Pressburg (ROAN) 10-Q 7 Aug 14 2014 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Jul. 31, 2014
Document and Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Entity Registrant Name	'Linn Energy, LLC	'
Entity Central Index Key	'0001326428	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'Yes	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	331,729,246
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$38,339	$52,171
Accounts receivable – trade, net	549,589	488,202
Derivative instruments	91,611	176,130
Other current assets	107,882	99,437
Total current assets	787,421	815,940
Noncurrent assets:	'	'
Oil and natural gas properties (successful efforts method)	18,684,209	17,888,559
Less accumulated depletion and amortization	-4,051,761	-3,546,284
Oil and natural gas properties, successful efforts method, net	14,632,448	14,342,275
Other property and equipment	676,294	647,882
Less accumulated depreciation	-135,316	-110,939
Other property and equipment, net	540,978	536,943
Derivative instruments	175,537	682,002
Other noncurrent assets	132,280	127,804
Noncurrent assets, excluding property, total	307,817	809,806
Total noncurrent assets	15,481,243	15,689,024
Total assets	16,268,664	16,504,964
Current liabilities:	'	'
Accounts payable and accrued expenses	860,171	849,624
Derivative instruments	59,907	28,176
Other accrued liabilities	138,378	163,375
Current portion of long-term debt	0	211,558
Total current liabilities	1,058,456	1,252,733
Noncurrent liabilities:	'	'
Credit facilities	3,418,175	2,733,175
Term loan	500,000	500,000
Senior notes, net	5,726,176	5,725,483
Derivative instruments	8,827	4,649
Other noncurrent liabilities	395,907	397,497
Total noncurrent liabilities	10,049,085	9,360,804
Commitments and contingencies (Note 10)	'	'
Unitholders’ capital:	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	5,854,727	6,291,824
Accumulated deficit	-693,604	-400,397
Total unitholders' capital	5,161,123	5,891,427
Total liabilities and unitholders’ capital	$16,268,664	$16,504,964

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Unitholders' capital: Units issued	331,667,975	329,661,161
Unitholders' capital: Units outstanding	331,667,975	329,661,161

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$967,850	$488,207	$1,906,727	$950,939
Gains (losses) on oil and natural gas derivatives	-408,788	326,733	-650,281	218,363
Marketing revenues	30,273	17,222	60,819	27,074
Other revenues	7,616	6,663	13,273	11,509
Total revenues	596,951	838,825	1,330,538	1,207,885
Expenses:	'	'	'	'
Lease operating expenses	184,901	83,584	378,934	172,305
Transportation expenses	44,854	29,298	90,484	56,481
Marketing expenses	23,274	9,360	44,346	16,734
General and administrative expenses	66,906	46,305	146,134	104,871
Exploration costs	1,551	818	2,642	3,044
Depreciation, depletion and amortization	274,435	198,629	542,236	396,070
Impairment of long-lived assets	0	-14,851	0	42,202
Taxes, other than income taxes	68,531	32,397	134,244	72,068
(Gains) losses on sale of assets and other, net	5,467	-959	8,053	2,213
Total expenses	669,919	384,581	1,347,073	865,988
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-134,300	-103,847	-268,113	-204,206
Loss on extinguishment of debt	0	-4,187	0	-4,187
Other, net	-2,549	-2,182	-4,852	-3,825
Total other income and (expenses)	-136,849	-110,216	-272,965	-212,218
Income (loss) before income taxes	-209,817	344,028	-289,500	129,679
Income tax expense (benefit)	-1,947	-1,129	3,707	6,407
Net income (loss)	($207,870)	$345,157	($293,207)	$123,272
Net income (loss) per unit:	'	'	'	'
Basic (in usd per unit)	($0.64)	$1.47	($0.91)	$0.52
Diluted (in usd per unit)	($0.64)	$1.46	($0.91)	$0.52
Weighted average units outstanding:	'	'	'	'
Basic (in units)	328,844	233,448	328,588	233,313
Diluted (in units)	328,844	233,910	328,588	233,800
Distributions declared per unit (in usd per unit)	$0.73	$0.73	$1.45	$1.45

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS' CAPITAL (Unaudited) (USD $)	3 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	$5,891,427
Issuance of units	'	7,887
Distributions to unitholders	'	-480,583
Unit-based compensation expenses	'	32,583
Excess tax benefit from unit-based compensation	'	3,016
Net loss	-207,870	-293,207
30-Jun-14	5,161,123	5,161,123
Units [Member]	'	'
Increase (Decrease) in Unitholders' Capital	'	'
December 31, 2013 (in units)	'	329,661
Issuance of units (in units)	'	2,007
June 30, 2014 (in units)	331,668	331,668
Unitholders' Capital [Member]	'	'
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	6,291,824
Issuance of units	'	7,887
Distributions to unitholders	'	-480,583
Unit-based compensation expenses	'	32,583
Excess tax benefit from unit-based compensation	'	3,016
Net loss	'	0
30-Jun-14	5,854,727	5,854,727
Accumulated Income [Member]	'	'
Increase (Decrease) in Unitholders' Capital	'	'
31-Dec-13	'	-400,397
Issuance of units	'	0
Distributions to unitholders	'	0
Unit-based compensation expenses	'	0
Excess tax benefit from unit-based compensation	'	0
Net loss	'	-293,207
30-Jun-14	($693,604)	($693,604)

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Cash flow from operating activities:	'	'	'	'
Net income (loss)	($207,870)	$345,157	($293,207)	$123,272
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'	'
Depreciation, depletion and amortization	274,435	198,629	542,236	396,070
Impairment of long-lived assets	0	-14,851	0	42,202
Unit-based compensation expenses	'	'	32,583	19,575
Loss on extinguishment of debt	0	4,187	0	4,187
Amortization and write-off of deferred financing fees	'	'	6,202	10,905
Losses on sale of assets and other, net	'	'	3,506	16,814
Deferred income taxes	'	'	3,475	5,725
Derivatives activities:	'	'	'	'
Total (gains) losses	408,788	-326,733	650,281	-218,363
Cash settlements	-9,000	58,708	-23,123	144,502
Changes in assets and liabilities:	'	'	'	'
(Increase) decrease in accounts receivable – trade, net	'	'	-61,891	36,174
(Increase) decrease in other assets	'	'	-6,947	2,260
Increase (decrease) in accounts payable and accrued expenses	'	'	113,582	-5,319
Decrease in other liabilities	'	'	-51,062	-16,648
Net cash provided by operating activities	'	'	915,635	561,356
Cash flow from investing activities:	'	'	'	'
Acquisition of oil and natural gas properties and joint-venture funding	'	'	-25,891	-64,381
Development of oil and natural gas properties	'	'	-805,617	-495,899
Purchases of other property and equipment	'	'	-31,411	-55,147
Proceeds from sale of properties and equipment and other	'	'	-11,730	210,899
Net cash used in investing activities	'	'	-874,649	-404,528
Cash flow from financing activities:	'	'	'	'
Proceeds from borrowings	'	'	1,095,000	775,000
Repayments of debt	'	'	-616,124	-560,737
Distributions to unitholders	'	'	-480,583	-341,117
Financing fees and other, net	'	'	-56,127	-30,656
Excess tax benefit from unit-based compensation	'	'	3,016	591
Net cash used in financing activities	'	'	-54,818	-156,919
Net decrease in cash and cash equivalents	'	'	-13,832	-91
Cash and cash equivalents:	'	'	'	'
Beginning	'	'	52,171	1,243
Ending	$38,339	$1,152	$38,339	$1,152

Basis_of_Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Nature of Business
	Linn Energy, LLC (“LINN Energy” or the “Company”) is an independent oil and natural gas company. LINN Energy’s mission is to acquire, develop and maximize cash flow from a growing portfolio of long-life oil and natural gas assets. The Company’s properties are located in the United States (“U.S.”), in the Mid-Continent, the Rockies, the Permian Basin, California, the Hugoton Basin, Michigan, Illinois and east Texas.
	Principles of Consolidation and Reporting
	The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The Company’s other investment is accounted for at cost.
	The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ capital or cash flows.
	Use of Estimates
	The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
	Recently Issued Accounting Standards
	In May 2014, the Financial Accounting Standards Board issued an Accounting Standards Update (“ASU”) that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. The ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 2016, and interim periods within those years (early adoption prohibited). The Company is currently evaluating the impact, if any, of the adoption of this ASU on its consolidated financial statements and related disclosures.

Acquisitions_JointVenture_Fund

Acquisitions, Joint-Venture Funding and Divestitures	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Acquisitions, Joint-Venture Funding and Divestitures	'
	Acquisitions, Joint-Venture Funding and Divestitures
	For the six months ended June 30, 2014, the Company paid approximately $25 million, including interest, towards the future funding 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.
	During the six months ended June 30, 2014, the Company completed small acquisitions of oil and natural gas properties located in its various operating regions. The Company, in the aggregate, paid approximately $1 million in total consideration for these properties.
	Properties Exchange – Pending
	On May 20, 2014, the Company, through two of its wholly owned subsidiaries, entered into a definitive agreement to trade a portion of its Permian Basin properties to Exxon Mobil Corporation and its affiliates, including its wholly owned subsidiary XTO Energy Inc., for operating interests in the Hugoton Basin. The Company anticipates the transaction will close in the third quarter of 2014, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied.
	Acquisitions and Divestiture – Pending
	On June 27, 2014, the Company, through one of its wholly owned subsidiaries, entered into a definitive purchase and sale agreement to acquire certain oil and natural gas properties and related assets located primarily in the Rockies, Mid-Continent, east Texas, north Louisiana and south Texas from affiliates of Devon Energy Corporation for a contract price of $2.3 billion. The Company anticipates the acquisition will close in the third quarter of 2014, subject to closing conditions, and has secured $2.3 billion of committed interim financing for the acquisition, subject to final documentation. There can be no assurance that all of the conditions to closing will be satisfied.
	On July 18, 2014, the Company, through one of its wholly owned subsidiaries, entered into a definitive purchase and sale agreement to acquire certain oil and natural gas properties located in the Hugoton Basin from Pioneer Natural Resources Company for a contract price of $340 million, including a deposit of $34 million paid in July 2014. The Company anticipates the acquisition will close in the third quarter of 2014, subject to closing conditions, and will be financed with borrowings under the LINN Credit Facility, as defined in Note 6. There can be no assurance that all of the conditions to closing will be satisfied.
	On July 24, 2014, the Company, through one of its wholly owned subsidiaries, entered into a definitive purchase and sale agreement to sell its interests in certain non-producing oil and natural gas properties located in the Mid-Continent region for a purchase price of approximately $90 million, subject to closing adjustments. The sale is anticipated to close in the fourth quarter of 2014, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied. The Company plans to use the net proceeds from the sale to repay borrowings under the LINN Credit Facility.
	Acquisitions – 2013
	Berry Acquisition
	On December 16, 2013, the Company completed the transactions contemplated by the merger agreement between the Company, LinnCo, LLC (“LinnCo”), an affiliate of LINN Energy, and Berry Petroleum Company, now Berry Petroleum Company, LLC (“Berry”), under which LinnCo acquired all of the outstanding common shares of Berry and the contribution agreement between LinnCo and the Company, under which LinnCo contributed Berry to the Company in exchange for LINN Energy units. Under the merger agreement, as amended, Berry’s shareholders received 1.68 LinnCo common shares for each Berry common share they owned, totaling 93,756,674 LinnCo common shares. Under the contribution agreement, LinnCo contributed Berry to LINN Energy in exchange for 93,756,674 newly issued LINN Energy units, after which Berry became an indirect wholly owned subsidiary of LINN Energy. The transaction has a value of approximately $4.6 billion, including the assumption of approximately $2.3 billion of Berry’s debt and net of cash acquired of approximately $451 million.
	This acquisition was accounted for under the acquisition method of accounting. Accordingly, the Company conducted assessments of net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated fair values on the acquisition date, while transaction and integration costs associated with the acquisitions were expensed as incurred. The initial accounting for the business combination is not complete and adjustments to provisional amounts, or recognition of additional assets acquired or liabilities assumed, may occur as more detailed analyses are completed and additional information is obtained about the facts and circumstances that existed as of the acquisition date. The results of operations of the acquisition have been included in the condensed consolidated financial statements since the acquisition date.
	The following unaudited pro forma financial information presents a summary of the Company’s consolidated results of operations for the three months and six months ended June 30, 2013, assuming the Berry acquisition had been completed as of January 1, 2013, including adjustments to reflect the values assigned to the net assets acquired:
		Three Months Ended		Six Months Ended
		30-Jun-13		30-Jun-13
		(in thousands, except
		per unit amounts)
	Total revenues and other	$	1,161,137	$	1,806,346
	Total operating expenses	$	586,909	$	1,256,821
	Net income	$	441,935	$	284,615
	Net income per unit:
	Basic	$	1.34	$	0.86
	Diluted	$	1.34	$	0.86
	The pro forma condensed combined statements of operations includes adjustments to:
	•	Reflect the results of Berry.
	•	Reflect incremental depreciation, depletion and amortization expense, using the units-of-production method, related to oil and natural gas properties acquired and using an estimated useful life of 20 years for other property and equipment.
	•	Reflect a reduction in interest expense related to the amortization of the adjustment to fair value of Berry’s debt using the effective interest method.
	•	Exclude transaction costs included in the historical statements of operations for the three months and six months ended June 30, 2013, as they reflect nonrecurring charges not expected to have a continuing impact on the combined results.
	•	Reflect approximately 93.8 million LINN Energy units assumed to be issued in conjunction with the transaction on January 1, 2013.
	Divestiture – 2013
	On May 31, 2013, the Company, through one of its wholly owned subsidiaries, together with the Company’s partners, Panther Energy, LLC and Red Willow Mid-Continent, LLC, completed the sale of its interests in certain oil and natural gas properties located in the Mid-Continent region (“Panther Operated Cleveland Properties”) to Midstates Petroleum Company, Inc. At March 31, 2013, the carrying value of the Panther Operated Cleveland Properties was reduced to fair value less costs to sell resulting in an impairment charge of approximately $57 million and the properties were classified as “assets held for sale.” On May 31, 2013, upon the completion of the sale, the Company recorded an adjustment of approximately $15 million to reduce the initial impairment charge recorded in March 2013 resulting in a total impairment charge of approximately $42 million for the six months ended June 30, 2013. The charge is included in “impairment of long-lived assets” on the condensed consolidated statement of operations. Proceeds received for the Company’s portion of its interests in the properties were approximately $219 million, net of costs to sell of approximately $2 million.

