Pressburg (ROAN) 10-Q 29 Apr 15 2015 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2015
Document and Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	31-Mar-15
Amendment Flag	FALSE
Entity Registrant Name	Linn Energy, LLC
Entity Central Index Key	1326428
Current Fiscal Year End Date	-19
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	336,887,489
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$48,312	$1,809
Accounts receivable – trade, net	340,838	471,684
Derivative instruments	1,119,332	1,077,142
Other current assets	147,969	155,955
Total current assets	1,656,451	1,706,590
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	18,246,897	18,068,900
Less accumulated depletion and amortization	-5,592,674	-4,867,682
Oil and natural gas properties, successful efforts method, net	12,654,223	13,201,218
Other property and equipment	682,772	669,149
Less accumulated depreciation	-158,409	-144,282
Other property and equipment, net	524,363	524,867
Derivative instruments	949,879	848,097
Other noncurrent assets	135,259	142,737
Noncurrent assets, excluding property, total	1,085,138	990,834
Total noncurrent assets	14,263,724	14,716,919
Total assets	15,920,175	16,423,509
Current liabilities:
Accounts payable and accrued expenses	608,926	814,809
Derivative instruments	899	0
Other accrued liabilities	184,430	167,736
Total current liabilities	794,255	982,545
Noncurrent liabilities:
Credit facilities	3,148,175	2,968,175
Term loan	500,000	500,000
Senior notes, net	6,750,313	6,827,634
Derivative instruments	1,999	684
Other noncurrent liabilities	598,930	600,866
Total noncurrent liabilities	10,999,417	10,897,359
Commitments and contingencies (Note 10)
Unitholders’ capital:
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	5,317,869	5,395,811
Accumulated deficit	-1,191,366	-852,206
Total unitholders' capital	4,126,503	4,543,605
Total liabilities and unitholders’ capital	$15,920,175	$16,423,509

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical)	Mar. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Unitholders' capital: Units issued	336,887,489	331,974,913
Unitholders' capital: Units outstanding	336,887,489	331,974,913

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues and other:
Oil, natural gas and natural gas liquids sales	$450,569	$938,877
Gains (losses) on oil and natural gas derivatives	424,781	-241,493
Marketing revenues	33,744	30,546
Other revenues	7,453	5,657
Total revenues	916,547	733,587
Expenses:
Lease operating expenses	173,021	194,033
Transportation expenses	53,540	45,630
Marketing expenses	28,841	21,072
General and administrative expenses	78,968	79,228
Exploration costs	396	1,091
Depreciation, depletion and amortization	215,014	267,801
Impairment of long-lived assets	532,617	0
Taxes, other than income taxes	54,045	65,713
(Gains) losses on sale of assets and other, net	-12,287	2,586
Total expenses	1,124,155	677,154
Other income and (expenses):
Interest expense, net of amounts capitalized	-143,101	-133,813
Gain on extinguishment of debt	6,635	0
Other, net	-2,213	-2,303
Total other income and (expenses)	-138,679	-136,116
Loss before income taxes	-346,287	-79,683
Income tax expense (benefit)	-7,127	5,654
Net loss	($339,160)	($85,337)
Net loss per unit:
Basic (in usd per unit)	($1.03)	($0.27)
Diluted (in usd per unit)	($1.03)	($0.27)
Weighted average units outstanding:
Basic (in units)	330,642	328,329
Diluted (in units)	330,642	328,329
Distributions declared per unit	$0.31	$0.73

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS' CAPITAL (Unaudited) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015
Increase (Decrease) in Unitholders' Capital
December 31, 2014 (in units)	331,974,913
31-Dec-14	$4,543,605
Sale of units (in units)	1,328,192
Sale of units, net of offering costs of $594	15,306
Issuance of units	0
Distributions to unitholders	-104,815
Unit-based compensation expenses	20,510
Excess tax benefit from unit-based compensation and other	-8,943
Net loss	-339,160
March 31, 2015 (in units)	336,887,489
31-Mar-15	4,126,503
Member Units [Member]
Increase (Decrease) in Unitholders' Capital
December 31, 2014 (in units)	331,975,000
Sale of units (in units)	1,328,000
Issuance of units (in units)	3,584,000
March 31, 2015 (in units)	336,887,000
Common Stock Including Additional Paid in Capital [Member]
Increase (Decrease) in Unitholders' Capital
31-Dec-14	5,395,811
Sale of units, net of offering costs of $594	15,306
Issuance of units	0
Distributions to unitholders	-104,815
Unit-based compensation expenses	20,510
Excess tax benefit from unit-based compensation and other	-8,943
Net loss	0
31-Mar-15	5,317,869
Accumulated Deficit
Increase (Decrease) in Unitholders' Capital
31-Dec-14	-852,206
Sale of units, net of offering costs of $594	0
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	-339,160
31-Mar-15	($1,191,366)

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS' CAPITAL (Unaudited) (Parenthetical) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Statement of Stockholders' Equity [Abstract]
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	$594

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flow from operating activities:
Net loss	($339,160)	($85,337)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	215,014	267,801
Impairment of long-lived assets	532,617	0
Unit-based compensation expenses	20,510	21,500
Gain on extinguishment of debt	-6,635	0
Amortization and write-off of deferred financing fees	6,712	2,313
(Gains) losses on sale of assets and other, net	-7,100	1,327
Deferred income taxes	-7,158	5,584
Derivatives activities:
Total (gains) losses	423,855	-241,493
Cash settlements	282,082	-14,511
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	135,230	-34,337
Increase in other assets	-12,399	-4,176
Increase (decrease) in accounts payable and accrued expenses	-29,868	16,105
Increase in other liabilities	8,713	16,720
Net cash provided by operating activities	374,703	434,482
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	0	-25,345
Development of oil and natural gas properties	-264,818	-394,843
Purchases of other property and equipment	-12,401	-10,151
Proceeds from sale of properties and equipment and other	27,500	-10,686
Net cash used in investing activities	-249,719	-441,025
Cash flow from financing activities:
Proceeds from sale of units	15,900	0
Proceeds from borrowings	395,000	540,000
Repayments of debt	-280,287	-241,188
Distributions to unitholders	-104,815	-240,073
Financing fees and offering costs	-453	-2,662
Excess tax benefit from unit-based compensation	-8,867	1,457
Other	-94,959	-34,848
Net cash provided by (used in) financing activities	-78,481	22,686
Net increase in cash and cash equivalents	46,503	16,143
Cash and cash equivalents:
Beginning	1,809	52,171
Ending	$48,312	$68,314

Basis_of_Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2015
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 Hugoton Basin, California, the Mid-Continent, the Permian Basin, TexLa, South Texas and Michigan/Illinois.
	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, 2014. 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. 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 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 April 2015, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify the presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2015, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its condensed consolidated financial statements and related disclosures.
	In May 2014, the FASB issued an 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 condensed consolidated financial statements and related disclosures.

Acquisitions_and_JointVenture_

Acquisitions and Joint-Venture Funding	3 Months Ended
	Mar. 31, 2015
Business Combinations [Abstract]
Acquisitions and Joint-Venture Funding	Acquisitions and Joint-Venture Funding
	The revenues and expenses related to certain oil and natural gas properties acquired in 2014 from subsidiaries of Devon Energy Corporation (“Devon” and the acquisition, the “Devon Assets Acquisition”) are included in the condensed consolidated results of operations of the Company as of August 29, 2014. The following unaudited pro forma financial information presents a summary of the Company’s consolidated results of operations for the three months ended March 31, 2014, assuming the Devon Assets Acquisition had been completed as of January 1, 2014, 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 transaction 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 transaction.
		Three Months Ended
		31-Mar-14
		(in thousands, except per unit amounts)
	Total revenues and other	$	879,115
	Total operating expenses	$	765,491
	Net loss	$	(62,305	)
	Net loss per unit:
	Basic	$	(0.20	)
	Diluted	$	(0.20	)
	The pro forma condensed combined statement of operations includes adjustments to:
	•	Reflect the results of the Devon Assets Acquisition.
	•	Reflect incremental depreciation, depletion and amortization expense, using the unit-of-production method related to oil and natural gas properties acquired and an estimated useful life of 10 years for other property and equipment.
	•	Reflect incremental accretion expense related to asset retirement obligations on oil and natural gas properties acquired.
	•	Reflect an increase in interest expense related to incremental debt of $2.3 billion incurred to fund the purchase price.
	•	Reflect incremental amortization of deferred financing fees associated with debt incurred to fund the purchase price.
	Joint-Venture Funding – 2014
	For the three months ended March 31, 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	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Unitholders' Capital	Unitholders’ Capital
	At-the-Market Offering Program
	The Company has the authority to sell up to $500 million of units under an at-the-market offering program. Sales of units, if any, will be made under an equity distribution agreement by means of ordinary brokers’ transactions, through the facilities of the NASDAQ Global Select Market, any other national securities exchange or facility thereof, a trading facility of a national securities association or an alternate trading system, to or through a market maker or directly on or through an electronic communication network, a “dark pool” or any similar market venue, at market prices, in block transactions, or as otherwise agreed with a sales agent. The Company expects to use the net proceeds from any sale of the units for general corporate purposes, which may include, among other things, capital expenditures, acquisitions and the repayment of debt.
	During the three months ended March 31, 2015, the Company, under its equity distribution agreement, issued and sold 1,328,192 units representing limited liability company interests at an average unit price of $11.97 for net proceeds of approximately $16 million (net of approximately $159,000 in commissions). In connection with the issuance and sale of these units, the Company also incurred professional service expenses of approximately $435,000. The Company used the net proceeds for general corporate purposes including the open market repurchases of a portion of its 8.625% senior notes due April 2020 (see Note 6). At March 31, 2015, units totaling approximately $484 million in aggregate offering price remained available to be issued and sold under the agreement.
	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 April 1, 2015, the Company’s Board of Directors declared a cash distribution of $0.3125 per unit with respect to the first quarter of 2015, to be paid in three equal installments of $0.1042 per unit. The first monthly distribution with respect to the first quarter of 2015, totaling approximately $35 million, was paid on April 16, 2015, to unitholders of record as of the close of business on April 13, 2015.

Oil_and_Natural_Gas_Properties

Oil and Natural Gas Properties	3 Months Ended
	Mar. 31, 2015
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:
		March 31,			December 31,
		2015			2014
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	13,368,818		$	13,362,642
	Development	3,012,467			2,830,841
	Unproved properties	1,865,612			1,875,417
		18,246,897			18,068,900
	Less accumulated depletion and amortization	(5,592,674		)	(4,867,682		)
		$	12,654,223		$	13,201,218
	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 of proved and risk-adjusted probable and possible reserves 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 ended March 31, 2015, the Company recorded noncash impairment charges, before and after tax, of approximately $533 million associated with proved oil and natural gas properties. The impairment was due to a decline in commodity prices. 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 impairment charges are included in “impairment of long-lived assets” on the condensed consolidated statement of operations. Following are the impairment charges recorded:
	•	Shallow Texas Panhandle Brown Dolomite formation – $278 million;
	•	California region – $207 million;
	•	TexLa region – $33 million;
	•	South Texas region – $9 million; and
	•	Mid-Continent region – $6 million.
	The Company recorded no impairment charges for the three months ended March 31, 2014.

UnitBased_Compensation

Unit-Based Compensation	3 Months Ended
	Mar. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Unit-Based Compensation	Unit-Based Compensation
	During the three months ended March 31, 2015, the Company granted 3,468,245 restricted units and 697,120 phantom units to employees, primarily as part of its annual review of its employees’ compensation, including executives, with an aggregate fair value of approximately $42 million. The restricted units and phantom units vest over three years. A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:
		Three Months Ended
		March 31,
		2015		2014
		(in thousands)
	General and administrative expenses	$	16,633	$	18,223
	Lease operating expenses	3,877		3,277
	Total unit-based compensation expenses	$	20,510	$	21,500
	Income tax benefit	$	7,579	$	7,944
	Cash-Based Performance Unit Awards
	The Company also granted 567,320 performance units (the maximum number of units available to be earned) to certain executive officers. The 2015 performance unit awards vest three years from the award date. The vesting of these units is determined based on the Company’s performance compared to the performance of a predetermined group of peer companies over a specified performance period, and the value of vested units is to be paid in cash. To date, no performance units have vested and no amounts have been paid to settle any such awards. Performance unit awards that are settled in cash are recorded as a liability with the changes in fair value recognized over the vesting period. For the three months ended March 31, 2015, the Company recognized expense for cash-based performance unit awards of approximately $266,000, included in “general and administrative expenses” on the condensed consolidated statement of operations. At March 31, 2015, the Company’s liability related to these performance unit awards was also approximately $266,000.

