase in accounts payable and accrued expenses	15,163	0
Decrease in accounts payable and accrued expenses – affiliates	-11,831	0
Increase in other liabilities	228	0
Net cash provided by operating activities	-22,928	0
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-2,521,393	0
Development of oil and natural gas properties	0	0
Purchases of other property and equipment	0	0
Investment in affiliates	0	'
Change in notes receivable with affiliate	0	0
Advance to related party	0	'
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	-2,521,393	0
Cash flow from financing activities:	'	'
Proceeds from borrowings	1,300,000	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and other, net	0	0
Change in notes payable with affiliate	0	0
Advance from related party	1,285,000	'
Capital contributions – affiliates	0	'
Excess tax benefit from unit-based compensation	0	0
Net cash provided by (used in) financing activities	2,585,000	0
Net increase in cash and cash equivalents	40,679	0
Cash and cash equivalents:	'	'
Beginning	0	0
Ending	40,679	0
Consolidation, Eliminations [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-53,244	-408,602
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	0	0
(Gains) losses on sale of assets and other, net	0	0
Equity in earnings from consolidated subsidiaries	53,244	408,602
Deferred income taxes	0	0
Derivatives activities:	'	'
Total (gains) losses	0	0
Cash settlements	0	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	0	0
Decrease in accounts receivable – affiliates	-486,449	-341,730
Decrease in other assets	0	0
Increase in accounts payable and accrued expenses	0	0
Decrease in accounts payable and accrued expenses – affiliates	486,449	341,730
Increase in other liabilities	0	0
Net cash provided by operating activities	0	0
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	0	0
Development of oil and natural gas properties	0	0
Purchases of other property and equipment	0	0
Investment in affiliates	167,721	'
Change in notes receivable with affiliate	35,300	38,200
Advance to related party	2,570,000	'
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	2,773,021	38,200
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and other, net	0	0
Change in notes payable with affiliate	-35,300	-38,200
Advance from related party	-2,570,000	'
Capital contributions – affiliates	-167,721	'
Excess tax benefit from unit-based compensation	0	0
Net cash provided by (used in) financing activities	-2,773,021	-38,200
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents:	'	'
Beginning	0	0
Ending	$0	$0

Subsidiary_Guarantors_Details_

Subsidiary Guarantors Details (Details)	9 Months Ended
	Sep. 30, 2014
Condensed Financial Information [Abstract]	'
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	100.00%