Unitholders_Capital

Unitholders' Capital	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Unitholders' Capital	'
	Unitholders’ Capital
	Distributions
	Under the Company’s limited liability company agreement, unitholders are entitled to receive a distribution of available cash, which includes cash on hand plus borrowings less any reserves established by the Company’s Board of Directors to provide for the proper conduct of the Company’s business (including reserves for future capital expenditures, including drilling, acquisitions and anticipated future credit needs) or to fund distributions over the next four quarters. Distributions paid by the Company are presented on the condensed consolidated statement of unitholders’ capital and the condensed consolidated statements of cash flows. On July 1, 2014, the Company’s Board of Directors declared a cash distribution of $0.725 per unit with respect to the second quarter of 2014, to be paid in three equal installments of $0.2416 per unit. The first monthly distribution with respect to the second quarter of 2014, totaling approximately $80 million, was paid on July 16, 2014, to unitholders of record as of the close of business on July 11, 2014.

Oil_and_Natural_Gas_Properties

Oil and Natural Gas Properties	6 Months Ended
	Jun. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Oil and Natural Gas Properties	'
	Oil and Natural Gas Properties
	Oil and Natural Gas Capitalized Costs
	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	12,329,359		$	12,277,089
	Development	4,468,702			3,660,277
	Unproved properties	1,886,148			1,951,193
		18,684,209			17,888,559
	Less accumulated depletion and amortization	(4,051,761		)	(3,546,284		)
		$	14,632,448		$	14,342,275

UnitBased_Compensation

Unit-Based Compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Unit-Based Compensation	'
	Unit-Based Compensation
	During the six months ended June 30, 2014, the Company granted 1,447,577 restricted units and 214,875 phantom units to employees, primarily as part of its annual review of its employees’ compensation, including executives, with an aggregate fair value of approximately $56 million. The restricted units and phantom units vest over three years. The Company also granted 212,524 performance units (the maximum number of units available to be earned) to certain executive officers, with an aggregate fair value of approximately $5 million. The initial 2014 performance unit awards vest 50% in two years and 50% in three years from the award date. A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	General and administrative expenses	$	9,496	$	7,136	$	27,719	$	17,001
	Lease operating expenses	1,587		1,177		4,864		2,574
	Total unit-based compensation expenses	$	11,083	$	8,313	$	32,583	$	19,575
	Income tax benefit	$	4,095	$	3,072	$	12,039	$	7,233

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	The following summarizes the Company’s outstanding debt:
		June 30,			31-Dec-13
		2014
		(in thousands, except percentages)
	LINN credit facility (1)	$	2,245,000		$	1,560,000
	Berry credit facility (2)	1,173,175			1,173,175
	Term loan (3)	500,000			500,000
	10.25% Berry senior notes due June 2014	—			205,257
	6.50% senior notes due May 2019	750,000			750,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,300,000			1,300,000
	6.75% Berry senior notes due November 2020	299,970			300,000
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.375% Berry senior notes due September 2022	599,163			600,000
	Net unamortized discounts and premiums	(22,957		)	(18,216		)
	Total debt, net	9,644,351			9,170,216
	Less current maturities	—			(211,558		)
	Total long-term debt, net	$	9,644,351		$	8,958,658
	(1)	Variable interest rates of 1.90% and 1.92% at June 30, 2014, and December 31, 2013, respectively.
	(2)	Variable interest rates of 2.66% and 2.67% at June 30, 2014, and December 31, 2013, respectively.
	(3)	Variable interest rates of 2.65% and 2.67% at June 30, 2014, and December 31, 2013, 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, as defined below, 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.
		30-Jun-14						December 31, 2013
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit Facilities	$	3,418,175		$	3,418,175		$	2,733,175	$	2,733,175
	Term loan	500,000			500,000			500,000		500,000
	Senior notes, net	5,726,176			6,091,525			5,937,041		6,162,402
	Total debt, net	$	9,644,351		$	10,009,700		$	9,170,216	$	9,395,577
	Credit Facilities
	LINN Credit Facility
	The Company’s Sixth Amended and Restated Credit Agreement (“LINN Credit Facility”) provides for a revolving credit facility up to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount of $4.0 billion. At June 30, 2014, the LINN Credit Facility had a borrowing base of $4.5 billion and available borrowing capacity of approximately $1.8 billion, which includes a $5 million reduction for outstanding letters of credit. In April 2014, the Company entered into an amendment to the LINN Credit Facility to extend the maturity from April 2018 to April 2019, among other items.
	Redetermination of the borrowing base under the LINN Credit Facility, based primarily on reserve reports that reflect commodity prices at such time, occurs semi-annually, in April and October. The administrative agent, at the direction of certain of the lenders, has the right to request one interim borrowing base redetermination per year. The Company also has the right to request one interim borrowing base redetermination per year, as well as the right to an additional interim redetermination each year in connection with certain acquisitions. Significant declines in commodity prices may result in a decrease in the borrowing base. The Company’s obligations under the LINN Credit Facility are secured by mortgages on certain of its material subsidiaries’ oil and natural gas properties and other personal property as well as a pledge of all ownership interests in the Company’s direct and indirect material subsidiaries. The Company is required to maintain either: 1) mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on the most recent reserve report, or 2) a Collateral Coverage Ratio of at least 2.5 to 1. Collateral Coverage Ratio is defined as the ratio of the present value of future cash flows from proved reserves from the currently mortgaged properties to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount. Additionally, the obligations under the LINN Credit Facility are guaranteed by all of the Company’s material subsidiaries, other than Berry, and are required to be guaranteed by any future material subsidiaries. The Company is in compliance with all financial and other covenants of the LINN Credit Facility.
	At the Company’s election, interest on borrowings under the LINN Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin between 1.5% and 2.5% per annum (depending on the then-current level of borrowings under the LINN Credit Facility) or the alternate base rate (“ABR”) plus an applicable margin between 0.5% and 1.5% per annum (depending on the then-current level of borrowings under the LINN Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at LIBOR. The Company is required to pay a commitment fee to the lenders under the LINN Credit Facility, which accrues at a rate per annum between 0.375% and 0.5% (depending on the then-current level of borrowings under the LINN Credit Facility) on the average daily unused amount of the maximum commitment amount of the lenders.
	In addition, the Company has a $500 million senior secured term loan with certain participants in its lender group under the LINN Credit Facility. Upon the amendment of the LINN Credit Facility in April 2014, the term loan has a maturity date of April 2019, consistent with the maturity of the LINN Credit Facility, and incurs interest based on either the LIBOR plus a margin of 2.5% per annum or the ABR plus a margin of 1.5% per annum, at the Company’s election. Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at LIBOR. The term loan may be repaid at the option of the Company without premium or penalty, subject to breakage costs. While the term loan is outstanding, the Company is required to maintain either: 1) mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on the most recent reserve report, or 2) a Term Loan Collateral Coverage Ratio of at least 2.5 to 1. The Term Loan Collateral Coverage Ratio is defined as the ratio of the present value of future cash flows from proved reserves from the currently mortgaged properties to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount and the aggregate amount of the term loan outstanding. The other terms and conditions of the LINN Credit Facility, including the financial and other restrictive covenants set forth therein, are applicable to the term loan.
	Berry Credit Facility
	Berry’s Second Amended and Restated Credit Agreement (“Berry Credit Facility”) has a borrowing base of $1.4 billion, subject to lender commitments. At June 30, 2014, lender commitments under the facility were $1.2 billion but there was less than $1 million of available borrowing capacity, including outstanding letters of credit. In February 2014, Berry entered into an amendment to the Berry Credit Facility to amend the terms of certain financial and reporting covenants, and in April 2014, Berry entered into an amendment to the Berry Credit Facility to extend the maturity from May 2016 to April 2019 and to amend the terms of certain financial covenants and definitions, among other items.
	Redetermination of the borrowing base under the Berry Credit Facility, based primarily on reserve reports that reflect commodity prices at such time, occurs semi-annually, in April and October. The lenders under the Berry Credit Facility and Berry also have the right to request interim borrowing base redeterminations once between scheduled redeterminations. Significant declines in commodity prices may result in a decrease in the borrowing base. Berry’s obligations under the Berry Credit Facility are secured by mortgages on its oil and natural gas properties and other personal property. Berry is required to maintain mortgages on properties representing at least 80% of the present value of its oil and natural gas proved reserves.
	Berry is currently in compliance with all financial and other covenants of the Berry Credit Facility. At December 31, 2013, Berry’s Current Ratio (as defined in the Berry Credit Facility), fell short of the requirement under its covenant primarily due to factors related to the transactions between the Company, LinnCo and Berry, including a reassessment of the carrying value of items on Berry’s balance sheet as of the acquisition date and updated accruals as of December 31, 2013. In February 2014, Berry received a waiver of the applicability of that covenant and any noncompliance which may have resulted as of December 31, 2013, and entered into an amendment to its credit facility to address this covenant for future periods. The shortfall and related waiver and amendment had no effect on Berry’s compliance with the indentures governing its outstanding senior notes for the quarter ended December 31, 2013, and Berry was in compliance with all of the covenants under the indentures governing its senior notes at December 31, 2013.
	At Berry’s election, interest on borrowings under the Berry Credit Facility is determined by reference to either the LIBOR plus an applicable margin between 1.5% and 2.5% per annum (depending on the then-current level of borrowings under the Berry Credit Facility) or a Base Rate (as defined in the Berry Credit Facility) plus an applicable margin between 0.5% and 1.5% per annum (depending on the then-current level of borrowings under the Berry Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the Base Rate and at the end of the applicable interest period for loans bearing interest at LIBOR. Berry is required to pay a commitment fee to the lenders under the Berry Credit Facility, which accrues at a rate per annum between 0.375% and 0.5% (depending on the then-current level of utilization under the Berry Credit Facility) on the average daily unused amount of the maximum commitment amount of the lenders.
	The Company refers to the LINN Credit Facility and the Berry Credit Facility, collectively, as the “Credit Facilities.”
	Senior Notes Due May 2019
	The Company has $750 million in aggregate principal amount of 6.50% senior notes due May 2019 (the “May 2019 Senior Notes”). In an exchange offer that expired in October 2012, the Company exchanged all of its $750 million outstanding principal amount of May 2019 Senior Notes for an equal amount of new May 2019 Senior Notes. The terms of the new May 2019 Senior Notes are substantially similar in all material respects to those of the outstanding May 2019 Senior Notes, except that the transfer restrictions, registration rights and additional interest provisions relating to the outstanding May 2019 Senior Notes do not apply to the new May 2019 Senior Notes.
	Senior Notes Due November 2019
	The Company has $1.8 billion in aggregate principal amount of 6.25% senior notes due November 2019 (the “November 2019 Senior Notes”). In connection with the issuance and sale of the November 2019 Senior Notes, the Company entered into a Registration Rights Agreement (“November 2019 Registration Rights Agreement”) with the initial purchasers. Under the November 2019 Registration Rights Agreement, the Company agreed to use its reasonable efforts to file with the SEC and cause to become effective a registration statement relating to an offer to issue new notes having terms substantially similar to the November 2019 Senior Notes in exchange for outstanding November 2019 Senior Notes within 400 days after the notes were issued. On March 22, 2013, the Company filed a registration statement on Form S-4 to register exchange notes that are substantially similar to the November 2019 Senior Notes. On June 2, 2014, the registration statement was declared effective and the Company commenced an offer to exchange any and all of its $1.8 billion outstanding principal amount of November 2019 Senior Notes for an equal amount of new November 2019 Senior Notes.
	The terms of the new November 2019 Senior Notes are substantially similar in all material respects to those of the outstanding November 2019 Senior Notes, except that the transfer restrictions, registration rights and additional interest provisions relating to the outstanding November 2019 Senior Notes do not apply to the new November 2019 Senior Notes. The exchange offer expired on June 28, 2014. The effective date of the registration statement was past the deadline in the registration rights agreement, and therefore, the Company paid additional interest of approximately $15 million since the deadline.
	Senior Notes Due April 2020 and Senior Notes Due February 2021
	The Company has $1.3 billion in aggregate principal amount of 8.625% senior notes due April 2020 (the “April 2020 Senior Notes”) and $1.0 billion in aggregate principal amount of 7.75% senior notes due February 2021 (the “February 2021 Senior Notes,” and together with the April 2020 Senior Notes, the “2010 Issued Senior Notes”). The restrictive legends from each of the 2010 Issued Senior Notes have been removed making them freely tradable (other than with respect to persons that are affiliates of the Company), thereby terminating the Company’s obligations under each of the registration rights agreements entered into in connection with the issuance of the 2010 Issued Senior Notes.
	Berry Senior Notes Due November 2020
	Berry has $300 million in aggregate principal amount of 6.75% senior notes due November 2020 (the “Berry November 2020 Senior Notes”). The Berry November 2020 Senior Notes were recorded at their fair value of approximately $310 million on the Berry acquisition date including a $10 million premium which is being amortized to interest expense over the life of the related notes.
	Berry Senior Notes Due September 2022
	Berry has $599 million in aggregate principal amount of 6.375% senior notes due September 2022 (the “Berry September 2022 Senior Notes”). The Berry September 2022 Senior Notes were recorded at their fair value of approximately $607 million on the Berry acquisition date including a $7 million premium which is being amortized to interest expense over the life of the related notes.
	Repurchases of Berry Senior Notes
	In February 2014, in accordance with the indentures related to Berry’s senior notes, the Company repurchased through cash tender offers $321,000, $30,000 and $837,000 of Berry’s 10.25% senior notes due June 2014 (the “Berry June 2014 Senior Notes”), November 2020 Senior Notes and September 2022 Senior Notes, respectively.
	Payment of Berry June 2014 Senior Notes
	On May 30, 2014, in accordance with the provisions of the indenture related to the Berry June 2014 Senior Notes, the Company paid in full the remaining outstanding principal amount of approximately $205 million.
	Senior Notes Covenants
	The Company’s senior notes contain covenants that, among other things, may limit its ability to: (i) pay distributions on, purchase or redeem the Company’s units or redeem its subordinated debt; (ii) make investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create certain liens; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets; (vii) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries. The Company is in compliance with all financial and other covenants of its senior notes.
	Berry’s senior notes contain covenants that, among other things, may limit its ability to: (i) incur or guarantee additional indebtedness; (ii) pay distributions on Berry’s equity or redeem its subordinated debt; (iii) create certain liens; (iv) enter into agreements that restrict distributions or other payments from Berry’s restricted subsidiaries to Berry; (v) sell assets; (vi) engage in transactions with affiliates; and (vii) consolidate, merge or transfer all or substantially all of Berry’s assets. Berry is in compliance with all financial and other covenants of its senior notes.