Debt

Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt	Debt
	The following summarizes the Company’s outstanding debt:
		March 31,			31-Dec-14
		2015
		(in thousands, except percentages)
	LINN credit facility (1)	$	1,975,000		$	1,795,000
	Berry credit facility (2)	1,173,175			1,173,175
	Term loan (3)	500,000			500,000
	6.50% senior notes due May 2019	1,200,000			1,200,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,220,800			1,300,000
	6.75% Berry senior notes due November 2020	299,970			299,970
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.50% senior notes due September 2021	650,000			650,000
	6.375% Berry senior notes due September 2022	599,163			599,163
	Net unamortized discounts and premiums	(19,620		)	(21,499		)
	Total debt, net	10,398,488			10,295,809
	Less current maturities	—			—
	Total long-term debt, net	$	10,398,488		$	10,295,809
	(1)	Variable interest rates of 1.93% and 1.92% at March 31, 2015, and December 31, 2014, respectively.
	(2)	Variable interest rates of 2.68% and 2.67% at March 31, 2015, and December 31, 2014, respectively.
	(3)	Variable interest rates of 2.68% and 2.66% at March 31, 2015, and December 31, 2014, respectively.
	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 loan 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.
		31-Mar-15						December 31, 2014
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facilities	$	3,148,175		$	3,148,175		$	2,968,175	$	2,968,175
	Term loan	500,000			500,000			500,000		500,000
	Senior notes, net	6,750,313			5,454,065			6,827,634		5,703,649
	Total debt, net	$	10,398,488		$	9,102,240		$	10,295,809	$	9,171,824
	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 $4.0 billion. The maturity date is April 2019. At March 31, 2015, the borrowing base under the LINN Credit Facility was $4.5 billion and availability under the revolving credit facility was approximately $2.0 billion, which includes a $6 million reduction for outstanding letters of credit.
	Redetermination of the borrowing base under the LINN Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. The administrative agent, at the direction of a super-majority 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 spring 2015 semi-annual redetermination is scheduled for May 2015, and the Company anticipates its lenders will recommend a decrease in the borrowing base under the LINN Credit Facility.
	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 Petroleum Company, LLC (“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 the 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 the 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”) currently has a borrowing base of $1.4 billion, subject to lender commitments. The maturity date is April 2019. At March 31, 2015, 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.
	Redetermination of the borrowing base under the Berry Credit Facility, based primarily on reserve reports using lender commodity price expectations 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. The spring 2015 semi-annual redetermination is scheduled for May 2015, and the Company anticipates its lenders will recommend a decrease in the borrowing base under the Berry Credit Facility.
	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 in compliance with all financial and other covenants of the Berry Credit Facility.
	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 the 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.”
	Repurchases of Senior Notes
	During the three months ended March 31, 2015, the Company repurchased on the open market approximately $79 million of its 8.625% senior notes due April 2020. In connection with the repurchases, the Company recorded a gain on extinguishment of debt of approximately $7 million for the three months ended March 31, 2015.
	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 or dividends 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.
	In addition, any cash generated by Berry is currently being used by Berry to fund its activities. To the extent that Berry generates cash in excess of its needs, the indentures governing Berry’s senior notes limit the amount it may distribute to LINN Energy to the amount available under a “restricted payments basket,” and Berry may not distribute any such amounts unless it is permitted by the indentures to incur additional debt pursuant to the consolidated coverage ratio test set forth in the Berry indentures. Berry’s restricted payments basket may be increased in accordance with the terms of the Berry indentures by, among other things, 50% of Berry’s future net income, reductions in its indebtedness and restricted investments, and future capital contributions.

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2015
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 also hedges its exposure to natural gas differentials in certain operating areas but does not currently hedge exposure to oil differentials.
	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 or consumption to provide an economic hedge of the risk related to the future commodity prices received or paid. The Company does not enter into derivative contracts for trading purposes. In connection with the 2013 acquisition of Berry, the Company assumed certain derivative contracts that Berry had entered into prior to the acquisition date, including swap contracts, collars and three-way collars. The Company did not designate any of its 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 March 31, 2015:
		April 1 - December 31, 2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	88,935			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	54,137			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	4.88		$	—
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	9,426			11,465			4,755			—
	Average price ($/Bbl)	$	93.33		$	90.56		$	89.02		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	825			—			—			—
	Short put ($/Bbl)	$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	101.62		$	—		$	—		$	—
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	2,581			3,271			384			—
	Average price ($/Bbl)	$	90		$	90		$	90		$	—
		April 1 - December 31, 2015			2016			2017			2018
	Natural gas basis differential positions: (2)
	Panhandle basis swaps: (3)
	Hedged volume (MMMBtu)	65,670			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps: (3)
	Hedged volume (MMMBtu)	43,707			65,794			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.23	)	$	(0.24	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps: (3)
	Hedged volume (MMMBtu)	7,040			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps: (3)
	Hedged volume (MMMBtu)	19,351			34,364			36,730			986
	Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.02	)	$	(0.02	)	$	(0.08	)
	Permian basis swaps: (3)
	Hedged volume (MMMBtu)	3,823			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	SoCal basis swaps: (4)
	Hedged volume (MMMBtu)	22,050			32,940			—			—
	Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.03	)	$	—		$	—
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (5)
	Hedged volume (MBbls)	5,463			7,446			6,486			—
	Hedged differential ($/Bbl)	$	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, at counterparty election 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)	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.
	(4)	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.
	(5)	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”).
	During the three months ended March 31, 2015, the Company entered into commodity derivative contracts consisting of natural gas basis swaps for May 2015 through December 2017, to hedge exposure to differentials in certain producing areas, and oil swaps for April 2015 through December 2015. In addition, the Company entered into natural gas basis swaps for May 2015 through December 2016 to hedge exposure to the differential in California, where it consumes natural gas in its heavy oil development operations.
	Settled derivatives on natural gas production for the three months ended March 31, 2015, included volumes of 46,823 MMMBtu at an average contract price of $5.12 per MMBtu. Settled derivatives on oil production for the three months ended March 31, 2015, included volumes of 3,975 MBbls at an average contract price of $94.29 per Bbl. Settled derivatives on natural gas production for the three months ended March 31, 2014, included volumes of 43,651 MMMBtu at an average contract price of $5.14 per MMBtu. Settled derivatives on oil production for the three months ended March 31, 2014, included volumes of 6,161 MBbls at an average contract price of $92.39 per Bbl.
	The natural gas derivatives are settled based on the closing price of NYMEX Henry Hub 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 price of NYMEX WTI 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:
		31-Mar-15			December 31,
					2014
		(in thousands)
	Assets:
	Commodity derivatives	$	2,106,710		$	2,014,815
Liabilities:
Commodity derivatives	$	40,397		$	90,260
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 $2.1 billion at March 31, 2015. 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 used to hedge production were net gains of approximately $425 million for the three months March 31, 2015, and net losses of approximately $241 million for the three months ended March 31, 2014, and are reported on the condensed consolidated statements of operations in “gains (losses) on oil and natural gas derivatives.” Gains and losses on derivatives used to hedge natural gas consumption, entered into in March 2015, were net losses of approximately $1 million for the three months ended March 31, 2015, and are reported on the condensed consolidated statement of operations in “lease operating expenses.” For the three months ended March 31, 2015, and March 31, 2014, the Company received net cash settlements of approximately $282 million and paid net cash settlements of approximately $15 million, respectively.

Fair_Value_Measurements_on_a_R

Fair Value Measurements on a Recurring Basis	3 Months Ended
	Mar. 31, 2015
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 instruments 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.
	Fair Value Hierarchy
	In accordance with applicable accounting standards, the Company has categorized its financial instruments, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		31-Mar-15
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	2,106,710	$	(37,499	)	$	2,069,211
	Liabilities:
	Commodity derivatives	$	40,397	$	(37,499	)	$	2,898
		31-Dec-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	2,014,815	$	(89,576	)	$	1,925,239
	Liabilities:
	Commodity derivatives	$	90,260	$	(89,576	)	$	684
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations
	The Company has the obligation to plug and abandon oil and natural gas wells and related equipment at the end of production operations. Estimated asset retirement costs are recognized as liabilities with an increase to the carrying amounts of the related long-lived assets when the obligation is incurred. The liabilities 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% for the three months ended March 31, 2015); and (iv) a credit-adjusted risk-free interest rate (average of 5.6% for the three months ended March 31, 2015). 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 Company’s asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2014	$	497,570
	Liabilities added from drilling	1,390
	Current year accretion expense	7,399
	Settlements	(1,783		)
	Revision of estimates	(1,345		)
	Asset retirement obligations at March 31, 2015	$	503,231

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
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 Company’s motion to dismiss was denied by the Court, and the parties have agreed on a scheduling order, which provides for briefing on the class certification issues in late 2015 and the first part of 2016. The Company has denied that it has liability on the claims asserted in the case and has denied that class certification is proper. If the Court accepts the Company’s arguments, there will be no liability to the Company in the case. For another statewide class action royalty payment dispute, briefing on class certification issues is expected to be completed during the summer of 2015. The Company has denied that it has any liability on the claims and has denied that class certification is proper. If the Court accepts the Company’s arguments, there will be no liability to the Company in the case. The Company is unable to estimate a possible loss, or range of possible loss, if any, in these cases. 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.
	During the three months ended March 31, 2015, and March 31, 2014, 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.

Earnings_Per_Unit

Earnings Per Unit	3 Months Ended
	Mar. 31, 2015
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 loss:
		Three Months Ended
		March 31,
		2015			2014
		(in thousands,
		except per unit data)
	Net loss	$	(339,160	)	$	(85,337	)
	Allocated to participating securities	(1,781		)	(2,199		)
		$	(340,941	)	$	(87,536	)
	Basic net loss per unit	$	(1.03	)	$	(0.27	)
	Diluted net loss per unit	$	(1.03	)	$	(0.27	)
	Basic weighted average units outstanding	330,642			328,329
	Dilutive effect of unit equivalents	—			—
	Diluted weighted average units outstanding	330,642			328,329
	Basic units outstanding excludes the effect of weighted average anti-dilutive unit equivalents related to approximately 5 million and 6 million unit options and warrants for the three months ended March 31, 2015, and March 31, 2014, respectively. All equivalent units were antidilutive for both the three months ended March 31, 2015, and March 31, 2014.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
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	3 Months Ended
	Mar. 31, 2015
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:
		March 31,		December 31,
		2015		2014
		(in thousands)
	Accrued interest	$	143,088	$	105,310
	Accrued compensation	22,854		44,875
	Asset retirement obligations	16,187		16,187
	Other	2,301		1,364
		$	184,430	$	167,736
	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Three Months Ended
		March 31,
		2015		2014
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	98,541	$	77,512
	Cash payments for income taxes	$	57	$	—
	Noncash investing activities:
	Accrued capital expenditures	$	161,247	$	338,323
	Included in “acquisition of oil and natural gas properties and joint-venture funding” on the condensed consolidated statement of cash flows for the three months ended March 31, 2014, is approximately $25 million paid by the Company to fund the commitment related to the joint-venture agreement entered into with Anadarko in April 2012 (see Note 2).
	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 both March 31, 2015, and December 31, 2014, 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 December 31, 2014, net outstanding checks of approximately $95 million were reclassified and included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet. At March 31, 2015, no net outstanding checks were reclassified. Net outstanding checks are presented as cash flows from financing activities and included in “other” on the condensed consolidated statements of cash flows.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions
	LinnCo
	LinnCo, LLC (“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 2013 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 March 31, 2015, 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 financial, legal, accounting, tax advisory, financial advisory and engineering fees, and 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 expensed by LINN Energy.
	For the three months ended March 31, 2015, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $1.4 million, of which approximately $1.1 million had been paid by LINN Energy on LinnCo’s behalf as of March 31, 2015. The expenses for the three months ended March 31, 2015, include approximately $491,000 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.
	For the three months ended March 31, 2014, LinnCo incurred total general and administrative expenses of approximately $734,000, of which approximately $83,000 had been paid by LINN Energy on LinnCo’s behalf as of March 31, 2014. The expenses for the three months ended March 31, 2014, include approximately $470,000 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 three months ended March 31, 2014, LINN Energy paid approximately $11 million on LinnCo’s behalf for general and administrative expenses incurred by LinnCo in 2013.
	During the three months ended March 31, 2015, and March 31, 2014, the Company paid approximately $40 million and $93 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 ended March 31, 2015, and March 31, 2014, the Company incurred expenditures of approximately $3 million and $4 million, respectively, related to services rendered by Superior and its subsidiaries.

Subsidiary_Guarantors

Subsidiary Guarantors	3 Months Ended
	Mar. 31, 2015
Condensed Consolidating Financial Information [Abstract]
Subsidiary Guarantors	Subsidiary Guarantors
	LINN Energy, LLC’s May 2019 senior notes, November 2019 senior notes, April 2020 senior notes, February 2021 senior notes and September 2021 senior notes are guaranteed by all of the Company’s material subsidiaries, other than Berry Petroleum Company, LLC, which is an indirect 100% wholly owned subsidiary of the Company.
	The following condensed consolidating financial information presents the financial information of LINN Energy, LLC, the guarantor subsidiaries and the non-guarantor subsidiary 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 or non-guarantor subsidiary 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
	31-Mar-15
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	3,864		$	43,024		$	1,424		$	—		$	48,312
	Accounts receivable – trade, net	—			251,957			88,881			—			340,838
	Accounts receivable – affiliates	4,011,808			33,061			—			(4,044,869		)	—
	Derivative instruments	—			1,099,777			19,555			—			1,119,332
	Other current assets	18			94,722			53,229			—			147,969
	Total current assets	4,015,690			1,522,541			163,089			(4,044,869		)	1,656,451
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,318,736			4,928,161			—			18,246,897
	Less accumulated depletion and amortization	—			(4,790,872		)	(865,266		)	63,464			(5,592,674		)
		—			8,527,864			4,062,895			63,464			12,654,223
	Other property and equipment	—			564,928			117,844			—			682,772
	Less accumulated depreciation	—			(147,307		)	(11,102		)	—			(158,409		)
		—			417,621			106,742			—			524,363
	Derivative instruments	—			949,798			81			—			949,879
	Notes receivable – affiliates	146,900			—			—			(146,900		)	—
	Advance to affiliate	—			—			220,571			(220,571		)	—
	Investments in consolidated subsidiaries	8,296,020			—			—			(8,296,020		)	—
	Other noncurrent assets, net	110,256			11,660			13,343			—			135,259
		8,553,176			961,458			233,995			(8,663,491		)	1,085,138
	Total noncurrent assets	8,553,176			9,906,943			4,403,632			(8,600,027		)	14,263,724
	Total assets	$	12,568,866		$	11,429,484		$	4,566,721		$	(12,644,896	)	$	15,920,175
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	5,150		$	422,042		$	181,734		$	—		$	608,926
	Accounts payable – affiliates	—			4,011,808			33,061			(4,044,869		)	—
	Advance from affiliate	—			220,571			—			(220,571		)	—
	Derivative instruments	—			—			899			—			899
	Other accrued liabilities	132,202			37,872			14,356			—			184,430
	Total current liabilities	137,352			4,692,293			230,050			(4,265,440		)	794,255
	Noncurrent liabilities:
	Credit facilities	1,975,000			—			1,173,175			—			3,148,175
	Term loan	500,000			—			—			—			500,000
	Senior notes, net	5,836,998			—			913,315			—			6,750,313
	Notes payable – affiliates	—			146,900			—			(146,900		)	—
	Derivative instruments	—			1,770			229			—			1,999
	Other noncurrent liabilities	—			401,479			197,451			—			598,930
	Total noncurrent liabilities	8,311,998			550,149			2,284,170			(146,900		)	10,999,417
	Unitholders’ capital:
	Units issued and outstanding	5,310,882			4,831,265			2,372,603			(7,196,881		)	5,317,869
	Accumulated income (deficit)	(1,191,366		)	1,355,777			(320,102		)	(1,035,675		)	(1,191,366		)
		4,119,516			6,187,042			2,052,501			(8,232,556		)	4,126,503
	Total liabilities and unitholders’ capital	$	12,568,866		$	11,429,484		$	4,566,721		$	(12,644,896	)	$	15,920,175
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-14
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	38		$	185		$	1,586		$	—		$	1,809
	Accounts receivable – trade, net	—			371,325			100,359			—			471,684
	Accounts receivable – affiliates	4,028,890			13,205			—			(4,042,095		)	—
	Derivative instruments	—			1,033,448			43,694			—			1,077,142
	Other current assets	18			96,678			59,259			—			155,955
Total current assets	4,028,946			1,514,841			204,898			(4,042,095		)	1,706,590
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	—			13,196,841			4,872,059			—			18,068,900
Less accumulated depletion and amortization	—			(4,342,675		)	(525,007		)	—			(4,867,682		)
	—			8,854,166			4,347,052			—			13,201,218
Other property and equipment	—			553,150			115,999			—			669,149
Less accumulated depreciation	—			(135,830		)	(8,452		)	—			(144,282		)
	—			417,320			107,547			—			524,867
Derivative instruments	—			848,097			—			—			848,097
Notes receivable – affiliates	130,500			—			—			(130,500		)	—
Advance to affiliate	—			—			293,627			(293,627		)	—
Investments in consolidated subsidiaries	8,562,608			—			—			(8,562,608		)	—
Other noncurrent assets, net	116,637			11,816			14,284			—			142,737
	8,809,745			859,913			307,911			(8,986,735		)	990,834
Total noncurrent assets	8,809,745			10,131,399			4,762,510			(8,986,735		)	14,716,919
Total assets	$	12,838,691		$	11,646,240		$	4,967,408		$	(13,028,830	)	$	16,423,509
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	3,784		$	581,880		$	229,145		$	—		$	814,809
Accounts payable – affiliates	—			4,028,890			13,205			(4,042,095		)	—
Advance from affiliate	—			293,627			—			(293,627		)	—
Derivative instruments	—			—			—			—			—
Other accrued liabilities	89,507			59,142			19,087			—			167,736
Total current liabilities	93,291			4,963,539			261,437			(4,335,722		)	982,545
Noncurrent liabilities:
Credit facilities	1,795,000			—			1,173,175			—			2,968,175
Term loan	500,000			—			—			—			500,000
Senior notes, net	5,913,857			—			913,777			—			6,827,634
Notes payable – affiliates	—			130,500			—			(130,500		)	—
Derivative instruments	—			684			—			—			684
Other noncurrent liabilities	—			400,851			200,015			—			600,866
Total noncurrent liabilities	8,208,857			532,035			2,286,967			(130,500		)	10,897,359
Unitholders’ capital:
Units issued and outstanding	5,388,749			4,831,339			2,416,381			(7,240,658		)	5,395,811
Accumulated income (deficit)	(852,206		)	1,319,327			2,623			(1,321,950		)	(852,206		)
	4,536,543			6,150,666			2,419,004			(8,562,608		)	4,543,605
Total liabilities and unitholders’ capital	$	12,838,691		$	11,646,240		$	4,967,408		$	(13,028,830	)	$	16,423,509
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended March 31, 2015
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	293,983		$	156,586		$	—		$	450,569
Gains on oil and natural gas derivatives	—			421,514			3,267			—			424,781
Marketing revenues	—			26,212			7,532			—			33,744
Other revenues	—			5,557			1,896			—			7,453
	—			747,266			169,281			—			916,547
Expenses:
Lease operating expenses	—			105,832			67,189			—			173,021
Transportation expenses	—			40,934			12,606			—			53,540
Marketing expenses	—			23,196			5,645			—			28,841
General and administrative expenses	—			57,781			21,187			—			78,968
Exploration costs	—			396			—			—			396
Depreciation, depletion and amortization	—			140,699			72,979			1,336			215,014
Impairment of long-lived assets	—			325,417			272,000			(64,800		)	532,617
Taxes, other than income taxes	2			30,711			23,332			—			54,045
Gains on sale of assets and other, net	—			(7,814		)	(4,473		)	—			(12,287		)
	2			717,152			470,465			(63,464		)	1,124,155
Other income and (expenses):
Interest expense, net of amounts capitalized	(123,386		)	1,706			(21,421		)	—			(143,101		)
Interest expense – affiliates	—			(2,382		)	—			2,382			—
Interest income – affiliates	2,382			—			—			(2,382		)	—
Gain on extinguishment of debt	6,635			—			—			—			6,635
Equity in losses from consolidated subsidiaries	(222,811		)	—			—			222,811			—
Other, net	(1,978		)	(65		)	(170		)	—			(2,213		)
	(339,158		)	(741		)	(21,591		)	222,811			(138,679		)
Income (loss) before income taxes	(339,160		)	29,373			(322,775		)	286,275			(346,287		)
Income tax benefit	—			(7,077		)	(50		)	—			(7,127		)
Net income (loss)	$	(339,160	)	$	36,450		$	(322,725	)	$	286,275		$	(339,160	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended March 31, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	605,761		$	333,116		$	—		$	938,877
Gains (losses) on oil and natural gas derivatives	—			(244,958		)	3,465			—			(241,493		)
Marketing revenues	—			15,731			14,815			—			30,546
Other revenues	—			5,673			(16		)	—			5,657
	—			382,207			351,380			—			733,587
Expenses:
Lease operating expenses	—			104,002			90,031			—			194,033
Transportation expenses	—			37,637			7,993			—			45,630
Marketing expenses	—			10,091			10,981			—			21,072
General and administrative expenses	—			35,737			43,491			—			79,228
Exploration costs	—			1,091			—			—			1,091
Depreciation, depletion and amortization	—			199,170			68,631			—			267,801
Taxes, other than income taxes	—			42,684			23,029			—			65,713
(Gains) losses on sale of assets and other, net	—			(781		)	3,367			—			2,586
	—			429,631			247,523			—			677,154
Other income and (expenses):
Interest expense, net of amounts capitalized	(109,650		)	(162		)	(24,001		)	—			(133,813		)
Interest expense – affiliates	—			(1,550		)	—			1,550			—
Interest income – affiliates	1,550			—			—			(1,550		)	—
Equity in earnings from consolidated subsidiaries	24,893			—			—			(24,893		)	—
Other, net	(2,130		)	16			(189		)	—			(2,303		)
	(85,337		)	(1,696		)	(24,190		)	(24,893		)	(136,116		)
Income (loss) before income taxes	(85,337		)	(49,120		)	79,667			(24,893		)	(79,683		)
Income tax expense (benefit)	—			5,685			(31		)	—			5,654
Net income (loss)	$	(85,337	)	$	(54,805	)	$	79,698		$	(24,893	)	$	(85,337	)
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2015
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from operating activities:
Net income (loss)	$	(339,160	)	$	36,450		$	(322,725	)	$	286,275		$	(339,160	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	—			140,699			72,979			1,336			215,014
Impairment of long-lived assets	—			325,417			272,000			(64,800		)	532,617
Unit-based compensation expenses	—			20,510			—			—			20,510
Gain on extinguishment of debt	(6,635		)	—			—			—			(6,635		)
Amortization and write-off of deferred financing fees	6,453			—			259			—			6,712
Gains on sale of assets and other, net	—			(5,243		)	(1,857		)	—			(7,100		)
Equity in losses from consolidated subsidiaries	222,811			—			—			(222,811		)	—
Deferred income taxes	—			(7,108		)	(50		)	—			(7,158		)
Derivatives activities:
Total gains	—			(421,514		)	(2,341		)	—			(423,855		)
Cash settlements	—			254,569			27,513			—			282,082
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	21,921			96,917			16,392			—			135,230
(Increase) decrease in accounts receivable – affiliates	17,082			(19,856		)	—			2,774			—
Increase in other assets	—			(8,521		)	(3,878		)	—			(12,399		)
Decrease in accounts payable and accrued expenses	(290		)	(3,844		)	(25,734		)	—			(29,868		)
Increase (decrease) in accounts payable and accrued expenses – affiliates	—			(17,082		)	19,856			(2,774		)	—
Increase (decrease) in other liabilities	42,695			(24,057		)	(9,925		)	—			8,713
Net cash provided by (used in) operating activities	(35,123		)	367,337			42,489			—			374,703
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			—			—			—			—
Development of oil and natural gas properties	—			(263,209		)	(1,609		)	—			(264,818		)
Purchases of other property and equipment	—			(11,309		)	(1,092		)	—			(12,401		)
Investment in affiliates	43,778			—			—			(43,778		)	—
Change in notes receivable with affiliate	(16,400		)	—			—			16,400			—
Proceeds from sale of properties and equipment and other	(1,121		)	24,808			3,813			—			27,500
Net cash provided by (used in) investing activities	26,257			(249,710		)	1,112			(27,378		)	(249,719		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from sale of units	15,900			—			—			—			15,900
Proceeds from borrowings	395,000			—			—			—			395,000
Repayments of debt	(280,287		)	—			—			—			(280,287		)
Distributions to unitholders	(104,815		)	—			—			—			(104,815		)
Financing fees and offering costs	(453		)	—			—			—			(453		)
Change in notes payable with affiliate	—			16,400			—			(16,400		)	—
Distribution to affiliate	—			—			(43,778		)	43,778			—
Excess tax benefit from unit-based compensation	(8,867		)	—			—			—			(8,867		)
Other	(3,786		)	(91,188		)	15			—			(94,959		)
Net cash provided by (used in) financing activities	12,692			(74,788		)	(43,763		)	27,378			(78,481		)
Net increase (decrease) in cash and cash equivalents	3,826			42,839			(162		)	—			46,503
Cash and cash equivalents:
Beginning	38			185			1,586			—			1,809
Ending	$	3,864		$	43,024		$	1,424		$	—		$	48,312
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from operating activities:
Net income (loss)	$	(85,337	)	$	(54,805	)	$	79,698		$	(24,893	)	$	(85,337	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	—			199,170			68,631			—			267,801
Unit-based compensation expenses	—			21,500			—			—			21,500
Amortization and write-off of deferred financing fees	5,791			—			(3,478		)	—			2,313
Losses on sale of assets and other, net	—			1,327			—			—			1,327
Equity in earnings from consolidated subsidiaries	(24,893		)	—			—			24,893			—
Deferred income taxes	—			5,615			(31		)	—			5,584
Derivatives activities:
Total (gains) losses	—			244,958			(3,465		)	—			241,493
Cash settlements	—			(11,856		)	(2,655		)	—			(14,511		)
Changes in assets and liabilities:
Increase in accounts receivable – trade, net	—			(18,964		)	(15,373		)	—			(34,337		)
Decrease in accounts receivable – affiliates	10,513			16,950			—			(27,463		)	—
Increase in other assets	—			(3,136		)	(1,040		)	—			(4,176		)
Increase (decrease) in accounts payable and accrued expenses	30			20,252			(4,177		)	—			16,105
Decrease in accounts payable and accrued expenses – affiliates	—			(10,513		)	(16,950		)	27,463			—
Increase (decrease) in other liabilities	53,698			(30,648		)	(6,330		)	—			16,720
Net cash provided by (used in) operating activities	(40,198		)	379,850			94,830			—			434,482
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(25,345		)	—			—			(25,345		)
Development of oil and natural gas properties	—			(260,093		)	(134,750		)	—			(394,843		)
Purchases of other property and equipment	—			(8,318		)	(1,833		)	—			(10,151		)
Change in notes receivable with affiliate	(9,200		)	—			—			9,200			—
Proceeds from sale of properties and equipment and other	(11,230		)	544			—			—			(10,686		)
Net cash used in investing activities	(20,430		)	(293,212		)	(136,583		)	9,200			(441,025		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from borrowings	540,000			—			—			—			540,000
Repayments of debt	(240,000		)	—			(1,188		)	—			(241,188		)
Distributions to unitholders	(240,073		)	—			—			—			(240,073		)
Financing fees and offering costs	(81		)	—			(2,581		)	—			(2,662		)
Change in notes payable with affiliate	—			9,200			—			(9,200		)	—
Excess tax benefit from unit-based compensation	—			1,457			—			—			1,457
Other	763			(35,611		)	—			—			(34,848		)
Net cash provided by (used in) financing activities	60,609			(24,954		)	(3,769		)	(9,200		)	22,686
Net increase (decrease) in cash and cash equivalents	(19		)	61,684			(45,522		)	—			16,143
Cash and cash equivalents:
Beginning	52			1,078			51,041			—			52,171
Ending	$	33		$	62,762		$	5,519		$	—		$	68,314