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	Derivatives
	Commodity Derivatives
	The Company hedges a significant portion of its forecasted production to reduce exposure to fluctuations in the prices of oil and natural gas and provide long-term cash flow predictability to manage its business, service debt and pay distributions. The current direct NGL hedging market is constrained in terms of price, volume, duration and number of counterparties, which limits the Company’s ability to effectively hedge its NGL production. As a result, currently, the Company directly hedges only its oil and natural gas production.
	The Company enters into commodity hedging transactions primarily in the form of swap contracts that are designed to provide a fixed price and, from time to time, put options that are designed to provide a fixed price floor with the opportunity for upside. The Company enters into these transactions with respect to a portion of its projected production to provide an economic hedge of the risk related to the future commodity prices received. The Company does not enter into derivative contracts for trading purposes. In connection with the Berry acquisition (see Note 2), the Company assumed certain derivative contracts that Berry had entered into prior to the acquisition date, including oil swaps, oil trade month roll swaps and oil collars through 2014, and oil basis swaps and oil three-way collars through 2015. The Company did not designate any of these contracts as cash flow hedges; therefore, the changes in fair value of these instruments are recorded in current earnings. See Note 8 for fair value disclosures about oil and natural gas commodity derivatives.
	The following table summarizes derivative positions for the periods indicated as of June 30, 2014:
		July 1 - December 31, 2014			2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	49,100			118,041			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.25		$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	40,141			71,854			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	5		$	4.88		$	—
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	8,485			11,599			11,465			4,755			—
	Average price ($/Bbl)	$	92.44		$	96.23		$	90.56		$	89.02		$	—
	Collars (NYMEX WTI):
	Hedged volume (MBbls)	368			—			—			—			—
	Average floor price ($/Bbl)	$	90		$	—		$	—		$	—		$	—
	Average ceiling price ($/Bbl)	$	102.87		$	—		$	—		$	—		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	1,564			1,095			—			—			—
	Short put ($/Bbl)	$	72.11		$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	93.76		$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	109.79		$	101.62		$	—		$	—		$	—
		July 1 - December 31, 2014			2015			2016			2017			2018
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	1,996			3,426			3,271			384			—
	Average price ($/Bbl)	$	91.3		$	90		$	90		$	90		$	—
	Three-way collars (ICE Brent):
	Hedged volume (MBbls)	184			—			—			—			—
	Short put ($/Bbl)	$	80		$	—		$	—		$	—		$	—
	Long put ($/Bbl)	$	100		$	—		$	—		$	—		$	—
	Short call ($/Bbl)	$	114.05		$	—		$	—		$	—		$	—
	Natural gas basis differential positions: (2)
	Panhandle basis swaps:
	Hedged volume (MMMBtu)	40,020			87,162			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps:
	Hedged volume (MMMBtu)	20,619			43,292			46,294			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.20	)	$	(0.20	)	$	(0.20	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps:
	Hedged volume (MMMBtu)	4,784			9,344			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.08		$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps:
	Hedged volume (MMMBtu)	2,650			4,891			4,575			3,604			986
	Hedged differential ($/MMBtu)	$	(0.10	)	$	(0.10	)	$	(0.10	)	$	(0.08	)	$	(0.08	)
	Permian basis swaps:
	Hedged volume (MMMBtu)	2,466			5,074			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	Oil basis differential positions:
	ICE Brent - NYMEX WTI basis swaps:
	Hedged volume (MBbls)	1,840			2,920			—			—			—
	Hedged differential ($/Bbl)	$	11.6		$	11.6		$	—		$	—		$	—
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (3)
	Hedged volume (MBbls)	4,577			7,251			7,446			6,486			—
	Hedged differential ($/Bbl)	$	0.24		$	0.24		$	0.25		$	0.25		$	—
	(1)	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
	(2)	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
	(3)	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).
	Settled derivatives on natural gas production for the three months and six months ended June 30, 2014, included volumes of 44,136 MMMBtu and 87,787 MMMBtu, respectively, at an average contract price of $5.14 per MMBtu. Settled derivatives on oil production for the three months and six months ended June 30, 2014, included volumes of 6,230 MBbls and 12,391 MBbls, respectively, at an average contract price of $92.39 per Bbl. Settled derivatives on natural gas production for the three months and six months ended June 30, 2013, included volumes of 43,253 MMMBtu and 86,031 MMMBtu, respectively, at an average contract price of $5.29 per MMBtu. Settled derivatives on oil production for the three months and six months ended June 30, 2013, included volumes of 3,734 MBbls and 7,426 MBbls, respectively, at an average contract price of $95.57 per Bbl. The natural gas derivatives are settled based on the closing price of NYMEX natural gas on the last trading day for the delivery month, which occurs on the third business day preceding the delivery month, or the relevant index prices of natural gas published in Inside FERC’s Gas Market Report on the first business day of the delivery month. The oil derivatives are settled based on the average closing prices of NYMEX WTI and ICE Brent crude oil for each day of the delivery month.
Balance Sheet Presentation
The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed consolidated balance sheets. The following summarizes the fair value of derivatives outstanding on a gross basis:
	June 30,			December 31,
	2014			2013
	(in thousands)
Assets:
Commodity derivatives	$	551,636		$	1,048,212
Liabilities:
Commodity derivatives	$	353,222		$	222,905
By using derivative instruments to economically hedge exposures to changes in commodity prices, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Company, which creates credit risk. The Company’s counterparties are current participants or affiliates of participants in its Credit Facilities or were participants or affiliates of participants in its Credit Facilities at the time it originally entered into the derivatives. The Credit Facilities are secured by the Company’s oil, natural gas and NGL reserves; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties. The maximum amount of loss due to credit risk that the Company would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of financial instruments, was approximately $552 million at June 30, 2014. The Company minimizes the credit risk in derivative instruments by: (i) limiting its exposure to any single counterparty; (ii) entering into derivative instruments only with counterparties that meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity derivatives are subject to counterparty netting under agreements governing such derivatives and therefore the risk of loss due to counterparty nonperformance is somewhat mitigated.
Gains (Losses) on Derivatives
Gains and losses on derivatives were net losses of approximately $409 million and $650 million for the three months and six months ended June 30, 2014, respectively. Net losses for the three months and six months ended June 30, 2014, include cash settlement payments of approximately $9 million and $23 million, respectively. Gains and losses on derivatives were net gains of approximately $327 million and $218 million for the three months and six months ended June 30, 2013, respectively. Net gains for the three months and six months ended June 30, 2013, include cash settlement receipts of approximately $59 million and $145 million, respectively. These amounts are reported on the condensed consolidated statements of operations in “gains (losses) on oil and natural gas derivatives.”