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2015
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, 2014. 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. 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 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 April 2015, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify the presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2015, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its condensed consolidated financial statements and related disclosures.
	In May 2014, the FASB issued an 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 condensed consolidated financial statements and related disclosures.

Acquisitions_and_JointVenture_1

Acquisitions and Joint-Venture Funding (Tables)	3 Months Ended
	Mar. 31, 2015
Business Combinations [Abstract]
Schedule of Pro Forma Results of Business Combination
		Three Months Ended
		31-Mar-14
		(in thousands, except per unit amounts)
	Total revenues and other	$	879,115
	Total operating expenses	$	765,491
	Net loss	$	(62,305	)
	Net loss per unit:
	Basic	$	(0.20	)
	Diluted	$	(0.20	)
	The pro forma condensed combined statement of operations includes adjustments to:
	•	Reflect the results of the Devon Assets Acquisition.
	•	Reflect incremental depreciation, depletion and amortization expense, using the unit-of-production method related to oil and natural gas properties acquired and an estimated useful life of 10 years for other property and equipment.
	•	Reflect incremental accretion expense related to asset retirement obligations on oil and natural gas properties acquired.
	•	Reflect an increase in interest expense related to incremental debt of $2.3 billion incurred to fund the purchase price.
	•	Reflect incremental amortization of deferred financing fees associated with debt incurred to fund the purchase price.

Oil_and_Natural_Gas_Properties1

Oil and Natural Gas Properties (Tables)	3 Months Ended
	Mar. 31, 2015
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:
		March 31,			December 31,
		2015			2014
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	13,368,818		$	13,362,642
	Development	3,012,467			2,830,841
	Unproved properties	1,865,612			1,875,417
		18,246,897			18,068,900
	Less accumulated depletion and amortization	(5,592,674		)	(4,867,682		)
		$	12,654,223		$	13,201,218

UnitBased_Compensation_Tables

Unit-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
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
		March 31,
		2015		2014
		(in thousands)
	General and administrative expenses	$	16,633	$	18,223
	Lease operating expenses	3,877		3,277
	Total unit-based compensation expenses	$	20,510	$	21,500
	Income tax benefit	$	7,579	$	7,944

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Summary of Outstanding Debt	The following summarizes the Company’s outstanding debt:
		March 31,			31-Dec-14
		2015
		(in thousands, except percentages)
	LINN credit facility (1)	$	1,975,000		$	1,795,000
	Berry credit facility (2)	1,173,175			1,173,175
	Term loan (3)	500,000			500,000
	6.50% senior notes due May 2019	1,200,000			1,200,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,220,800			1,300,000
	6.75% Berry senior notes due November 2020	299,970			299,970
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.50% senior notes due September 2021	650,000			650,000
	6.375% Berry senior notes due September 2022	599,163			599,163
	Net unamortized discounts and premiums	(19,620		)	(21,499		)
	Total debt, net	10,398,488			10,295,809
	Less current maturities	—			—
	Total long-term debt, net	$	10,398,488		$	10,295,809
	(1)	Variable interest rates of 1.93% and 1.92% at March 31, 2015, and December 31, 2014, respectively.
	(2)	Variable interest rates of 2.68% and 2.67% at March 31, 2015, and December 31, 2014, respectively.
	(3)	Variable interest rates of 2.68% and 2.66% at March 31, 2015, and December 31, 2014, respectively.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments
		31-Mar-15						December 31, 2014
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facilities	$	3,148,175		$	3,148,175		$	2,968,175	$	2,968,175
	Term loan	500,000			500,000			500,000		500,000
	Senior notes, net	6,750,313			5,454,065			6,827,634		5,703,649
	Total debt, net	$	10,398,488		$	9,102,240		$	10,295,809	$	9,171,824

Derivatives_Tables

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following table summarizes derivative positions for the periods indicated as of March 31, 2015:
		April 1 - December 31, 2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	88,935			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	54,137			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	4.88		$	—
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	9,426			11,465			4,755			—
	Average price ($/Bbl)	$	93.33		$	90.56		$	89.02		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	825			—			—			—
	Short put ($/Bbl)	$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	101.62		$	—		$	—		$	—
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	2,581			3,271			384			—
	Average price ($/Bbl)	$	90		$	90		$	90		$	—
		April 1 - December 31, 2015			2016			2017			2018
	Natural gas basis differential positions: (2)
	Panhandle basis swaps: (3)
	Hedged volume (MMMBtu)	65,670			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps: (3)
	Hedged volume (MMMBtu)	43,707			65,794			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.23	)	$	(0.24	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps: (3)
	Hedged volume (MMMBtu)	7,040			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps: (3)
	Hedged volume (MMMBtu)	19,351			34,364			36,730			986
	Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.02	)	$	(0.02	)	$	(0.08	)
	Permian basis swaps: (3)
	Hedged volume (MMMBtu)	3,823			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	SoCal basis swaps: (4)
	Hedged volume (MMMBtu)	22,050			32,940			—			—
	Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.03	)	$	—		$	—
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (5)
	Hedged volume (MBbls)	5,463			7,446			6,486			—
	Hedged differential ($/Bbl)	$	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, at counterparty election 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)	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.
	(4)	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.
	(5)	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:
		31-Mar-15			December 31,
					2014
		(in thousands)
	Assets:
	Commodity derivatives	$	2,106,710		$	2,014,815
	Liabilities:
	Commodity derivatives	$	40,397		$	90,260

Fair_Value_Measurements_on_a_R1

Fair Value Measurements on a Recurring Basis (Tables)	3 Months Ended
	Mar. 31, 2015
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:
		31-Mar-15
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	2,106,710	$	(37,499	)	$	2,069,211
	Liabilities:
	Commodity derivatives	$	40,397	$	(37,499	)	$	2,898
		31-Dec-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	2,014,815	$	(89,576	)	$	1,925,239
	Liabilities:
	Commodity derivatives	$	90,260	$	(89,576	)	$	684
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations Reconciliation	The following presents a reconciliation of the Company’s asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2014	$	497,570
	Liabilities added from drilling	1,390
	Current year accretion expense	7,399
	Settlements	(1,783		)
	Revision of estimates	(1,345		)
	Asset retirement obligations at March 31, 2015	$	503,231

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	3 Months Ended
	Mar. 31, 2015
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 loss:
		Three Months Ended
		March 31,
		2015			2014
		(in thousands,
		except per unit data)
	Net loss	$	(339,160	)	$	(85,337	)
	Allocated to participating securities	(1,781		)	(2,199		)
		$	(340,941	)	$	(87,536	)
	Basic net loss per unit	$	(1.03	)	$	(0.27	)
	Diluted net loss per unit	$	(1.03	)	$	(0.27	)
	Basic weighted average units outstanding	330,642			328,329
	Dilutive effect of unit equivalents	—			—
	Diluted weighted average units outstanding	330,642			328,329

Supplemental_Disclosures_to_th1

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Tables)	3 Months Ended
	Mar. 31, 2015
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]
Other Accrued Liabilities	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:
		March 31,		December 31,
		2015		2014
		(in thousands)
	Accrued interest	$	143,088	$	105,310
	Accrued compensation	22,854		44,875
	Asset retirement obligations	16,187		16,187
	Other	2,301		1,364
		$	184,430	$	167,736
Supplemental Disclosures to the Condensed Conslidated Statements of Cash Flow	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Three Months Ended
		March 31,
		2015		2014
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	98,541	$	77,512
	Cash payments for income taxes	$	57	$	—
	Noncash investing activities:
	Accrued capital expenditures	$	161,247	$	338,323

Subsidiary_Guarantors_Tables

Subsidiary Guarantors (Tables)	3 Months Ended
	Mar. 31, 2015
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Mar-15
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	3,864		$	43,024		$	1,424		$	—		$	48,312
	Accounts receivable – trade, net	—			251,957			88,881			—			340,838
	Accounts receivable – affiliates	4,011,808			33,061			—			(4,044,869		)	—
	Derivative instruments	—			1,099,777			19,555			—			1,119,332
	Other current assets	18			94,722			53,229			—			147,969
	Total current assets	4,015,690			1,522,541			163,089			(4,044,869		)	1,656,451
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,318,736			4,928,161			—			18,246,897
	Less accumulated depletion and amortization	—			(4,790,872		)	(865,266		)	63,464			(5,592,674		)
		—			8,527,864			4,062,895			63,464			12,654,223
	Other property and equipment	—			564,928			117,844			—			682,772
	Less accumulated depreciation	—			(147,307		)	(11,102		)	—			(158,409		)
		—			417,621			106,742			—			524,363
	Derivative instruments	—			949,798			81			—			949,879
	Notes receivable – affiliates	146,900			—			—			(146,900		)	—
	Advance to affiliate	—			—			220,571			(220,571		)	—
	Investments in consolidated subsidiaries	8,296,020			—			—			(8,296,020		)	—
	Other noncurrent assets, net	110,256			11,660			13,343			—			135,259
		8,553,176			961,458			233,995			(8,663,491		)	1,085,138
	Total noncurrent assets	8,553,176			9,906,943			4,403,632			(8,600,027		)	14,263,724
	Total assets	$	12,568,866		$	11,429,484		$	4,566,721		$	(12,644,896	)	$	15,920,175
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	5,150		$	422,042		$	181,734		$	—		$	608,926
	Accounts payable – affiliates	—			4,011,808			33,061			(4,044,869		)	—
	Advance from affiliate	—			220,571			—			(220,571		)	—
	Derivative instruments	—			—			899			—			899
	Other accrued liabilities	132,202			37,872			14,356			—			184,430
	Total current liabilities	137,352			4,692,293			230,050			(4,265,440		)	794,255
	Noncurrent liabilities:
	Credit facilities	1,975,000			—			1,173,175			—			3,148,175
	Term loan	500,000			—			—			—			500,000
	Senior notes, net	5,836,998			—			913,315			—			6,750,313
	Notes payable – affiliates	—			146,900			—			(146,900		)	—
	Derivative instruments	—			1,770			229			—			1,999
	Other noncurrent liabilities	—			401,479			197,451			—			598,930
	Total noncurrent liabilities	8,311,998			550,149			2,284,170			(146,900		)	10,999,417
	Unitholders’ capital:
	Units issued and outstanding	5,310,882			4,831,265			2,372,603			(7,196,881		)	5,317,869
	Accumulated income (deficit)	(1,191,366		)	1,355,777			(320,102		)	(1,035,675		)	(1,191,366		)
		4,119,516			6,187,042			2,052,501			(8,232,556		)	4,126,503
	Total liabilities and unitholders’ capital	$	12,568,866		$	11,429,484		$	4,566,721		$	(12,644,896	)	$	15,920,175
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-14
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	38		$	185		$	1,586		$	—		$	1,809
	Accounts receivable – trade, net	—			371,325			100,359			—			471,684
	Accounts receivable – affiliates	4,028,890			13,205			—			(4,042,095		)	—
	Derivative instruments	—			1,033,448			43,694			—			1,077,142
	Other current assets	18			96,678			59,259			—			155,955
	Total current assets	4,028,946			1,514,841			204,898			(4,042,095		)	1,706,590
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,196,841			4,872,059			—			18,068,900
Less accumulated depletion and amortization	—			(4,342,675		)	(525,007		)	—			(4,867,682		)
	—			8,854,166			4,347,052			—			13,201,218
Other property and equipment	—			553,150			115,999			—			669,149
Less accumulated depreciation	—			(135,830		)	(8,452		)	—			(144,282		)
	—			417,320			107,547			—			524,867
Derivative instruments	—			848,097			—			—			848,097
Notes receivable – affiliates	130,500			—			—			(130,500		)	—
Advance to affiliate	—			—			293,627			(293,627		)	—
Investments in consolidated subsidiaries	8,562,608			—			—			(8,562,608		)	—
Other noncurrent assets, net	116,637			11,816			14,284			—			142,737
	8,809,745			859,913			307,911			(8,986,735		)	990,834
Total noncurrent assets	8,809,745			10,131,399			4,762,510			(8,986,735		)	14,716,919
Total assets	$	12,838,691		$	11,646,240		$	4,967,408		$	(13,028,830	)	$	16,423,509
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	3,784		$	581,880		$	229,145		$	—		$	814,809
Accounts payable – affiliates	—			4,028,890			13,205			(4,042,095		)	—
Advance from affiliate	—			293,627			—			(293,627		)	—
Derivative instruments	—			—			—			—			—
Other accrued liabilities	89,507			59,142			19,087			—			167,736
Total current liabilities	93,291			4,963,539			261,437			(4,335,722		)	982,545
Noncurrent liabilities:
Credit facilities	1,795,000			—			1,173,175			—			2,968,175
Term loan	500,000			—			—			—			500,000
Senior notes, net	5,913,857			—			913,777			—			6,827,634
Notes payable – affiliates	—			130,500			—			(130,500		)	—
Derivative instruments	—			684			—			—			684
Other noncurrent liabilities	—			400,851			200,015			—			600,866
Total noncurrent liabilities	8,208,857			532,035			2,286,967			(130,500		)	10,897,359
Unitholders’ capital:
Units issued and outstanding	5,388,749			4,831,339			2,416,381			(7,240,658		)	5,395,811
Accumulated income (deficit)	(852,206		)	1,319,327			2,623			(1,321,950		)	(852,206		)
	4,536,543			6,150,666			2,419,004			(8,562,608		)	4,543,605
Total liabilities and unitholders’ capital	$	12,838,691		$	11,646,240		$	4,967,408		$	(13,028,830	)	$	16,423,509
Condensed Consolidating Statements of Operations	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Three Months Ended March 31, 2015
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	293,983		$	156,586		$	—		$	450,569
	Gains on oil and natural gas derivatives	—			421,514			3,267			—			424,781
	Marketing revenues	—			26,212			7,532			—			33,744
	Other revenues	—			5,557			1,896			—			7,453
		—			747,266			169,281			—			916,547
	Expenses:
	Lease operating expenses	—			105,832			67,189			—			173,021
	Transportation expenses	—			40,934			12,606			—			53,540
	Marketing expenses	—			23,196			5,645			—			28,841
	General and administrative expenses	—			57,781			21,187			—			78,968
	Exploration costs	—			396			—			—			396
	Depreciation, depletion and amortization	—			140,699			72,979			1,336			215,014
	Impairment of long-lived assets	—			325,417			272,000			(64,800		)	532,617
	Taxes, other than income taxes	2			30,711			23,332			—			54,045
	Gains on sale of assets and other, net	—			(7,814		)	(4,473		)	—			(12,287		)
		2			717,152			470,465			(63,464		)	1,124,155
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(123,386		)	1,706			(21,421		)	—			(143,101		)
	Interest expense – affiliates	—			(2,382		)	—			2,382			—
	Interest income – affiliates	2,382			—			—			(2,382		)	—
	Gain on extinguishment of debt	6,635			—			—			—			6,635
	Equity in losses from consolidated subsidiaries	(222,811		)	—			—			222,811			—
	Other, net	(1,978		)	(65		)	(170		)	—			(2,213		)
		(339,158		)	(741		)	(21,591		)	222,811			(138,679		)
	Income (loss) before income taxes	(339,160		)	29,373			(322,775		)	286,275			(346,287		)
	Income tax benefit	—			(7,077		)	(50		)	—			(7,127		)
	Net income (loss)	$	(339,160	)	$	36,450		$	(322,725	)	$	286,275		$	(339,160	)
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Three Months Ended March 31, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	605,761		$	333,116		$	—		$	938,877
	Gains (losses) on oil and natural gas derivatives	—			(244,958		)	3,465			—			(241,493		)
	Marketing revenues	—			15,731			14,815			—			30,546
	Other revenues	—			5,673			(16		)	—			5,657
		—			382,207			351,380			—			733,587
	Expenses:
	Lease operating expenses	—			104,002			90,031			—			194,033
	Transportation expenses	—			37,637			7,993			—			45,630
	Marketing expenses	—			10,091			10,981			—			21,072
	General and administrative expenses	—			35,737			43,491			—			79,228
	Exploration costs	—			1,091			—			—			1,091
	Depreciation, depletion and amortization	—			199,170			68,631			—			267,801
	Taxes, other than income taxes	—			42,684			23,029			—			65,713
	(Gains) losses on sale of assets and other, net	—			(781		)	3,367			—			2,586
		—			429,631			247,523			—			677,154
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(109,650		)	(162		)	(24,001		)	—			(133,813		)
	Interest expense – affiliates	—			(1,550		)	—			1,550			—
	Interest income – affiliates	1,550			—			—			(1,550		)	—
	Equity in earnings from consolidated subsidiaries	24,893			—			—			(24,893		)	—
	Other, net	(2,130		)	16			(189		)	—			(2,303		)
		(85,337		)	(1,696		)	(24,190		)	(24,893		)	(136,116		)
	Income (loss) before income taxes	(85,337		)	(49,120		)	79,667			(24,893		)	(79,683		)
	Income tax expense (benefit)	—			5,685			(31		)	—			5,654
	Net income (loss)	$	(85,337	)	$	(54,805	)	$	79,698		$	(24,893	)	$	(85,337	)
Condensed Consolidating Statements of Cash Flows	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Three Months Ended March 31, 2015
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from operating activities:
	Net income (loss)	$	(339,160	)	$	36,450		$	(322,725	)	$	286,275		$	(339,160	)
	Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
	Depreciation, depletion and amortization	—			140,699			72,979			1,336			215,014
	Impairment of long-lived assets	—			325,417			272,000			(64,800		)	532,617
	Unit-based compensation expenses	—			20,510			—			—			20,510
	Gain on extinguishment of debt	(6,635		)	—			—			—			(6,635		)
	Amortization and write-off of deferred financing fees	6,453			—			259			—			6,712
	Gains on sale of assets and other, net	—			(5,243		)	(1,857		)	—			(7,100		)
	Equity in losses from consolidated subsidiaries	222,811			—			—			(222,811		)	—
	Deferred income taxes	—			(7,108		)	(50		)	—			(7,158		)
	Derivatives activities:
	Total gains	—			(421,514		)	(2,341		)	—			(423,855		)
	Cash settlements	—			254,569			27,513			—			282,082
	Changes in assets and liabilities:
	Decrease in accounts receivable – trade, net	21,921			96,917			16,392			—			135,230
	(Increase) decrease in accounts receivable – affiliates	17,082			(19,856		)	—			2,774			—
	Increase in other assets	—			(8,521		)	(3,878		)	—			(12,399		)
	Decrease in accounts payable and accrued expenses	(290		)	(3,844		)	(25,734		)	—			(29,868		)
	Increase (decrease) in accounts payable and accrued expenses – affiliates	—			(17,082		)	19,856			(2,774		)	—
	Increase (decrease) in other liabilities	42,695			(24,057		)	(9,925		)	—			8,713
	Net cash provided by (used in) operating activities	(35,123		)	367,337			42,489			—			374,703
	Cash flow from investing activities:
	Acquisition of oil and natural gas properties and joint-venture funding	—			—			—			—			—
	Development of oil and natural gas properties	—			(263,209		)	(1,609		)	—			(264,818		)
	Purchases of other property and equipment	—			(11,309		)	(1,092		)	—			(12,401		)
	Investment in affiliates	43,778			—			—			(43,778		)	—
	Change in notes receivable with affiliate	(16,400		)	—			—			16,400			—
	Proceeds from sale of properties and equipment and other	(1,121		)	24,808			3,813			—			27,500
	Net cash provided by (used in) investing activities	26,257			(249,710		)	1,112			(27,378		)	(249,719		)
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from financing activities:
	Proceeds from sale of units	15,900			—			—			—			15,900
	Proceeds from borrowings	395,000			—			—			—			395,000
	Repayments of debt	(280,287		)	—			—			—			(280,287		)
	Distributions to unitholders	(104,815		)	—			—			—			(104,815		)
	Financing fees and offering costs	(453		)	—			—			—			(453		)
	Change in notes payable with affiliate	—			16,400			—			(16,400		)	—
	Distribution to affiliate	—			—			(43,778		)	43,778			—
	Excess tax benefit from unit-based compensation	(8,867		)	—			—			—			(8,867		)
	Other	(3,786		)	(91,188		)	15			—			(94,959		)
	Net cash provided by (used in) financing activities	12,692			(74,788		)	(43,763		)	27,378			(78,481		)
	Net increase (decrease) in cash and cash equivalents	3,826			42,839			(162		)	—			46,503
	Cash and cash equivalents:
	Beginning	38			185			1,586			—			1,809
	Ending	$	3,864		$	43,024		$	1,424		$	—		$	48,312
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Three Months Ended March 31, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from operating activities:
	Net income (loss)	$	(85,337	)	$	(54,805	)	$	79,698		$	(24,893	)	$	(85,337	)
	Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
	Depreciation, depletion and amortization	—			199,170			68,631			—			267,801
	Unit-based compensation expenses	—			21,500			—			—			21,500
	Amortization and write-off of deferred financing fees	5,791			—			(3,478		)	—			2,313
Losses on sale of assets and other, net	—			1,327			—			—			1,327
Equity in earnings from consolidated subsidiaries	(24,893		)	—			—			24,893			—
Deferred income taxes	—			5,615			(31		)	—			5,584
Derivatives activities:
Total (gains) losses	—			244,958			(3,465		)	—			241,493
Cash settlements	—			(11,856		)	(2,655		)	—			(14,511		)
Changes in assets and liabilities:
Increase in accounts receivable – trade, net	—			(18,964		)	(15,373		)	—			(34,337		)
Decrease in accounts receivable – affiliates	10,513			16,950			—			(27,463		)	—
Increase in other assets	—			(3,136		)	(1,040		)	—			(4,176		)
Increase (decrease) in accounts payable and accrued expenses	30			20,252			(4,177		)	—			16,105
Decrease in accounts payable and accrued expenses – affiliates	—			(10,513		)	(16,950		)	27,463			—
Increase (decrease) in other liabilities	53,698			(30,648		)	(6,330		)	—			16,720
Net cash provided by (used in) operating activities	(40,198		)	379,850			94,830			—			434,482
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(25,345		)	—			—			(25,345		)
Development of oil and natural gas properties	—			(260,093		)	(134,750		)	—			(394,843		)
Purchases of other property and equipment	—			(8,318		)	(1,833		)	—			(10,151		)
Change in notes receivable with affiliate	(9,200		)	—			—			9,200			—
Proceeds from sale of properties and equipment and other	(11,230		)	544			—			—			(10,686		)
Net cash used in investing activities	(20,430		)	(293,212		)	(136,583		)	9,200			(441,025		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from borrowings	540,000			—			—			—			540,000
Repayments of debt	(240,000		)	—			(1,188		)	—			(241,188		)
Distributions to unitholders	(240,073		)	—			—			—			(240,073		)
Financing fees and offering costs	(81		)	—			(2,581		)	—			(2,662		)
Change in notes payable with affiliate	—			9,200			—			(9,200		)	—
Excess tax benefit from unit-based compensation	—			1,457			—			—			1,457
Other	763			(35,611		)	—			—			(34,848		)
Net cash provided by (used in) financing activities	60,609			(24,954		)	(3,769		)	(9,200		)	22,686
Net increase (decrease) in cash and cash equivalents	(19		)	61,684			(45,522		)	—			16,143
Cash and cash equivalents:
Beginning	52			1,078			51,041			—			52,171
Ending	$	33		$	62,762		$	5,519		$	—		$	68,314