Fair_Value_Measurements_on_a_R

Fair Value Measurements on a Recurring Basis	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements on a Recurring Basis	'
	Fair Value Measurements on a Recurring Basis
	The Company accounts for its commodity derivatives at fair value (see Note 7) on a recurring basis. The Company determines the fair value of its oil and natural gas derivatives utilizing pricing models that use a variety of techniques, including market quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those securities trade in active markets. Assumed credit risk adjustments, based on published credit ratings, public bond yield spreads and credit default swap spreads, are applied to the Company’s commodity derivatives.
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		30-Jun-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	551,636	$	(284,488	)	$	267,148
	Liabilities:
	Commodity derivatives	$	353,222	$	(284,488	)	$	68,734
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	1,048,212	$	(190,080	)	$	858,132
	Liabilities:
	Commodity derivatives	$	222,905	$	(190,080	)	$	32,825
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Asset retirement obligations associated with retiring tangible long-lived assets are recognized as a liability in the period in which a legal obligation is incurred and becomes determinable and are included in “other accrued liabilities” and “other noncurrent liabilities” on the condensed consolidated balance sheets. Accretion expense is included in “depreciation, depletion and amortization” on the condensed consolidated statements of operations. The fair value of additions to the asset retirement obligations is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plug and abandon costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors (2.0% for the six months ended June 30, 2014); and (iv) a credit-adjusted risk-free interest rate (average of 5.4% for the six months ended June 30, 2014). These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.
	The following presents a reconciliation of the asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	289,321
	Liabilities added from drilling	5,673
	Current year accretion expense	9,570
	Settlements	(9,947		)
	Revision of estimates	9,130
	Asset retirement obligations at June 30, 2014	$	303,747

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	The Company has been named as a defendant in a number of lawsuits, including claims from royalty owners related to disputed royalty payments and royalty valuations. With respect to a certain statewide class action case, the parties in this case are currently engaged in settlement negotiations and based on the current status of those negotiations, the Company estimates a range of possible loss of $1 million to $4.5 million for which an appropriate reserve has been established. For a certain statewide class action royalty payment dispute where a reserve has not yet been established, the Company has denied that it has any liability on the claims and has raised arguments and defenses that, if accepted by the court, will result in no loss to the Company. Based on the 10th Circuit Court of Appeals’ decision to reverse class certification orders in two unrelated certification cases, the court has permitted additional limited discovery prior to the briefing and hearing on class certification. Briefing and the hearing on class certification have not yet been set by the court. As a result, the Company is unable to estimate a possible loss, or range of possible loss, if any. In addition, the Company is involved in various other disputes arising in the ordinary course of business. The Company is not currently a party to any litigation or pending claims that it believes would have a material adverse effect on its overall business, financial position, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved.
	Prior to the Company’s acquisition of Berry, Berry became, and continues to be, a defendant in a certain statewide royalty class action case, in which the parties have entered into a settlement agreement to settle past claims for approximately $2.4 million. Subject to approval of the settlement agreement by the court, Berry and the Company anticipate distribution of settlement funds to begin late in the third quarter or early fourth quarter of 2014.
	In the summer of 2013, several class action complaints were filed in the United States District Court, Southern District of Texas and the United States District Court, Southern District of New York (the “SDNY”) against LINN Energy, LinnCo, certain of their officers and directors and the various underwriters for LinnCo’s initial public offering (these cases were subsequently consolidated in the SDNY (the “Combined Actions”)). These cases collectively asserted claims based on allegations that LINN Energy made false or misleading statements relating to its hedging strategy, the cash flow available for distribution to unitholders, and LINN Energy’s energy production in its Exchange Act filings and additional claims based on alleged misstatements relating to these issues in the prospectus and registration statement for LinnCo’s initial public offering.
	In November 2013, LINN Energy and the other defendants filed a motion to dismiss the Combined Actions. On July 8, 2014, the Court dismissed the plaintiff’s claims with prejudice concluding that the plaintiff failed to demonstrate any material misstatement or omission by LINN Energy or LinnCo.
	On July 10, 2013, Judy Mesirov, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against Mark E. Ellis, Kolja Rockov, David B. Rottino, Arden L. Walker, Jr., Charlene A. Ripley, Michael C. Linn, Joseph P. McCoy, George A. Alcorn, Terrence S. Jacobs, David D. Dunlap, Jeffrey C. Swoveland, and Linda M. Stephens in the District Court of Harris County, Texas (the “Mesirov Action”). On July 12, 2013, John Peters, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants in the District Court of Harris County, Texas (the “Peters Action”). On August 26, 2013, Joseph Abdalla, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants in the District Court of Harris County, Texas (the “Abdalla Action”) (the Mesirov Action, Peters Action, and Abdalla Actions together, the “Texas State Court Derivative Actions”). On August 19, 2013, the Charlote J. Lombardo Trust of 2004, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants in the United States District Court for the Southern District of Texas (the “Lombardo Action”). On September 30, 2013, the Thelma Feldman Rev. Trust, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants (the “Feldman Rev. Trust Action”). On October 21, 2013, the Parker Family Trust of 2012, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants (the “Parker Family Trust Action”) (the Lombardo Action, Feldman Rev. Trust Action, and Parker Family Trust Action together, the “Texas Federal Court Derivative Actions”) (the Texas State Court Derivative Action and Texas Federal Court Derivative Actions together, the “Texas Derivative Actions”). On May 28, 2014, Bill McKinnon, derivatively on behalf of nominal defendant LINN Energy, filed a shareholder derivative petition against many of the same defendants (the “McKinnon Action”) in the Delaware Court of Chancery (the “Delaware Derivative Action”) (the Delaware Derivative Action and the Texas Derivative Actions collectively, the “Derivative Actions”). The Derivative Actions assert derivative claims on behalf of LINN Energy against the individual defendants for alleged breaches of fiduciary duty, waste of corporate assets, mismanagement, abuse of control, and unjust enrichment based on factual allegations similar to those in the Combined Actions. The cases are in their preliminary stages and it is possible that additional similar actions could be filed in the District Court of Harris County, Texas, the Delaware Court of Chancery, or in other jurisdictions. As a result, the Company is unable to estimate a possible loss, or range of possible loss, if any.
	During the six months ended June 30, 2014, and June 30, 2013, the Company made no significant payments to settle any legal, environmental or tax proceedings. The Company regularly analyzes current information and accrues for probable liabilities on the disposition of certain matters as necessary. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.
	In 2008, Lehman Brothers Holdings Inc. and Lehman Brothers Commodity Services Inc. (together “Lehman”), filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code with the U.S. Bankruptcy Court for the Southern District of New York. In March 2011, the Company and Lehman entered into Termination Agreements under which the Company was granted general unsecured claims against Lehman in the amount of $51 million (the “Company Claim”). In December 2011, a Chapter 11 Plan (“Lehman Plan”) was approved by the Bankruptcy Court. Based on the recovery estimates described in the approved disclosure statement relating to the Lehman Plan, the Company expects to ultimately receive a substantial portion of the Company Claim. In April 2014 and April 2013, the Company received approximately $3 million and $5 million, respectively, of the Company Claim of which both amounts are included in “gains (losses) on oil and natural gas derivatives” on the condensed consolidated statements of operations. In the aggregate, the Company has received approximately $42 million of the Company Claim and additional distributions are expected to occur in the future.

Earnings_Per_Unit

Earnings Per Unit	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Unit	'
	Earnings Per Unit
	Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted earnings per unit is computed by adjusting the average number of units outstanding for the dilutive effect, if any, of unit equivalents. The Company uses the treasury stock method to determine the dilutive effect.
	The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net income (loss):
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(in thousands, except per unit data)
	Net income (loss)	$	(207,870	)	$	345,157		$	(293,207	)	$	123,272
	Allocated to participating securities	(2,154		)	(2,629		)	(4,306		)	(2,599		)
		$	(210,024	)	$	342,528		$	(297,513	)	$	120,673
	Basic net income (loss) per unit	$	(0.64	)	$	1.47		$	(0.91	)	$	0.52
	Diluted net income (loss) per unit	$	(0.64	)	$	1.46		$	(0.91	)	$	0.52
	Basic weighted average units outstanding	328,844			233,448			328,588			233,313
	Dilutive effect of unit equivalents	—			462			—			487
	Diluted weighted average units outstanding	328,844			233,910			328,588			233,800
	Basic units outstanding excludes the effect of weighted average anti-dilutive unit equivalents related to approximately 6 million unit options and warrants for the three months and six months ended June 30, 2014, and 3 million for the three months and six months ended June 30, 2013. All equivalent units were antidilutive for the three months and six months ended June 30, 2014.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The Company is a limited liability company treated as a partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits of the Company are passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Company’s subsidiaries are Subchapter C-corporations subject to federal and state income taxes. As such, with the exception of the state of Texas and certain subsidiaries, the Company is not a taxable entity, it does not directly pay federal and state income taxes and recognition has not been given to federal and state income taxes for the operations of the Company. Amounts recognized for income taxes are reported in “income tax expense (benefit)” on the condensed consolidated statements of operations.

Supplemental_Disclosures_to_th

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	6 Months Ended
	Jun. 30, 2014
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'
Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows	'
	Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows
	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Accrued compensation	$	31,702		$	55,257
	Accrued interest	92,019			93,998
	Asset retirement obligations	12,616			6,270
	Other	2,041			7,850
		$	138,378		$	163,375
	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Six Months Ended
		June 30,
		2014			2013
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	264,141		$	192,517
	Cash payments for income taxes	$	—		$	14
	Noncash investing activities:
	In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:
	Fair value of assets acquired	$	4,242		$	7,655
	Cash (paid) received	(1,139		)	3,231
	Receivables from sellers	—			1,792
	Payables to sellers	—			(6,854		)
	Liabilities assumed	$	3,103		$	5,824
	Included in “acquisition of oil and natural gas properties and joint-venture funding” on the condensed consolidated statements of cash flows for the six months ended June 30, 2014, and June 30, 2013, is approximately $25 million and $68 million, respectively, paid by the Company towards the future funding 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 June 30, 2014, and December 31, 2013, and primarily represents cash deposited by the Company into a separate account and designated for asset retirement obligations in accordance with contractual agreements.
	The Company manages its working capital and cash requirements to borrow only as needed from its Credit Facilities. At December 31, 2013, net outstanding checks of approximately $48 million were reclassified and included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet. At June 30, 2014, there were no net outstanding checks reclassified. The Company presents net outstanding checks as cash flows from financing activities on the condensed consolidated statements of cash flows.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	LinnCo
	LinnCo, an affiliate of LINN Energy, was formed on April 30, 2012. LinnCo’s initial sole purpose was to own units in LINN Energy. In connection with the acquisition of Berry, LinnCo amended its limited liability company agreement to permit, among other things, the acquisition and subsequent contribution of assets to LINN Energy. All of LinnCo’s common shares are held by the public. As of June 30, 2014, LinnCo had no significant assets or operations other than those related to its interest in LINN Energy and owned approximately 39% of LINN Energy’s outstanding units.
	LINN Energy has agreed to provide to LinnCo, or to pay on LinnCo’s behalf, any legal, accounting, tax advisory, financial advisory and engineering fees, printing costs or other administrative and out-of-pocket expenses incurred by LinnCo, along with any other expenses incurred in connection with any public offering of shares in LinnCo or incurred as a result of being a publicly traded entity. These expenses include costs associated with annual, quarterly and other reports to holders of LinnCo shares, tax return and Form 1099 preparation and distribution, NASDAQ listing fees, printing costs, independent auditor fees and expenses, legal counsel fees and expenses, limited liability company governance and compliance expenses and registrar and transfer agent fees. In addition, the Company has agreed to indemnify LinnCo and its officers and directors for damages suffered or costs incurred (other than income taxes payable by LinnCo) in connection with carrying out LinnCo’s activities. All expenses and costs paid by LINN Energy on LinnCo’s behalf are accounted for as investment at cost.
	For the three months and six months ended June 30, 2014, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $749,000 and $1.5 million, respectively, all of which had been paid by LINN Energy on LinnCo’s behalf as of June 30, 2014. The expenses for the three months and six months ended June 30, 2014, include approximately $471,000 and $941,000, respectively, related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses. In addition, during the six months ended June 30, 2014, LINN Energy paid approximately $11 million on LinnCo’s behalf for general and administrative expenses incurred by LinnCo in 2013.
	For the three months and six months ended June 30, 2013, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $3 million and $15 million, respectively, of which approximately $8 million had been paid by LINN Energy on LinnCo’s behalf as of June 30, 2013. The expenses for the three months and six months ended June 30, 2013, included approximately $2 million and $13 million, respectively, of transaction costs related to professional services rendered by third parties in connection with the Berry acquisition. The expenses for the three months and six months ended June 30, 2013, also included approximately $344,000 and $806,000, respectively, related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses.
	During the three months and six months ended June 30, 2014, the Company paid approximately $93 million and $186 million, respectively, in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy. During the three months and six months ended June 30, 2013, the Company paid approximately $25 million and $50 million, respectively, in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy.
	Other
	One of the Company’s directors is the President and Chief Executive Officer of Superior Energy Services, Inc. (“Superior”), which provides oilfield services to the Company. For the three months and six months ended June 30, 2014, the Company paid approximately $8 million and $12 million, respectively, and for the three months and six months ended June 30, 2013, the Company paid approximately $7 million and $13 million, respectively, to Superior and its subsidiaries for services rendered to the Company. The transactions associated with these payments were consummated on terms equivalent to those that prevail in arm’s-length transactions.