Acquisitions_and_JointVenture_2

Acquisitions and Joint-Venture Funding (Details) (USD $)	0 Months Ended	3 Months Ended
	Apr. 03, 2012	Mar. 31, 2015	Jun. 27, 2014
Business Acquisition Anadarko [Member]
Business Acquisition [Line Items]
Future Funding Commitment Of Joint Venture Consideration Transferred		$25,000,000
Future Funding Of Joint Venture Agreement	400,000,000
Business Acquisition Devon [Member] [Member]
Business Acquisition [Line Items]
Business acquisition interim financing			$2,300,000,000

Acquisitions_and_JointVenture_3

Acquisitions and Joint-Venture Funding Pro Forma Financial Information (Details) (Business Acquisition Devon [Member] [Member], USD $)	3 Months Ended
	Mar. 31, 2014	Jun. 27, 2014
Business Acquisition Devon [Member] [Member]
Business Acquisition, Pro Forma Information [Abstract]
Total revenues and other	$879,115,000
Total operating expenses	765,491,000
Net loss	-62,305,000
Net loss per unit:
Basic	($0.20)
Diluted	($0.20)
Property, Plant and Equipment, Useful Life	10 years
Business acquisition interim financing		$2,300,000,000

Unitholders_Capital_Details

Unitholders' Capital (Details) (USD $)	3 Months Ended		1 Months Ended			3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Jun. 30, 2015	31-May-15	Apr. 30, 2015	Jun. 30, 2015
Subsequent Event [Line Items]
Per unit cash dividend declared (in usd per unit)	$0.31	$0.73
Distributions to unitholders	$104,815	$240,073
Dividend Declared [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Per unit cash dividend declared (in usd per unit)			$0.10	$0.10	$0.10	$0.31
Dividend Paid [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Distributions to unitholders					$35,000

Unitholders_Capital_AtTheMarke

Unitholders' Capital At-The-Market Offering (Details) (USD $)	3 Months Ended
	Mar. 31, 2015
Debt Instrument [Line Items]
Equity Offering Program Maximum Value	$500,000,000
Sale of units (in units)	1,328,192
EquityOfferingProgramPricePerUnit	$11.97
EquityOfferingProgramNetProceeds	16,000,000
Equity Distribution Agreement Commissions And Professional Service Expenses	159,000
Equity distribution agreement professional service expenses	435,000
EquityOfferingProgramRemainingBalance	$484,000,000
Linn Energy, LLC [Member] | Senior Notes Due 2020 | Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.63%

Oil_and_Natural_Gas_Properties2

Oil and Natural Gas Properties (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	$532,617	$0
Proved properties:
Leasehold acquisition	13,368,818		13,362,642
Development	3,012,467		2,830,841
Unproved properties	1,865,612		1,875,417
Oil and natural gas properties (successful efforts method)	18,246,897		18,068,900
Less accumulated depletion and amortization	-5,592,674		-4,867,682
Oil and natural gas properties, successful efforts method, net	12,654,223		13,201,218
Shallow Texas Panhandle Brown Dolomite formation [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	278,000
California operating region [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	207,000
TexLa operating region [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	33,000
South Texas operating region [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	9,000
Mid-Continent operating region [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	$6,000

UnitBased_Compensation_Narrati

Unit-Based Compensation (Narrative) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred Compensation Share-based Arrangements, Liability, Classified, Noncurrent	$266,000
Unit-based compensation expense	20,510,000	21,500,000
Aggregate fair value of grants issued to employees	42,000,000
Vesting period of grants issued to employees	3 years
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted to employees	3,468,245
Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted to employees	697,120
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted to employees	567,320
General and administrative expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit-based compensation expense	16,633,000	18,223,000
General and administrative expenses | Liability Classified Performance Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit-based compensation expense	$266,000

UnitBased_Compensation_Compens

Unit-Based Compensation (Compensation Expenses) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	$20,510	$21,500
Income tax benefit	7,579	7,944
General and administrative expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	16,633	18,223
Lease operating expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	$3,877	$3,277

Debt_Details

Debt (Details) (USD $)	3 Months Ended
	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014		Apr. 30, 2012
Debt Instrument [Line Items]
Less current maturities	$0			$0
Term loan	500,000,000			500,000,000
Gain on extinguishment of debt	6,635,000		0
Percent of future net income allowable to increase Berry's restricted payments basket	50.00%
Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	1,200,000,000
Debt Instrument, Interest Rate at Period End (in hundredths)	2.68%			2.67%
Line of Credit Facility, Maximum Borrowing Capacity	1,400,000,000
Line of Credit Facility, Remaining Borrowing Capacity	1,000,000
The percentage of properties that the company is required to maintain mortgages on (in hundredths)	80.00%
Berry [Member] | Line of Credit | Credit Facility | Minimum
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.38%
Berry [Member] | Line of Credit | Credit Facility | Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.50%
Berry [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
Berry [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.50%
Berry [Member] | Line of Credit | Credit Facility | ABR | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.50%
Berry [Member] | Line of Credit | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.75%
Linn Energy, LLC [Member] | Line of Credit
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	4,000,000,000					4,000,000,000
Line of Credit Facility, Maximum Borrowing Capacity	4,500,000,000
Line of Credit Facility, Remaining Borrowing Capacity	2,000,000,000
Letters of Credit Outstanding, Amount	6,000,000
Line Of Credit Facility Collateral Coverage Ratio	2.5
Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument, Interest Rate at Period End (in hundredths)	1.93%			1.92%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | Minimum
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.38%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | Maximum
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.50%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.50%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | ABR | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.50%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.63%
Extinguishment of debt	79,000,000
Linn Energy, LLC [Member] | Loans Payable [Member]
Debt Instrument [Line Items]
Term loan	$500,000,000	[1]		$500,000,000	[1]
Debt Instrument, Interest Rate at Period End (in hundredths)	2.68%			2.66%
The percentage of properties that the company is required to maintain mortgages on (in hundredths)	80.00%
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility
Debt Instrument [Line Items]
The percentage of properties that the company is required to maintain mortgages on (in hundredths)	80.00%
Line Of Credit Facility Collateral Coverage Ratio	2.5
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.50%
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.50%
[1]	Variable interest rates of 2.68% and 2.66% at March 31, 2015, and December 31, 2014, respectively.

Debt_Schedule_of_Long_Term_Deb

Debt Schedule of Long Term Debt (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Credit facilities	$3,148,175		$2,968,175
Term loan	500,000		500,000
Senior notes, net	6,750,313		6,827,634
Total debt, net	10,398,488		10,295,809
Less current maturities	0		0
Total long-term debt, net	10,398,488		10,295,809
Senior Notes [Member]
Debt Instrument [Line Items]
Net unamortized discounts and premiums	-19,620		-21,499
Linn Energy, LLC [Member] | Line of Credit
Debt Instrument [Line Items]
Credit facilities	1,975,000	[1]	1,795,000	[1]
Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End	1.93%		1.92%
Linn Energy, LLC [Member] | Loans Payable [Member]
Debt Instrument [Line Items]
Term loan	500,000	[2]	500,000	[2]
Debt Instrument Interest Rate Period End	2.68%		2.66%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due May 2019
Debt Instrument [Line Items]
Senior notes, net	1,200,000		1,200,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019
Debt Instrument [Line Items]
Senior notes, net	1,800,000		1,800,000
Debt Instrument, Interest Rate, Stated Percentage	6.25%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due 2020
Debt Instrument [Line Items]
Senior notes, net	1,220,800		1,300,000
Debt Instrument, Interest Rate, Stated Percentage	8.63%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due September 2021 [Member]
Debt Instrument [Line Items]
Senior notes, net	650,000		650,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due February 2021 [Member]
Debt Instrument [Line Items]
Senior notes, net	1,000,000		1,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.75%
Berry [Member] | Line of Credit
Debt Instrument [Line Items]
Credit facilities	1,173,175	[3]	1,173,175	[3]
Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End	2.68%		2.67%
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2020
Debt Instrument [Line Items]
Senior notes, net	299,970		299,970
Debt Instrument, Interest Rate, Stated Percentage	6.75%
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Senior notes, net	$599,163		$599,163
Debt Instrument, Interest Rate, Stated Percentage	6.38%
[1]	Variable interest rates of 1.93% and 1.92% at March 31, 2015, and December 31, 2014, respectively.
[2]	Variable interest rates of 2.68% and 2.66% at March 31, 2015, and December 31, 2014, respectively.
[3]	Variable interest rates of 2.68% and 2.67% at March 31, 2015, and December 31, 2014, respectively.

Debt_Debt_Fair_Value_Disclosur

Debt Debt Fair Value Disclosure (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Carrying Value
Credit facilities	$3,148,175	$2,968,175
Term loan	500,000	500,000
Senior notes, net	6,750,313	6,827,634
Total debt, net	10,398,488	10,295,809
Fair Value
Credit facilities	3,148,175	2,968,175
Term loan	500,000	500,000
Senior notes, net	5,454,065	5,703,649
Total debt, net	$9,102,240	$9,171,824

Derivatives_Commodity_Derivati

Derivatives (Commodity Derivatives) (Details)	Mar. 31, 2015
	MMMBTU
2015 | Natural Gas Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	88,935
Average Price (in usd per energy unit)	5.19
2015 | Natural Gas Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	54,137
Average Price (in usd per energy unit)	5
2015 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	9,426	[1]
Average Price (in usd per energy unit)	93.33	[1]
2015 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	2,581
Average Price (in usd per energy unit)	90
2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	825
2015 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	65,670	[2],[3]
Hedged Differential (in usd per energy unit)	-0.33	[2],[3]
2015 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	43,707	[2],[3]
Hedged Differential (in usd per energy unit)	-0.23	[2],[3]
2015 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	7,040	[2],[3]
Hedged Differential (in usd per energy unit)	0.06	[2],[3]
2015 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	19,351	[2],[3]
Hedged Differential (in usd per energy unit)	-0.03	[2],[3]
2015 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	3,823	[2],[3]
Hedged Differential (in usd per energy unit)	-0.21	[2],[3]
2015 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	22,050	[3],[4]
Hedged Differential (in usd per energy unit)	-0.03	[3],[4]
2015 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	5,463	[5]
Hedged Differential (in usd per energy unit)	0.24	[5]
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
Average Price (in usd per energy unit)	5
2016 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	11,465	[1]
Average Price (in usd per energy unit)	90.56	[1]
2016 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	3,271
Average Price (in usd per energy unit)	90
2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0
2016 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	59,954	[2],[3]
Hedged Differential (in usd per energy unit)	-0.32	[2],[3]
2016 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	65,794	[2],[3]
Hedged Differential (in usd per energy unit)	-0.24	[2],[3]
2016 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	7,768	[2],[3]
Hedged Differential (in usd per energy unit)	0.05	[2],[3]
2016 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	34,364	[2],[3]
Hedged Differential (in usd per energy unit)	-0.02	[2],[3]
2016 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	4,219	[2],[3]
Hedged Differential (in usd per energy unit)	-0.2	[2],[3]
2016 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	32,940	[3],[4]
Hedged Differential (in usd per energy unit)	-0.03	[3],[4]
2016 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	7,446	[5]
Hedged Differential (in usd per energy unit)	0.25	[5]
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
Average Price (in usd per energy unit)	4.88
2017 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	4,755	[1]
Average Price (in usd per energy unit)	89.02	[1]
2017 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	384
Average Price (in usd per energy unit)	90
2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0
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	[2],[3]
Hedged Differential (in usd per energy unit)	-0.33	[2],[3]
2017 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	38,880	[2],[3]
Hedged Differential (in usd per energy unit)	-0.19	[2],[3]
2017 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	7,437	[2],[3]
Hedged Differential (in usd per energy unit)	0.05	[2],[3]
2017 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	36,730	[2],[3]
Hedged Differential (in usd per energy unit)	-0.02	[2],[3]
2017 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	4,819	[2],[3]
Hedged Differential (in usd per energy unit)	-0.2	[2],[3]
2017 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[3],[4]
Hedged Differential (in usd per energy unit)	0	[3],[4]
2017 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	6,486	[5]
Hedged Differential (in usd per energy unit)	0.25	[5]
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
Average Price (in usd per energy unit)	0
2018 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[1]
Average Price (in usd per energy unit)	0	[1]
2018 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	0
Average Price (in usd per energy unit)	0
2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0
2018 | 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
2018 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	16,425	[2],[3]
Hedged Differential (in usd per energy unit)	-0.33	[2],[3]
2018 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	10,804	[2],[3]
Hedged Differential (in usd per energy unit)	-0.19	[2],[3]
2018 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	2,044	[2],[3]
Hedged Differential (in usd per energy unit)	0.05	[2],[3]
2018 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	986	[2],[3]
Hedged Differential (in usd per energy unit)	-0.08	[2],[3]
2018 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	1,314	[2],[3]
Hedged Differential (in usd per energy unit)	-0.2	[2],[3]
2018 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[3],[4]
Hedged Differential (in usd per energy unit)	0	[3],[4]
2018 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[5]
Hedged Differential (in usd per energy unit)	0	[5]
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] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	70
Derivative, Cap Price	101.62
Short [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Derivative, Cap Price	0
Short [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Derivative, Cap Price	0
Short [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Derivative, Cap Price	0
Long [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	90
Long [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Long [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
Long [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]
Derivative [Line Items]
Derivative, Floor Price	0
[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, at counterparty election on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
[2]	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.
[3]	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
[4]	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.
[5]	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 $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$2,106,710
Assets:
Commodity derivatives	2,106,710	2,014,815
Liabilities:
Commodity derivatives	$40,397	$90,260

Derivatives_Gains_Losses_On_De

Derivatives (Gains (Losses) On Derivatives) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
	MBbls	MBbls
	MMMBTU	MMMBTU
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) on oil and natural gas derivatives	$423,855	($241,493)
Volume Of Natural Gas Production On Settled Derivatives	46,823	43,651
Cash settlements	282,082	-14,511
Average Contract Price On Natural Gas Settled Derivatives Per Unit	5.12	5.14
Volume Of Oil On Settled Derivatives	3,975	6,161
Average Contract Price On Oil Settled Derivatives Per Unit	94.29	92.39
Gains (losses) on oil and natural gas derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) on oil and natural gas derivatives	424,781	-241,493
Lease operating expenses
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) on oil and natural gas derivatives	($1,000)

Fair_Value_Measurements_on_a_R2

Fair Value Measurements on a Recurring Basis (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Assets:
Commodity derivatives	$2,106,710		$2,014,815
Commodity derivatives	-37,499	[1]	-89,576	[1]
Commodity derivatives	2,069,211		1,925,239
Liabilities:
Commodity derivatives	40,397		90,260
Commodity derivatives	-37,499	[1]	-89,576	[1]
Commodity derivatives	$2,898		$684
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
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	5.60%
Asset retirement obligations rollforward
Asset retirement obligations at December 31, 2014	$497,570
Liabilities added from drilling	1,390
Current year accretion expense	7,399
Settlements	-1,783
Revision of estimates	-1,345
Asset retirement obligations at March 31, 2015	$503,231

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Payments for Legal Settlements	$0	$0

Earnings_Per_Unit_Details

Earnings Per Unit (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share [Abstract]
Net loss	($339,160)	($85,337)
Allocated to participating securities	-1,781	-2,199
Net income (loss) available to common unitholders, basic	($340,941)	($87,536)
Earnings per share reconciliation
Basic loss per unit (in usd per unit)	($1.03)	($0.27)
Diluted loss per unit (in usd per unit)	($1.03)	($0.27)
Weighted average units outstanding
Basic weighted average units outstanding	330,642,000	328,329,000
Dilutive effect of unit equivalents	0	0
Diluted weighted average units outstanding	330,642,000	328,329,000
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)	5,000,000	6,000,000

Supplemental_Disclosures_to_th2

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Balance Sheets) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]
Restricted cash	$6,000,000	$6,000,000
Net Outstanding Checks	0	95,000,000
Other accrued liabilities
Accrued interest	143,088,000	105,310,000
Accrued compensation	22,854,000	44,875,000
Asset retirement obligations	16,187,000	16,187,000
Other	2,301,000	1,364,000
Other accrued liabilities	$184,430,000	$167,736,000

Supplemental_Disclosures_to_th3

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Cash Flows) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Cash payments for interest, net of amounts capitalized	$98,541,000	$77,512,000
Cash payments for income taxes	57,000	0
Noncash investing activities:
Accrued capital expenditures	161,247,000	338,323,000
Joint-venture funding		25,000,000
Net Outstanding Checks	$0		$95,000,000

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Related Party Transaction [Line Items]
General and administrative expenses	$78,968	$79,228
Distributions to unitholders	104,815	240,073
LinnCo [Member]
Related Party Transaction [Line Items]
Ownership percentage	39.00%
General and administrative expenses	1,400	734
Related party transaction, amounts of transaction	491	470
Director [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction	3,000	4,000
FY 2014 [Member] | LinnCo [Member]
Related Party Transaction [Line Items]
General and administrative expenses paid on behalf of LinnCo	1,100	83
FY 2013 [Member] | LinnCo [Member]
Related Party Transaction [Line Items]
General and administrative expenses paid on behalf of LinnCo		11,000
Dividend Paid [Member] | LinnCo [Member]
Related Party Transaction [Line Items]
Distributions to unitholders	$40,000	$93,000

Subsidiary_Guarantors_Condense

Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$48,312	$1,809	$68,314	$52,171
Accounts receivable – trade, net	340,838	471,684
Accounts receivable – affiliates	0	0
Derivative instruments	1,119,332	1,077,142
Other current assets	147,969	155,955
Total current assets	1,656,451	1,706,590
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	18,246,897	18,068,900
Less accumulated depletion and amortization	-5,592,674	-4,867,682
Oil and natural gas properties, successful efforts method, net	12,654,223	13,201,218
Other property and equipment	682,772	669,149
Less accumulated depreciation	-158,409	-144,282
Other property and equipment, net	524,363	524,867
Derivative instruments	949,879	848,097
Notes receivable – affiliates	0	0
Advance to affiliate	0	0
Investments in consolidated subsidiaries	0	0
Other noncurrent assets	135,259	142,737
Noncurrent assets, excluding property, total	1,085,138	990,834
Total noncurrent assets	14,263,724	14,716,919
Total assets	15,920,175	16,423,509
Current liabilities:
Accounts payable and accrued expenses	608,926	814,809
Accounts payable – affiliates	0	0
Advance from affiliate	0	0
Derivative instruments	899	0
Other accrued liabilities	184,430	167,736
Total current liabilities	794,255	982,545
Noncurrent liabilities:
Credit facilities	3,148,175	2,968,175
Term loan	500,000	500,000
Senior notes, net	6,750,313	6,827,634
Notes payable – affiliates	0	0
Derivative instruments	1,999	684
Other noncurrent liabilities	598,930	600,866
Total noncurrent liabilities	10,999,417	10,897,359
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	5,317,869	5,395,811
Unitholders’ capital:
Accumulated deficit	-1,191,366	-852,206
Total unitholders' capital	4,126,503	4,543,605
Total liabilities and unitholders’ capital	15,920,175	16,423,509
Reportable Legal Entities [Member] | LINN Energy, LLC
Current assets:
Cash and cash equivalents	3,864	38	33	52
Accounts receivable – trade, net	0	0
Accounts receivable – affiliates	4,011,808	4,028,890
Derivative instruments	0	0
Other current assets	18	18
Total current assets	4,015,690	4,028,946
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	146,900	130,500
Advance to affiliate	0	0
Investments in consolidated subsidiaries	8,296,020	8,562,608
Other noncurrent assets	110,256	116,637
Noncurrent assets, excluding property, total	8,553,176	8,809,745
Total noncurrent assets	8,553,176	8,809,745
Total assets	12,568,866	12,838,691
Current liabilities:
Accounts payable and accrued expenses	5,150	3,784
Accounts payable – affiliates	0	0
Advance from affiliate	0	0
Derivative instruments	0	0
Other accrued liabilities	132,202	89,507
Total current liabilities	137,352	93,291
Noncurrent liabilities:
Credit facilities	1,975,000	1,795,000
Term loan	500,000	500,000
Senior notes, net	5,836,998	5,913,857
Notes payable – affiliates	0	0
Derivative instruments	0	0
Other noncurrent liabilities	0	0
Total noncurrent liabilities	8,311,998	8,208,857
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	5,310,882	5,388,749
Unitholders’ capital:
Accumulated deficit	-1,191,366	-852,206
Total unitholders' capital	4,119,516	4,536,543
Total liabilities and unitholders’ capital	12,568,866	12,838,691
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	43,024	185	62,762	1,078
Accounts receivable – trade, net	251,957	371,325
Accounts receivable – affiliates	33,061	13,205
Derivative instruments	1,099,777	1,033,448
Other current assets	94,722	96,678
Total current assets	1,522,541	1,514,841
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	13,318,736	13,196,841
Less accumulated depletion and amortization	-4,790,872	-4,342,675
Oil and natural gas properties, successful efforts method, net	8,527,864	8,854,166
Other property and equipment	564,928	553,150
Less accumulated depreciation	-147,307	-135,830
Other property and equipment, net	417,621	417,320
Derivative instruments	949,798	848,097
Notes receivable – affiliates	0	0
Advance to affiliate	0	0
Investments in consolidated subsidiaries	0	0
Other noncurrent assets	11,660	11,816
Noncurrent assets, excluding property, total	961,458	859,913
Total noncurrent assets	9,906,943	10,131,399
Total assets	11,429,484	11,646,240
Current liabilities:
Accounts payable and accrued expenses	422,042	581,880
Accounts payable – affiliates	4,011,808	4,028,890
Advance from affiliate	220,571	293,627
Derivative instruments	0	0
Other accrued liabilities	37,872	59,142
Total current liabilities	4,692,293	4,963,539
Noncurrent liabilities:
Credit facilities	0	0
Term loan	0	0
Senior notes, net	0	0
Notes payable – affiliates	146,900	130,500
Derivative instruments	1,770	684
Other noncurrent liabilities	401,479	400,851
Total noncurrent liabilities	550,149	532,035
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	4,831,265	4,831,339
Unitholders’ capital:
Accumulated deficit	1,355,777	1,319,327
Total unitholders' capital	6,187,042	6,150,666
Total liabilities and unitholders’ capital	11,429,484	11,646,240
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Current assets:
Cash and cash equivalents	1,424	1,586	5,519	51,041
Accounts receivable – trade, net	88,881	100,359
Accounts receivable – affiliates	0	0
Derivative instruments	19,555	43,694
Other current assets	53,229	59,259
Total current assets	163,089	204,898
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	4,928,161	4,872,059
Less accumulated depletion and amortization	-865,266	-525,007
Oil and natural gas properties, successful efforts method, net	4,062,895	4,347,052
Other property and equipment	117,844	115,999
Less accumulated depreciation	-11,102	-8,452
Other property and equipment, net	106,742	107,547
Derivative instruments	81	0
Notes receivable – affiliates	0	0
Advance to affiliate	220,571	293,627
Investments in consolidated subsidiaries	0	0
Other noncurrent assets	13,343	14,284
Noncurrent assets, excluding property, total	233,995	307,911
Total noncurrent assets	4,403,632	4,762,510
Total assets	4,566,721	4,967,408
Current liabilities:
Accounts payable and accrued expenses	181,734	229,145
Accounts payable – affiliates	33,061	13,205
Advance from affiliate	0	0
Derivative instruments	899	0
Other accrued liabilities	14,356	19,087
Total current liabilities	230,050	261,437
Noncurrent liabilities:
Credit facilities	1,173,175	1,173,175
Term loan	0	0
Senior notes, net	913,315	913,777
Notes payable – affiliates	0	0
Derivative instruments	229	0
Other noncurrent liabilities	197,451	200,015
Total noncurrent liabilities	2,284,170	2,286,967
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	2,372,603	2,416,381
Unitholders’ capital:
Accumulated deficit	-320,102	2,623
Total unitholders' capital	2,052,501	2,419,004
Total liabilities and unitholders’ capital	4,566,721	4,967,408
Eliminations
Current assets:
Cash and cash equivalents	0	0	0	0
Accounts receivable – trade, net	0	0
Accounts receivable – affiliates	-4,044,869	-4,042,095
Derivative instruments	0	0
Other current assets	0	0
Total current assets	-4,044,869	-4,042,095
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	0	0
Less accumulated depletion and amortization	63,464	0
Oil and natural gas properties, successful efforts method, net	63,464	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	-146,900	-130,500
Advance to affiliate	-220,571	-293,627
Investments in consolidated subsidiaries	-8,296,020	-8,562,608
Other noncurrent assets	0	0
Noncurrent assets, excluding property, total	-8,663,491	-8,986,735
Total noncurrent assets	-8,600,027	-8,986,735
Total assets	-12,644,896	-13,028,830
Current liabilities:
Accounts payable and accrued expenses	0	0
Accounts payable – affiliates	-4,044,869	-4,042,095
Advance from affiliate	-220,571	-293,627
Derivative instruments	0	0
Other accrued liabilities	0	0
Total current liabilities	-4,265,440	-4,335,722
Noncurrent liabilities:
Credit facilities	0	0
Term loan	0	0
Senior notes, net	0	0
Notes payable – affiliates	-146,900	-130,500
Derivative instruments	0	0
Other noncurrent liabilities	0	0
Total noncurrent liabilities	-146,900	-130,500
336,887,489 units and 331,974,913 units issued and outstanding at March 31, 2015, and December 31, 2014, respectively	-7,196,881	-7,240,658
Unitholders’ capital:
Accumulated deficit	-1,035,675	-1,321,950
Total unitholders' capital	-8,232,556	-8,562,608
Total liabilities and unitholders’ capital	($12,644,896)	($13,028,830)