Subsidiary_Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2014
Condensed Financial Information [Abstract]	'
Subsidiary Guarantors	'
	Subsidiary Guarantors
	LINN Energy, LLC’s November 2019 Senior Notes, May 2019 Senior Notes and 2010 Issued Senior Notes are guaranteed by all of the Company’s material subsidiaries, other than Berry which is an indirect 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
	June 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	32		$	35,818		$	2,489		$	—		$	38,339
	Accounts receivable – trade, net	—			393,012			156,577			—			549,589
	Accounts receivable – affiliates	4,025,707			26,914			—			(4,052,621		)	—
	Derivative instruments	—			89,541			2,070			—			91,611
	Other current assets	476			77,171			30,235			—			107,882
	Total current assets	4,026,215			622,456			191,371			(4,052,621		)	787,421
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,558,084			5,126,125			—			18,684,209
	Less accumulated depletion and amortization	—			(3,901,130		)	(150,631		)	—			(4,051,761		)
		—			9,656,954			4,975,494			—			14,632,448
	Other property and equipment	—			586,438			89,856			—			676,294
	Less accumulated depreciation	—			(131,526		)	(3,790		)	—			(135,316		)
		—			454,912			86,066			—			540,978
	Derivative instruments	—			174,327			1,210			—			175,537
	Notes receivable – affiliates	114,400			—			—			(114,400		)	—
	Investments in consolidated subsidiaries	8,540,562			—			—			(8,540,562		)	—
	Other noncurrent assets, net	105,004			11,072			16,204			—			132,280
		8,759,966			185,399			17,414			(8,654,962		)	307,817
	Total noncurrent assets	8,759,966			10,297,265			5,078,974			(8,654,962		)	15,481,243
	Total assets	$	12,786,181		$	10,919,721		$	5,270,345		$	(12,707,583	)	$	16,268,664
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	1,822		$	570,680		$	287,669		$	—		$	860,171
	Accounts payable – affiliates	—			4,026,182			26,439			(4,052,621		)	—
	Derivative instruments	—			28,332			31,575			—			59,907
	Other accrued liabilities	75,773			43,045			19,560			—			138,378
	Total current liabilities	77,595			4,668,239			365,243			(4,052,621		)	1,058,456
	Noncurrent liabilities:
	Credit facilities	2,245,000			—			1,173,175			—			3,418,175
	Term loan	500,000			—			—			—			500,000
	Senior notes, net	4,811,496			—			914,680			—			5,726,176
	Notes payable – affiliates	—			114,400			—			(114,400		)	—
	Derivative instruments	—			8,827			—			—			8,827
	Other noncurrent liabilities	—			211,316			184,591			—			395,907
	Total noncurrent liabilities	7,556,496			334,543			2,272,446			(114,400		)	10,049,085
	Unitholders’ capital:
	Units issued and outstanding	5,845,694			4,833,310			2,493,923			(7,318,200		)	5,854,727
	Accumulated income (deficit)	(693,604		)	1,083,629			138,733			(1,222,362		)	(693,604		)
		5,152,090			5,916,939			2,632,656			(8,540,562		)	5,161,123
	Total liabilities and unitholders’ capital	$	12,786,181		$	10,919,721		$	5,270,345		$	(12,707,583	)	$	16,268,664
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-13
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	52		$	1,078		$	51,041		$	—		$	52,171
	Accounts receivable – trade, net	—			365,347			122,855			—			488,202
	Accounts receivable – affiliates	4,212,348			16,950			—			(4,229,298		)	—
	Derivative instruments	—			170,534			5,596			—			176,130
	Other current assets	330			68,274			30,833			—			99,437
	Total current assets	4,212,730			622,183			210,325			(4,229,298		)	815,940
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	—			13,074,900			4,813,659			—			17,888,559
Less accumulated depletion and amortization	—			(3,535,890		)	(10,394		)	—			(3,546,284		)
	—			9,539,010			4,803,265			—			14,342,275
Other property and equipment	—			564,756			83,126			—			647,882
Less accumulated depreciation	—			(110,706		)	(233		)	—			(110,939		)
	—			454,050			82,893			—			536,943
Derivative instruments	—			679,491			2,511			—			682,002
Notes receivable – affiliates	86,200			—			—			(86,200		)	—
Investments in consolidated subsidiaries	8,433,290			—			—			(8,433,290		)	—
Other noncurrent assets, net	108,785			10,968			8,051			—			127,804
	8,628,275			690,459			10,562			(8,519,490		)	809,806
Total noncurrent assets	8,628,275			10,683,519			4,896,720			(8,519,490		)	15,689,024
Total assets	$	12,841,005		$	11,305,702		$	5,107,045		$	(12,748,788	)	$	16,504,964
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	14,529		$	587,774		$	247,321		$	—		$	849,624
Accounts payable – affiliates	—			4,212,348			16,950			(4,229,298		)	—
Derivative instruments	—			7,783			20,393			—			28,176
Other accrued liabilities	75,071			59,311			28,993			—			163,375
Current portion of long-term debt	—			—			211,558			—			211,558
Total current liabilities	89,600			4,867,216			525,215			(4,229,298		)	1,252,733
Noncurrent liabilities:
Credit facilities	1,560,000			—			1,173,175			—			2,733,175
Term loan	500,000			—			—			—			500,000
Senior notes, net	4,809,055			—			916,428			—			5,725,483
Notes payable – affiliates	—			86,200			—			(86,200		)	—
Derivative instruments	—			—			4,649			—			4,649
Other noncurrent liabilities	—			205,406			192,091			—			397,497
Total noncurrent liabilities	6,869,055			291,606			2,286,343			(86,200		)	9,360,804
Unitholders’ capital:
Units issued and outstanding	6,282,747			4,833,354			2,315,460			(7,139,737		)	6,291,824
Accumulated income (deficit)	(400,397		)	1,313,526			(19,973		)	(1,293,553		)	(400,397		)
	5,882,350			6,146,880			2,295,487			(8,433,290		)	5,891,427
Total liabilities and unitholders’ capital	$	12,841,005		$	11,305,702		$	5,107,045		$	(12,748,788	)	$	16,504,964
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended June 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	607,470		$	360,380		$	—		$	967,850
Losses on oil and natural gas derivatives	—			(383,226		)	(25,562		)	—			(408,788		)
Marketing revenues	—			17,839			12,434			—			30,273
Other revenues	—			7,607			9			—			7,616
	—			249,690			347,261			—			596,951
Expenses:
Lease operating expenses	—			91,547			93,354			—			184,901
Transportation expenses	—			37,371			7,483			—			44,854
Marketing expenses	—			13,549			9,725			—			23,274
General and administrative expenses	—			38,584			28,322			—			66,906
Exploration costs	—			1,551			—			—			1,551
Depreciation, depletion and amortization	—			196,682			77,753			—			274,435
Taxes, other than income taxes	—			45,052			23,479			—			68,531
Losses on sale of assets and other, net	—			1,210			4,257			—			5,467
	—			425,546			244,373			—			669,919
Other income and (expenses):
Interest expense, net of amounts capitalized	(111,603		)	789			(23,486		)	—			(134,300		)
Interest expense – affiliates	—			(1,859		)	—			1,859			—
Interest income – affiliates	1,859			—			—			(1,859		)	—
Equity in losses from consolidated subsidiaries	(96,084		)	—			—			96,084			—
Other, net	(2,042		)	(62		)	(445		)	—			(2,549		)
	(207,870		)	(1,132		)	(23,931		)	96,084			(136,849		)
Income (loss) before income taxes	(207,870		)	(176,988		)	78,957			96,084			(209,817		)
Income tax benefit	—			(1,896		)	(51		)	—			(1,947		)
Net income (loss)	$	(207,870	)	$	(175,092	)	$	79,008		$	96,084		$	(207,870	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended June 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	488,207		$	—		$	—		$	488,207
Gains on oil and natural gas derivatives	—			326,733			—			—			326,733
Marketing revenues	—			17,222			—			—			17,222
Other revenues	—			6,663			—			—			6,663
	—			838,825			—			—			838,825
Expenses:
Lease operating expenses	—			83,584			—			—			83,584
Transportation expenses	—			29,298			—			—			29,298
Marketing expenses	—			9,360			—			—			9,360
General and administrative expenses	—			46,305			—			—			46,305
Exploration costs	—			818			—			—			818
Depreciation, depletion and amortization	—			198,629			—			—			198,629
Impairment of long-lived assets	—			(14,851		)	—			—			(14,851		)
Taxes, other than income taxes	—			32,397			—			—			32,397
Gains on sale of assets and other, net	—			(959		)	—			—			(959		)
	—			384,581			—			—			384,581
Other income and (expenses):
Interest expense, net of amounts capitalized	(103,207		)	(640		)	—			—			(103,847		)
Interest expense – affiliates	—			(1,412		)	—			1,412			—
Interest income – affiliates	1,412			—			—			(1,412		)	—
Loss on extinguishment of debt	(4,187		)	—			—			—			(4,187		)
Equity in earnings from consolidated subsidiaries	453,288			—			—			(453,288		)	—
Other, net	(2,149		)	(33		)	—			—			(2,182		)
	345,157			(2,085		)	—			(453,288		)	(110,216		)
Income before income taxes	345,157			452,159			—			(453,288		)	344,028
Income tax benefit	—			(1,129		)	—			—			(1,129		)
Net income	$	345,157		$	453,288		$	—		$	(453,288	)	$	345,157
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Six Months Ended June 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	1,213,231		$	693,496		$	—		$	1,906,727
Losses on oil and natural gas derivatives	—			(628,184		)	(22,097		)	—			(650,281		)
Marketing revenues	—			33,570			27,249			—			60,819
Other revenues	—			13,280			(7		)	—			13,273
	—			631,897			698,641			—			1,330,538
Expenses:
Lease operating expenses	—			195,549			183,385			—			378,934
Transportation expenses	—			75,008			15,476			—			90,484
Marketing expenses	—			23,640			20,706			—			44,346
General and administrative expenses	—			74,321			71,813			—			146,134
Exploration costs	—			2,642			—			—			2,642
Depreciation, depletion and amortization	—			395,852			146,384			—			542,236
Taxes, other than income taxes	—			87,736			46,508			—			134,244
Losses on sale of assets and other, net	—			429			7,624			—			8,053
	—			855,177			491,896			—			1,347,073
Other income and (expenses):
Interest expense, net of amounts capitalized	(221,253		)	627			(47,487		)	—			(268,113		)
Interest expense – affiliates	—			(3,409		)	—			3,409			—
Interest income – affiliates	3,409			—			—			(3,409		)	—
Equity in losses from consolidated subsidiaries	(71,191		)	—			—			71,191			—
Other, net	(4,172		)	(46		)	(634		)	—			(4,852		)
	(293,207		)	(2,828		)	(48,121		)	71,191			(272,965		)
Income (loss) before income taxes	(293,207		)	(226,108		)	158,624			71,191			(289,500		)
Income tax expense (benefit)	—			3,789			(82		)	—			3,707
Net income (loss)	$	(293,207	)	$	(229,897	)	$	158,706		$	71,191		$	(293,207	)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Six Months Ended June 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	950,939		$	—		$	—		$	950,939
Gains on oil and natural gas derivatives	—			218,363			—			—			218,363
Marketing revenues	—			27,074			—			—			27,074
Other revenues	—			11,509			—			—			11,509
	—			1,207,885			—			—			1,207,885
Expenses:
Lease operating expenses	—			172,305			—			—			172,305
Transportation expenses	—			56,481			—			—			56,481
Marketing expenses	—			16,734			—			—			16,734
General and administrative expenses	—			104,871			—			—			104,871
Exploration costs	—			3,044			—			—			3,044
Depreciation, depletion and amortization	—			396,070			—			—			396,070
Impairment of long-lived assets	—			42,202			—			—			42,202
Taxes, other than income taxes	—			72,068			—			—			72,068
Losses on sale of assets and other, net	724			1,489			—			—			2,213
	724			865,264			—			—			865,988
Other income and (expenses):
Interest expense, net of amounts capitalized	(204,064		)	(142		)	—			—			(204,206		)
Interest expense – affiliates	—			(2,554		)	—			2,554			—
Interest income – affiliates	2,554			—			—			(2,554		)	—
Loss on extinguishment of debt	(4,187		)	—			—			—			(4,187		)
Equity in earnings from consolidated subsidiaries	333,469			—			—			(333,469		)	—
Other, net	(3,776		)	(49		)	—			—			(3,825		)
	123,996			(2,745		)	—			(333,469		)	(212,218		)
Income before income taxes	123,272			339,876			—			(333,469		)	129,679
Income tax expense	—			6,407			—			—			6,407
Net income	$	123,272		$	333,469		$	—		$	(333,469	)	$	123,272
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2014
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from operating activities:
Net income (loss)	$	(293,207	)	$	(229,897	)	$	158,706		$	71,191		$	(293,207	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	—			395,852			146,384			—			542,236
Unit-based compensation expenses	—			32,583			—			—			32,583
Amortization and write-off of deferred financing fees	11,694			—			(5,492		)	—			6,202
Losses on sale of assets and other, net	—			3,506			—			—			3,506
Equity in losses from consolidated subsidiaries	71,191			—			—			(71,191		)	—
Deferred income taxes	—			3,557			(82		)	—			3,475
Derivatives activities:
Total losses	—			628,184			22,097			—			650,281
Cash settlements	—			(12,651		)	(10,472		)	—			(23,123		)
Changes in assets and liabilities:
Increase in accounts receivable – trade, net	—			(27,597		)	(34,294		)	—			(61,891		)
(Increase) decrease in accounts receivable – affiliates	220,694			(9,964		)	—			(210,730		)	—
(Increase) decrease in other assets	(146		)	(8,287		)	1,486			—			(6,947		)
Increase in accounts payable and accrued expenses	2			111,675			1,905			—			113,582
Increase (decrease) in accounts payable and accrued expenses – affiliates	—			(220,694		)	9,964			210,730			—
Increase (decrease) in other liabilities	702			(26,291		)	(25,473		)	—			(51,062		)
Net cash provided by operating activities	10,930			639,976			264,729			—			915,635
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(25,891		)	—			—			(25,891		)
Development of oil and natural gas properties	—			(536,488		)	(269,129		)	—			(805,617		)
Purchases of other property and equipment	—			(25,786		)	(5,625		)	—			(31,411		)
Investment in affiliates	(178,463		)	—			—			178,463			—
Change in notes receivable with affiliate	(28,200		)	—			—			28,200			—
Proceeds from sale of properties and equipment and other	(12,983		)	1,253			—			—			(11,730		)
Net cash used in investing activities	(219,646		)	(586,912		)	(274,754		)	206,663			(874,649		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from borrowings	1,095,000			—			—			—			1,095,000
Repayments of debt	(410,000		)	—			(206,124		)	—			(616,124		)
Distributions to unitholders	(480,583		)	—			—			—			(480,583		)
Financing fees and other, net	1,263			(46,524		)	(10,866		)	—			(56,127		)
Change in notes payable with affiliate	—			28,200			—			(28,200		)	—
Capital contributions – affiliates	—			—			178,463			(178,463		)	—
Excess tax benefit from unit-based compensation	3,016			—			—			—			3,016
Net cash provided by (used in) financing activities	208,696			(18,324		)	(38,527		)	(206,663		)	(54,818		)
Net increase (decrease) in cash and cash equivalents	(20		)	34,740			(48,552		)	—			(13,832		)
Cash and cash equivalents:
Beginning	52			1,078			51,041			—			52,171
Ending	$	32		$	35,818		$	2,489		$	—		$	38,339
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2013
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from operating activities:
Net income	$	123,272		$	333,469		$	—		$	(333,469	)	$	123,272
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	—			396,070			—			—			396,070
Impairment of long-lived assets	—			42,202			—			—			42,202
Unit-based compensation expenses	—			19,575			—			—			19,575
Loss on extinguishment of debt	4,187			—			—			—			4,187
Amortization and write-off of deferred financing fees	10,905			—			—			—			10,905
Losses on sale of assets and other, net	—			16,814			—			—			16,814
Equity in earnings from consolidated subsidiaries	(333,469		)	—			—			333,469			—
Deferred income taxes	—			5,725			—			—			5,725
Derivatives activities:
Total gains	—			(218,363		)	—			—			(218,363		)
Cash settlements	—			144,502			—			—			144,502
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	—			36,174			—			—			36,174
Decrease in accounts receivable – affiliates	366,386			—			—			(366,386		)	—
(Increase) decrease in other assets	(100		)	2,360			—			—			2,260
Decrease in accounts payable and accrued expenses	—			(5,319		)	—			—			(5,319		)
Decrease in accounts payable and accrued expenses – affiliates	—			(366,386		)	—			366,386			—
Increase (decrease) in other liabilities	771			(17,419		)	—			—			(16,648		)
Net cash provided by operating activities	171,952			389,404			—			—			561,356
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(64,381		)	—			—			(64,381		)
Development of oil and natural gas properties	—			(495,899		)	—			—			(495,899		)
Purchases of other property and equipment	—			(55,147		)	—			—			(55,147		)
Change in notes receivable with affiliate	(27,400		)	—			—			27,400			—
Proceeds from sale of properties and equipment and other	(8,409		)	219,308			—			—			210,899
Net cash used in investing activities	(35,809		)	(396,119		)	—			27,400			(404,528		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from borrowings	775,000			—			—			—			775,000
Repayments of debt	(560,737		)	—			—			—			(560,737		)
Distributions to unitholders	(341,117		)	—			—			—			(341,117		)
Financing fees and other, net	(9,366		)	(21,290		)	—			—			(30,656		)
Change in notes payable with affiliate	—			27,400			—			(27,400		)	—
Excess tax benefit from unit-based compensation	—			591			—			—			591
Net cash provided by (used in) financing activities	(136,220		)	6,701			—			(27,400		)	(156,919		)
Net decrease in cash and cash equivalents	(77		)	(14		)	—			—			(91		)
Cash and cash equivalents:
Beginning	107			1,136			—			—			1,243
Ending	$	30		$	1,122		$	—		$	—		$	1,152

SEC_Inquiry

SEC Inquiry	6 Months Ended
	Jun. 30, 2014
SEC Inquiry [Abstract]	'
SEC Inquiry	'
	SEC Inquiry
	As disclosed on July 1, 2013, the Company and its affiliate, LinnCo, have been notified by the staff of the SEC that its Fort Worth Regional Office has commenced an inquiry regarding LINN Energy and LinnCo (the “SEC inquiry”). The SEC staff is investigating whether any violations of federal securities laws have occurred. The SEC staff has stated that the fact of the inquiry should not be construed as an indication that the SEC or its staff has a negative view of any entity, individual or security. Both LINN Energy and LinnCo are cooperating fully with the SEC in this matter. LINN Energy and LinnCo are unable to predict the timing or outcome of the SEC inquiry or estimate the nature or amount of any possible sanction the SEC could seek to impose, which could include a fine, penalty, or court or administrative order prohibiting specific conduct, or a potential restatement of LINN Energy’s or LinnCo’s financial statements, any of which could be material. No provision for losses has been recorded for this exposure.

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Principles of Consolidation and Reporting	'
	Principles of Consolidation and Reporting
	The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The Company’s other investment is accounted for at cost.
	The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ capital or cash flows.
Use of Estimates	'
	Use of Estimates
	The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.

Acquisitions_JointVenture_Fund1

Acquisitions, Joint-Venture Funding and Divestitures (Tables)	6 Months Ended
	Jun. 30, 2013
Business Combinations [Abstract]	'
Schedule of Pro Forma Results of Business Combination	'
	The following unaudited pro forma financial information presents a summary of the Company’s consolidated results of operations for the three months and six months ended June 30, 2013, assuming the Berry acquisition had been completed as of January 1, 2013, including adjustments to reflect the values assigned to the net assets acquired:
		Three Months Ended		Six Months Ended
		30-Jun-13		30-Jun-13
		(in thousands, except
		per unit amounts)
	Total revenues and other	$	1,161,137	$	1,806,346
	Total operating expenses	$	586,909	$	1,256,821
	Net income	$	441,935	$	284,615
	Net income per unit:
	Basic	$	1.34	$	0.86
	Diluted	$	1.34	$	0.86

Oil_and_Natural_Gas_Properties1

Oil and Natural Gas Properties (Tables)	6 Months Ended
	Jun. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities	'
	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Proved properties:
	Leasehold acquisition	$	12,329,359		$	12,277,089
	Development	4,468,702			3,660,277
	Unproved properties	1,886,148			1,951,193
		18,684,209			17,888,559
	Less accumulated depletion and amortization	(4,051,761		)	(3,546,284		)
		$	14,632,448		$	14,342,275

UnitBased_Compensation_Tables

Unit-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Employee Service Share-Based Compensation Expense	'
	A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	General and administrative expenses	$	9,496	$	7,136	$	27,719	$	17,001
	Lease operating expenses	1,587		1,177		4,864		2,574
	Total unit-based compensation expenses	$	11,083	$	8,313	$	32,583	$	19,575
	Income tax benefit	$	4,095	$	3,072	$	12,039	$	7,233

Debt_Tables

Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Summary of Outstanding Debt	'
	The following summarizes the Company’s outstanding debt:
		June 30,			31-Dec-13
		2014
		(in thousands, except percentages)
	LINN credit facility (1)	$	2,245,000		$	1,560,000
	Berry credit facility (2)	1,173,175			1,173,175
	Term loan (3)	500,000			500,000
	10.25% Berry senior notes due June 2014	—			205,257
	6.50% senior notes due May 2019	750,000			750,000
	6.25% senior notes due November 2019	1,800,000			1,800,000
	8.625% senior notes due April 2020	1,300,000			1,300,000
	6.75% Berry senior notes due November 2020	299,970			300,000
	7.75% senior notes due February 2021	1,000,000			1,000,000
	6.375% Berry senior notes due September 2022	599,163			600,000
	Net unamortized discounts and premiums	(22,957		)	(18,216		)
	Total debt, net	9,644,351			9,170,216
	Less current maturities	—			(211,558		)
	Total long-term debt, net	$	9,644,351		$	8,958,658
	(1)	Variable interest rates of 1.90% and 1.92% at June 30, 2014, and December 31, 2013, respectively.
	(2)	Variable interest rates of 2.66% and 2.67% at June 30, 2014, and December 31, 2013, respectively.
	(3)	Variable interest rates of 2.65% and 2.67% at June 30, 2014, and December 31, 2013, respectively.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	'
		30-Jun-14						December 31, 2013
		Carrying Value			Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit Facilities	$	3,418,175		$	3,418,175		$	2,733,175	$	2,733,175
	Term loan	500,000			500,000			500,000		500,000
	Senior notes, net	5,726,176			6,091,525			5,937,041		6,162,402
	Total debt, net	$	9,644,351		$	10,009,700		$	9,170,216	$	9,395,577