Subsidiary_Guarantors_Condense1

Subsidiary Guarantors Condensed Consolidating Statements of Operations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues and other:
Oil, natural gas and natural gas liquids sales	$450,569	$938,877
Gains (losses) on oil and natural gas derivatives	424,781	-241,493
Marketing revenues	33,744	30,546
Other revenues	7,453	5,657
Total revenues	916,547	733,587
Expenses:
Lease operating expenses	173,021	194,033
Transportation expenses	53,540	45,630
Marketing expenses	28,841	21,072
General and administrative expenses	78,968	79,228
Exploration costs	396	1,091
Depreciation, depletion and amortization	215,014	267,801
Impairment of long-lived assets	532,617	0
Taxes, other than income taxes	54,045	65,713
(Gains) losses on sale of assets and other, net	-12,287	2,586
Total expenses	1,124,155	677,154
Other income and (expenses):
Interest expense, net of amounts capitalized	-143,101	-133,813
Interest expense – affiliates	0	0
Interest income – affiliates	0	0
Gain on extinguishment of debt	6,635	0
Equity in earnings from consolidated subsidiaries	0	0
Other, net	-2,213	-2,303
Total other income and (expenses)	-138,679	-136,116
Loss before income taxes	-346,287	-79,683
Income tax expense (benefit)	-7,127	5,654
Net loss	-339,160	-85,337
Reportable Legal Entities [Member] | LINN Energy, LLC
Revenues and other:
Oil, natural gas and natural gas liquids sales	0	0
Gains (losses) on oil and natural gas derivatives	0	0
Marketing revenues	0	0
Other revenues	0	0
Total revenues	0	0
Expenses:
Lease operating expenses	0	0
Transportation expenses	0	0
Marketing expenses	0	0
General and administrative expenses	0	0
Exploration costs	0	0
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0
Taxes, other than income taxes	2	0
(Gains) losses on sale of assets and other, net	0	0
Total expenses	2	0
Other income and (expenses):
Interest expense, net of amounts capitalized	-123,386	-109,650
Interest expense – affiliates	0	0
Interest income – affiliates	2,382	1,550
Gain on extinguishment of debt	6,635
Equity in earnings from consolidated subsidiaries	-222,811	24,893
Other, net	-1,978	-2,130
Total other income and (expenses)	-339,158	-85,337
Loss before income taxes	-339,160	-85,337
Income tax expense (benefit)	0	0
Net loss	-339,160	-85,337
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Revenues and other:
Oil, natural gas and natural gas liquids sales	293,983	605,761
Gains (losses) on oil and natural gas derivatives	421,514	-244,958
Marketing revenues	26,212	15,731
Other revenues	5,557	5,673
Total revenues	747,266	382,207
Expenses:
Lease operating expenses	105,832	104,002
Transportation expenses	40,934	37,637
Marketing expenses	23,196	10,091
General and administrative expenses	57,781	35,737
Exploration costs	396	1,091
Depreciation, depletion and amortization	140,699	199,170
Impairment of long-lived assets	325,417
Taxes, other than income taxes	30,711	42,684
(Gains) losses on sale of assets and other, net	-7,814	-781
Total expenses	717,152	429,631
Other income and (expenses):
Interest expense, net of amounts capitalized	1,706	-162
Interest expense – affiliates	-2,382	-1,550
Interest income – affiliates	0	0
Gain on extinguishment of debt	0
Equity in earnings from consolidated subsidiaries	0	0
Other, net	-65	16
Total other income and (expenses)	-741	-1,696
Loss before income taxes	29,373	-49,120
Income tax expense (benefit)	-7,077	5,685
Net loss	36,450	-54,805
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Revenues and other:
Oil, natural gas and natural gas liquids sales	156,586	333,116
Gains (losses) on oil and natural gas derivatives	3,267	3,465
Marketing revenues	7,532	14,815
Other revenues	1,896	-16
Total revenues	169,281	351,380
Expenses:
Lease operating expenses	67,189	90,031
Transportation expenses	12,606	7,993
Marketing expenses	5,645	10,981
General and administrative expenses	21,187	43,491
Exploration costs	0	0
Depreciation, depletion and amortization	72,979	68,631
Impairment of long-lived assets	272,000
Taxes, other than income taxes	23,332	23,029
(Gains) losses on sale of assets and other, net	-4,473	3,367
Total expenses	470,465	247,523
Other income and (expenses):
Interest expense, net of amounts capitalized	-21,421	-24,001
Interest expense – affiliates	0	0
Interest income – affiliates	0	0
Gain on extinguishment of debt	0
Equity in earnings from consolidated subsidiaries	0	0
Other, net	-170	-189
Total other income and (expenses)	-21,591	-24,190
Loss before income taxes	-322,775	79,667
Income tax expense (benefit)	-50	-31
Net loss	-322,725	79,698
Eliminations
Revenues and other:
Oil, natural gas and natural gas liquids sales	0	0
Gains (losses) on oil and natural gas derivatives	0	0
Marketing revenues	0	0
Other revenues	0	0
Total revenues	0	0
Expenses:
Lease operating expenses	0	0
Transportation expenses	0	0
Marketing expenses	0	0
General and administrative expenses	0	0
Exploration costs	0	0
Depreciation, depletion and amortization	1,336	0
Impairment of long-lived assets	-64,800
Taxes, other than income taxes	0	0
(Gains) losses on sale of assets and other, net	0	0
Total expenses	-63,464	0
Other income and (expenses):
Interest expense, net of amounts capitalized	0	0
Interest expense – affiliates	2,382	1,550
Interest income – affiliates	-2,382	-1,550
Gain on extinguishment of debt	0
Equity in earnings from consolidated subsidiaries	222,811	-24,893
Other, net	0	0
Total other income and (expenses)	222,811	-24,893
Loss before income taxes	286,275	-24,893
Income tax expense (benefit)	0	0
Net loss	$286,275	($24,893)

Subsidiary_Guarantors_Condense2

Subsidiary Guarantors Condensed Consolidating Statements of Cash Flow (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flow from operating activities:
Net loss	($339,160)	($85,337)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	215,014	267,801
Impairment of long-lived assets	532,617	0
Unit-based compensation expenses	20,510	21,500
Gain on extinguishment of debt	-6,635	0
Amortization and write-off of deferred financing fees	6,712	2,313
(Gains) losses on sale of assets and other, net	-7,100	1,327
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	-7,158	5,584
Total (gains) losses	423,855	-241,493
Derivatives activities:
Cash settlements	282,082	-14,511
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	135,230	-34,337
(Increase) decrease in accounts receivable – affiliates	0	0
Increase in other assets	-12,399	-4,176
Increase (decrease) in accounts payable and accrued expenses	-29,868	16,105
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	8,713	16,720
Net cash provided by operating activities	374,703	434,482
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	0	-25,345
Development of oil and natural gas properties	-264,818	-394,843
Purchases of other property and equipment	-12,401	-10,151
Investment in affiliates	0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	27,500	-10,686
Net cash used in investing activities	-249,719	-441,025
Cash flow from financing activities:
Proceeds from sale of units	15,900	0
Proceeds from borrowings	395,000	540,000
Repayments of debt	-280,287	-241,188
Distributions to unitholders	-104,815	-240,073
Financing fees and offering costs	-453	-2,662
Change in notes payable with affiliate	0	0
Distribution to affiliate	0
Excess tax benefit from unit-based compensation	-8,867	1,457
Other	-94,959	-34,848
Net cash provided by (used in) financing activities	-78,481	22,686
Net increase in cash and cash equivalents	46,503	16,143
Cash and cash equivalents:
Beginning	1,809	52,171
Ending	48,312	68,314
Reportable Legal Entities [Member] | LINN Energy, LLC
Cash flow from operating activities:
Net loss	-339,160	-85,337
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0
Unit-based compensation expenses	0	0
Gain on extinguishment of debt	-6,635
Amortization and write-off of deferred financing fees	6,453	5,791
(Gains) losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	222,811	-24,893
Deferred income taxes	0	0
Total (gains) losses	0	0
Derivatives activities:
Cash settlements	0	0
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	21,921	0
(Increase) decrease in accounts receivable – affiliates	17,082	10,513
Increase in other assets	0	0
Increase (decrease) in accounts payable and accrued expenses	-290	30
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	42,695	53,698
Net cash provided by operating activities	-35,123	-40,198
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	43,778
Change in notes receivable with affiliate	-16,400	-9,200
Proceeds from sale of properties and equipment and other	-1,121	-11,230
Net cash used in investing activities	26,257	-20,430
Cash flow from financing activities:
Proceeds from sale of units	15,900
Proceeds from borrowings	395,000	540,000
Repayments of debt	-280,287	-240,000
Distributions to unitholders	-104,815	-240,073
Financing fees and offering costs	-453	-81
Change in notes payable with affiliate	0	0
Distribution to affiliate	0
Excess tax benefit from unit-based compensation	-8,867	0
Other	-3,786	763
Net cash provided by (used in) financing activities	12,692	60,609
Net increase in cash and cash equivalents	3,826	-19
Cash and cash equivalents:
Beginning	38	52
Ending	3,864	33
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Cash flow from operating activities:
Net loss	36,450	-54,805
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	140,699	199,170
Impairment of long-lived assets	325,417
Unit-based compensation expenses	20,510	21,500
Gain on extinguishment of debt	0
Amortization and write-off of deferred financing fees	0	0
(Gains) losses on sale of assets and other, net	-5,243	1,327
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	-7,108	5,615
Total (gains) losses	421,514	-244,958
Derivatives activities:
Cash settlements	254,569	-11,856
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	96,917	-18,964
(Increase) decrease in accounts receivable – affiliates	-19,856	16,950
Increase in other assets	-8,521	-3,136
Increase (decrease) in accounts payable and accrued expenses	-3,844	20,252
Increase (decrease) in accounts payable and accrued expenses – affiliates	-17,082	-10,513
Increase in other liabilities	-24,057	-30,648
Net cash provided by operating activities	367,337	379,850
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	0	-25,345
Development of oil and natural gas properties	-263,209	-260,093
Purchases of other property and equipment	-11,309	-8,318
Investment in affiliates	0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	24,808	544
Net cash used in investing activities	-249,710	-293,212
Cash flow from financing activities:
Proceeds from sale of units	0
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and offering costs	0	0
Change in notes payable with affiliate	16,400	9,200
Distribution to affiliate	0
Excess tax benefit from unit-based compensation	0	1,457
Other	-91,188	-35,611
Net cash provided by (used in) financing activities	-74,788	-24,954
Net increase in cash and cash equivalents	42,839	61,684
Cash and cash equivalents:
Beginning	185	1,078
Ending	43,024	62,762
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Cash flow from operating activities:
Net loss	-322,725	79,698
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	72,979	68,631
Impairment of long-lived assets	272,000
Unit-based compensation expenses	0	0
Gain on extinguishment of debt	0
Amortization and write-off of deferred financing fees	259	-3,478
(Gains) losses on sale of assets and other, net	-1,857	0
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	-50	-31
Total (gains) losses	2,341	3,465
Derivatives activities:
Cash settlements	27,513	-2,655
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	16,392	-15,373
(Increase) decrease in accounts receivable – affiliates	0	0
Increase in other assets	-3,878	-1,040
Increase (decrease) in accounts payable and accrued expenses	-25,734	-4,177
Increase (decrease) in accounts payable and accrued expenses – affiliates	19,856	-16,950
Increase in other liabilities	-9,925	-6,330
Net cash provided by operating activities	42,489	94,830
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	-1,609	-134,750
Purchases of other property and equipment	-1,092	-1,833
Investment in affiliates	0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	3,813	0
Net cash used in investing activities	1,112	-136,583
Cash flow from financing activities:
Proceeds from sale of units	0
Proceeds from borrowings	0	0
Repayments of debt	0	-1,188
Distributions to unitholders	0	0
Financing fees and offering costs	0	-2,581
Change in notes payable with affiliate	0	0
Distribution to affiliate	-43,778
Excess tax benefit from unit-based compensation	0	0
Other	15	0
Net cash provided by (used in) financing activities	-43,763	-3,769
Net increase in cash and cash equivalents	-162	-45,522
Cash and cash equivalents:
Beginning	1,586	51,041
Ending	1,424	5,519
Eliminations
Cash flow from operating activities:
Net loss	286,275	-24,893
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	1,336	0
Impairment of long-lived assets	-64,800
Unit-based compensation expenses	0	0
Gain 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 losses from consolidated subsidiaries	-222,811	24,893
Deferred income taxes	0	0
Total (gains) losses	0	0
Derivatives activities:
Cash settlements	0	0
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	0	0
(Increase) decrease in accounts receivable – affiliates	2,774	-27,463
Increase in other assets	0	0
Increase (decrease) in accounts payable and accrued expenses	0	0
Increase (decrease) in accounts payable and accrued expenses – affiliates	-2,774	27,463
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	-43,778
Change in notes receivable with affiliate	16,400	9,200
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	-27,378	9,200
Cash flow from financing activities:
Proceeds from sale of units	0
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and offering costs	0	0
Change in notes payable with affiliate	-16,400	-9,200
Distribution to affiliate	43,778
Excess tax benefit from unit-based compensation	0	0
Other	0	0
Net cash provided by (used in) financing activities	27,378	-9,200
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)	3 Months Ended
	Mar. 31, 2015
Condensed Consolidating Financial Information [Abstract]
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	100.00%