Derivatives_Tables

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments	'
	The following table summarizes derivative positions for the periods indicated as of June 30, 2014:
		July 1 - December 31, 2014			2015			2016			2017			2018
	Natural gas positions:
	Fixed price swaps (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	49,100			118,041			121,841			120,122			36,500
	Average price ($/MMBtu)	$	5.25		$	5.19		$	4.2		$	4.26		$	5
	Put options (NYMEX Henry Hub):
	Hedged volume (MMMBtu)	40,141			71,854			76,269			66,886			—
	Average price ($/MMBtu)	$	5		$	5		$	5		$	4.88		$	—
	Oil positions:
	Fixed price swaps (NYMEX WTI): (1)
	Hedged volume (MBbls)	8,485			11,599			11,465			4,755			—
	Average price ($/Bbl)	$	92.44		$	96.23		$	90.56		$	89.02		$	—
	Collars (NYMEX WTI):
	Hedged volume (MBbls)	368			—			—			—			—
	Average floor price ($/Bbl)	$	90		$	—		$	—		$	—		$	—
	Average ceiling price ($/Bbl)	$	102.87		$	—		$	—		$	—		$	—
	Three-way collars (NYMEX WTI):
	Hedged volume (MBbls)	1,564			1,095			—			—			—
	Short put ($/Bbl)	$	72.11		$	70		$	—		$	—		$	—
	Long put ($/Bbl)	$	93.76		$	90		$	—		$	—		$	—
	Short call ($/Bbl)	$	109.79		$	101.62		$	—		$	—		$	—
		July 1 - December 31, 2014			2015			2016			2017			2018
	Put options (NYMEX WTI):
	Hedged volume (MBbls)	1,996			3,426			3,271			384			—
	Average price ($/Bbl)	$	91.3		$	90		$	90		$	90		$	—
	Three-way collars (ICE Brent):
	Hedged volume (MBbls)	184			—			—			—			—
	Short put ($/Bbl)	$	80		$	—		$	—		$	—		$	—
	Long put ($/Bbl)	$	100		$	—		$	—		$	—		$	—
	Short call ($/Bbl)	$	114.05		$	—		$	—		$	—		$	—
	Natural gas basis differential positions: (2)
	Panhandle basis swaps:
	Hedged volume (MMMBtu)	40,020			87,162			59,954			59,138			16,425
	Hedged differential ($/MMBtu)	$	(0.33	)	$	(0.33	)	$	(0.32	)	$	(0.33	)	$	(0.33	)
	NWPL Rockies basis swaps:
	Hedged volume (MMMBtu)	20,619			43,292			46,294			38,880			10,804
	Hedged differential ($/MMBtu)	$	(0.20	)	$	(0.20	)	$	(0.20	)	$	(0.19	)	$	(0.19	)
	MichCon basis swaps:
	Hedged volume (MMMBtu)	4,784			9,344			7,768			7,437			2,044
	Hedged differential ($/MMBtu)	$	0.08		$	0.06		$	0.05		$	0.05		$	0.05
	Houston Ship Channel basis swaps:
	Hedged volume (MMMBtu)	2,650			4,891			4,575			3,604			986
	Hedged differential ($/MMBtu)	$	(0.10	)	$	(0.10	)	$	(0.10	)	$	(0.08	)	$	(0.08	)
	Permian basis swaps:
	Hedged volume (MMMBtu)	2,466			5,074			4,219			4,819			1,314
	Hedged differential ($/MMBtu)	$	(0.21	)	$	(0.21	)	$	(0.20	)	$	(0.20	)	$	(0.20	)
	Oil basis differential positions:
	ICE Brent - NYMEX WTI basis swaps:
	Hedged volume (MBbls)	1,840			2,920			—			—			—
	Hedged differential ($/Bbl)	$	11.6		$	11.6		$	—		$	—		$	—
	Oil timing differential positions:
	Trade month roll swaps (NYMEX WTI): (3)
	Hedged volume (MBbls)	4,577			7,251			7,446			6,486			—
	Hedged differential ($/Bbl)	$	0.24		$	0.24		$	0.25		$	0.25		$	—
	(1)	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
	(2)	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
	(3)	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).
Fair Value of Derivatives Outstanding on a Gross Basis by Location on the Balance Sheet	'
	The following summarizes the fair value of derivatives outstanding on a gross basis:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Assets:
	Commodity derivatives	$	551,636		$	1,048,212
	Liabilities:
	Commodity derivatives	$	353,222		$	222,905

Fair_Value_Measurements_on_a_R1

Fair Value Measurements on a Recurring Basis (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Recurring Basis	'
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		30-Jun-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	551,636	$	(284,488	)	$	267,148
	Liabilities:
	Commodity derivatives	$	353,222	$	(284,488	)	$	68,734
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	1,048,212	$	(190,080	)	$	858,132
	Liabilities:
	Commodity derivatives	$	222,905	$	(190,080	)	$	32,825
	(1)	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations Reconciliation	'
	The following presents a reconciliation of the asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	289,321
	Liabilities added from drilling	5,673
	Current year accretion expense	9,570
	Settlements	(9,947		)
	Revision of estimates	9,130
	Asset retirement obligations at June 30, 2014	$	303,747

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Reconciliation of numerators and denominators of the basic and diluted per unit computations for net income (loss)	'
	The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net income (loss):
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(in thousands, except per unit data)
	Net income (loss)	$	(207,870	)	$	345,157		$	(293,207	)	$	123,272
	Allocated to participating securities	(2,154		)	(2,629		)	(4,306		)	(2,599		)
		$	(210,024	)	$	342,528		$	(297,513	)	$	120,673
	Basic net income (loss) per unit	$	(0.64	)	$	1.47		$	(0.91	)	$	0.52
	Diluted net income (loss) per unit	$	(0.64	)	$	1.46		$	(0.91	)	$	0.52
	Basic weighted average units outstanding	328,844			233,448			328,588			233,313
	Dilutive effect of unit equivalents	—			462			—			487
	Diluted weighted average units outstanding	328,844			233,910			328,588			233,800

Supplemental_Disclosures_to_th1

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Tables)	6 Months Ended
	Jun. 30, 2014
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'
Other Accrued Liabilities	'
	“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Accrued compensation	$	31,702		$	55,257
	Accrued interest	92,019			93,998
	Asset retirement obligations	12,616			6,270
	Other	2,041			7,850
		$	138,378		$	163,375
Supplemental Disclosures to the Condensed Conslidated Statements of Cash Flow	'
	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below:
		Six Months Ended
		June 30,
		2014			2013
		(in thousands)
	Cash payments for interest, net of amounts capitalized	$	264,141		$	192,517
	Cash payments for income taxes	$	—		$	14
	Noncash investing activities:
	In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:
	Fair value of assets acquired	$	4,242		$	7,655
	Cash (paid) received	(1,139		)	3,231
	Receivables from sellers	—			1,792
	Payables to sellers	—			(6,854		)
	Liabilities assumed	$	3,103		$	5,824

Subsidiary_Guarantors_Tables

Subsidiary Guarantors (Tables)	6 Months Ended
	Jun. 30, 2014
Condensed Financial Information [Abstract]	'
Condensed Consolidating Balance Sheet	'
	CONDENSED CONSOLIDATING BALANCE SHEETS
	June 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	32		$	35,818		$	2,489		$	—		$	38,339
	Accounts receivable – trade, net	—			393,012			156,577			—			549,589
	Accounts receivable – affiliates	4,025,707			26,914			—			(4,052,621		)	—
	Derivative instruments	—			89,541			2,070			—			91,611
	Other current assets	476			77,171			30,235			—			107,882
	Total current assets	4,026,215			622,456			191,371			(4,052,621		)	787,421
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,558,084			5,126,125			—			18,684,209
	Less accumulated depletion and amortization	—			(3,901,130		)	(150,631		)	—			(4,051,761		)
		—			9,656,954			4,975,494			—			14,632,448
	Other property and equipment	—			586,438			89,856			—			676,294
	Less accumulated depreciation	—			(131,526		)	(3,790		)	—			(135,316		)
		—			454,912			86,066			—			540,978
	Derivative instruments	—			174,327			1,210			—			175,537
	Notes receivable – affiliates	114,400			—			—			(114,400		)	—
	Investments in consolidated subsidiaries	8,540,562			—			—			(8,540,562		)	—
	Other noncurrent assets, net	105,004			11,072			16,204			—			132,280
		8,759,966			185,399			17,414			(8,654,962		)	307,817
	Total noncurrent assets	8,759,966			10,297,265			5,078,974			(8,654,962		)	15,481,243
	Total assets	$	12,786,181		$	10,919,721		$	5,270,345		$	(12,707,583	)	$	16,268,664
	LIABILITIES AND UNITHOLDERS’ CAPITAL
	Current liabilities:
	Accounts payable and accrued expenses	$	1,822		$	570,680		$	287,669		$	—		$	860,171
	Accounts payable – affiliates	—			4,026,182			26,439			(4,052,621		)	—
	Derivative instruments	—			28,332			31,575			—			59,907
	Other accrued liabilities	75,773			43,045			19,560			—			138,378
	Total current liabilities	77,595			4,668,239			365,243			(4,052,621		)	1,058,456
	Noncurrent liabilities:
	Credit facilities	2,245,000			—			1,173,175			—			3,418,175
	Term loan	500,000			—			—			—			500,000
	Senior notes, net	4,811,496			—			914,680			—			5,726,176
	Notes payable – affiliates	—			114,400			—			(114,400		)	—
	Derivative instruments	—			8,827			—			—			8,827
	Other noncurrent liabilities	—			211,316			184,591			—			395,907
	Total noncurrent liabilities	7,556,496			334,543			2,272,446			(114,400		)	10,049,085
	Unitholders’ capital:
	Units issued and outstanding	5,845,694			4,833,310			2,493,923			(7,318,200		)	5,854,727
	Accumulated income (deficit)	(693,604		)	1,083,629			138,733			(1,222,362		)	(693,604		)
		5,152,090			5,916,939			2,632,656			(8,540,562		)	5,161,123
	Total liabilities and unitholders’ capital	$	12,786,181		$	10,919,721		$	5,270,345		$	(12,707,583	)	$	16,268,664
	CONDENSED CONSOLIDATING BALANCE SHEETS
	31-Dec-13
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	52		$	1,078		$	51,041		$	—		$	52,171
	Accounts receivable – trade, net	—			365,347			122,855			—			488,202
	Accounts receivable – affiliates	4,212,348			16,950			—			(4,229,298		)	—
	Derivative instruments	—			170,534			5,596			—			176,130
	Other current assets	330			68,274			30,833			—			99,437
	Total current assets	4,212,730			622,183			210,325			(4,229,298		)	815,940
	Noncurrent assets:
	Oil and natural gas properties (successful efforts method)	—			13,074,900			4,813,659			—			17,888,559
	Less accumulated depletion and amortization	—			(3,535,890		)	(10,394		)	—			(3,546,284		)
	—			9,539,010			4,803,265			—			14,342,275
Other property and equipment	—			564,756			83,126			—			647,882
Less accumulated depreciation	—			(110,706		)	(233		)	—			(110,939		)
	—			454,050			82,893			—			536,943
Derivative instruments	—			679,491			2,511			—			682,002
Notes receivable – affiliates	86,200			—			—			(86,200		)	—
Investments in consolidated subsidiaries	8,433,290			—			—			(8,433,290		)	—
Other noncurrent assets, net	108,785			10,968			8,051			—			127,804
	8,628,275			690,459			10,562			(8,519,490		)	809,806
Total noncurrent assets	8,628,275			10,683,519			4,896,720			(8,519,490		)	15,689,024
Total assets	$	12,841,005		$	11,305,702		$	5,107,045		$	(12,748,788	)	$	16,504,964
LIABILITIES AND UNITHOLDERS’ CAPITAL
Current liabilities:
Accounts payable and accrued expenses	$	14,529		$	587,774		$	247,321		$	—		$	849,624
Accounts payable – affiliates	—			4,212,348			16,950			(4,229,298		)	—
Derivative instruments	—			7,783			20,393			—			28,176
Other accrued liabilities	75,071			59,311			28,993			—			163,375
Current portion of long-term debt	—			—			211,558			—			211,558
Total current liabilities	89,600			4,867,216			525,215			(4,229,298		)	1,252,733
Noncurrent liabilities:
Credit facilities	1,560,000			—			1,173,175			—			2,733,175
Term loan	500,000			—			—			—			500,000
Senior notes, net	4,809,055			—			916,428			—			5,725,483
Notes payable – affiliates	—			86,200			—			(86,200		)	—
Derivative instruments	—			—			4,649			—			4,649
Other noncurrent liabilities	—			205,406			192,091			—			397,497
Total noncurrent liabilities	6,869,055			291,606			2,286,343			(86,200		)	9,360,804
Unitholders’ capital:
Units issued and outstanding	6,282,747			4,833,354			2,315,460			(7,139,737		)	6,291,824
Accumulated income (deficit)	(400,397		)	1,313,526			(19,973		)	(1,293,553		)	(400,397		)
	5,882,350			6,146,880			2,295,487			(8,433,290		)	5,891,427
Total liabilities and unitholders’ capital	$	12,841,005		$	11,305,702		$	5,107,045		$	(12,748,788	)	$	16,504,964
Condensed Consolidating Statements of Operations	'
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Six Months Ended June 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	1,213,231		$	693,496		$	—		$	1,906,727
	Losses on oil and natural gas derivatives	—			(628,184		)	(22,097		)	—			(650,281		)
	Marketing revenues	—			33,570			27,249			—			60,819
	Other revenues	—			13,280			(7		)	—			13,273
		—			631,897			698,641			—			1,330,538
	Expenses:
	Lease operating expenses	—			195,549			183,385			—			378,934
	Transportation expenses	—			75,008			15,476			—			90,484
	Marketing expenses	—			23,640			20,706			—			44,346
	General and administrative expenses	—			74,321			71,813			—			146,134
	Exploration costs	—			2,642			—			—			2,642
	Depreciation, depletion and amortization	—			395,852			146,384			—			542,236
	Taxes, other than income taxes	—			87,736			46,508			—			134,244
	Losses on sale of assets and other, net	—			429			7,624			—			8,053
		—			855,177			491,896			—			1,347,073
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(221,253		)	627			(47,487		)	—			(268,113		)
	Interest expense – affiliates	—			(3,409		)	—			3,409			—
	Interest income – affiliates	3,409			—			—			(3,409		)	—
	Equity in losses from consolidated subsidiaries	(71,191		)	—			—			71,191			—
	Other, net	(4,172		)	(46		)	(634		)	—			(4,852		)
		(293,207		)	(2,828		)	(48,121		)	71,191			(272,965		)
	Income (loss) before income taxes	(293,207		)	(226,108		)	158,624			71,191			(289,500		)
	Income tax expense (benefit)	—			3,789			(82		)	—			3,707
	Net income (loss)	$	(293,207	)	$	(229,897	)	$	158,706		$	71,191		$	(293,207	)
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	For the Six Months Ended June 30, 2013
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Revenues and other:
	Oil, natural gas and natural gas liquids sales	$	—		$	950,939		$	—		$	—		$	950,939
	Gains on oil and natural gas derivatives	—			218,363			—			—			218,363
	Marketing revenues	—			27,074			—			—			27,074
	Other revenues	—			11,509			—			—			11,509
		—			1,207,885			—			—			1,207,885
	Expenses:
	Lease operating expenses	—			172,305			—			—			172,305
	Transportation expenses	—			56,481			—			—			56,481
	Marketing expenses	—			16,734			—			—			16,734
	General and administrative expenses	—			104,871			—			—			104,871
	Exploration costs	—			3,044			—			—			3,044
	Depreciation, depletion and amortization	—			396,070			—			—			396,070
	Impairment of long-lived assets	—			42,202			—			—			42,202
	Taxes, other than income taxes	—			72,068			—			—			72,068
	Losses on sale of assets and other, net	724			1,489			—			—			2,213
		724			865,264			—			—			865,988
	Other income and (expenses):
	Interest expense, net of amounts capitalized	(204,064		)	(142		)	—			—			(204,206		)
	Interest expense – affiliates	—			(2,554		)	—			2,554			—
	Interest income – affiliates	2,554			—			—			(2,554		)	—
	Loss on extinguishment of debt	(4,187		)	—			—			—			(4,187		)
	Equity in earnings from consolidated subsidiaries	333,469			—			—			(333,469		)	—
	Other, net	(3,776		)	(49		)	—			—			(3,825		)
		123,996			(2,745		)	—			(333,469		)	(212,218		)
	Income before income taxes	123,272			339,876			—			(333,469		)	129,679
	Income tax expense	—			6,407			—			—			6,407
Net income	$	123,272		$	333,469		$	—		$	(333,469	)	$	123,272
Condensed Consolidating Statements of Cash Flows	'
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Six Months Ended June 30, 2014
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from operating activities:
	Net income (loss)	$	(293,207	)	$	(229,897	)	$	158,706		$	71,191		$	(293,207	)
	Adjustments to reconcile net loss to net cash provided by operating activities:
	Depreciation, depletion and amortization	—			395,852			146,384			—			542,236
	Unit-based compensation expenses	—			32,583			—			—			32,583
	Amortization and write-off of deferred financing fees	11,694			—			(5,492		)	—			6,202
	Losses on sale of assets and other, net	—			3,506			—			—			3,506
	Equity in losses from consolidated subsidiaries	71,191			—			—			(71,191		)	—
	Deferred income taxes	—			3,557			(82		)	—			3,475
	Derivatives activities:
	Total losses	—			628,184			22,097			—			650,281
	Cash settlements	—			(12,651		)	(10,472		)	—			(23,123		)
	Changes in assets and liabilities:
	Increase in accounts receivable – trade, net	—			(27,597		)	(34,294		)	—			(61,891		)
	(Increase) decrease in accounts receivable – affiliates	220,694			(9,964		)	—			(210,730		)	—
	(Increase) decrease in other assets	(146		)	(8,287		)	1,486			—			(6,947		)
	Increase in accounts payable and accrued expenses	2			111,675			1,905			—			113,582
	Increase (decrease) in accounts payable and accrued expenses – affiliates	—			(220,694		)	9,964			210,730			—
	Increase (decrease) in other liabilities	702			(26,291		)	(25,473		)	—			(51,062		)
	Net cash provided by operating activities	10,930			639,976			264,729			—			915,635
	Cash flow from investing activities:
	Acquisition of oil and natural gas properties and joint-venture funding	—			(25,891		)	—			—			(25,891		)
	Development of oil and natural gas properties	—			(536,488		)	(269,129		)	—			(805,617		)
	Purchases of other property and equipment	—			(25,786		)	(5,625		)	—			(31,411		)
	Investment in affiliates	(178,463		)	—			—			178,463			—
	Change in notes receivable with affiliate	(28,200		)	—			—			28,200			—
	Proceeds from sale of properties and equipment and other	(12,983		)	1,253			—			—			(11,730		)
	Net cash used in investing activities	(219,646		)	(586,912		)	(274,754		)	206,663			(874,649		)
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from financing activities:
	Proceeds from borrowings	1,095,000			—			—			—			1,095,000
	Repayments of debt	(410,000		)	—			(206,124		)	—			(616,124		)
	Distributions to unitholders	(480,583		)	—			—			—			(480,583		)
	Financing fees and other, net	1,263			(46,524		)	(10,866		)	—			(56,127		)
	Change in notes payable with affiliate	—			28,200			—			(28,200		)	—
	Capital contributions – affiliates	—			—			178,463			(178,463		)	—
	Excess tax benefit from unit-based compensation	3,016			—			—			—			3,016
	Net cash provided by (used in) financing activities	208,696			(18,324		)	(38,527		)	(206,663		)	(54,818		)
	Net increase (decrease) in cash and cash equivalents	(20		)	34,740			(48,552		)	—			(13,832		)
	Cash and cash equivalents:
	Beginning	52			1,078			51,041			—			52,171
	Ending	$	32		$	35,818		$	2,489		$	—		$	38,339
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	For the Six Months Ended June 30, 2013
		LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
								Guarantor Subsidiary
		(in thousands)
	Cash flow from operating activities:
	Net income	$	123,272		$	333,469		$	—		$	(333,469	)	$	123,272
	Adjustments to reconcile net loss to net cash provided by operating activities:
	Depreciation, depletion and amortization	—			396,070			—			—			396,070
	Impairment of long-lived assets	—			42,202			—			—			42,202
	Unit-based compensation expenses	—			19,575			—			—			19,575
	Loss on extinguishment of debt	4,187			—			—			—			4,187
	Amortization and write-off of deferred financing fees	10,905			—			—			—			10,905
	Losses on sale of assets and other, net	—			16,814			—			—			16,814
Equity in earnings from consolidated subsidiaries	(333,469		)	—			—			333,469			—
Deferred income taxes	—			5,725			—			—			5,725
Derivatives activities:
Total gains	—			(218,363		)	—			—			(218,363		)
Cash settlements	—			144,502			—			—			144,502
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	—			36,174			—			—			36,174
Decrease in accounts receivable – affiliates	366,386			—			—			(366,386		)	—
(Increase) decrease in other assets	(100		)	2,360			—			—			2,260
Decrease in accounts payable and accrued expenses	—			(5,319		)	—			—			(5,319		)
Decrease in accounts payable and accrued expenses – affiliates	—			(366,386		)	—			366,386			—
Increase (decrease) in other liabilities	771			(17,419		)	—			—			(16,648		)
Net cash provided by operating activities	171,952			389,404			—			—			561,356
Cash flow from investing activities:
Acquisition of oil and natural gas properties and joint-venture funding	—			(64,381		)	—			—			(64,381		)
Development of oil and natural gas properties	—			(495,899		)	—			—			(495,899		)
Purchases of other property and equipment	—			(55,147		)	—			—			(55,147		)
Change in notes receivable with affiliate	(27,400		)	—			—			27,400			—
Proceeds from sale of properties and equipment and other	(8,409		)	219,308			—			—			210,899
Net cash used in investing activities	(35,809		)	(396,119		)	—			27,400			(404,528		)
	LINN Energy, LLC			Guarantor Subsidiaries			Non-			Eliminations			Consolidated
							Guarantor Subsidiary
	(in thousands)
Cash flow from financing activities:
Proceeds from borrowings	775,000			—			—			—			775,000
Repayments of debt	(560,737		)	—			—			—			(560,737		)
Distributions to unitholders	(341,117		)	—			—			—			(341,117		)
Financing fees and other, net	(9,366		)	(21,290		)	—			—			(30,656		)
Change in notes payable with affiliate	—			27,400			—			(27,400		)	—
Excess tax benefit from unit-based compensation	—			591			—			—			591
Net cash provided by (used in) financing activities	(136,220		)	6,701			—			(27,400		)	(156,919		)
Net decrease in cash and cash equivalents	(77		)	(14		)	—			—			(91		)
Cash and cash equivalents:
Beginning	107			1,136			—			—			1,243
Ending	$	30		$	1,122		$	—		$	—		$	1,152

Acquisitions_JointVenture_Fund2

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

3 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Mar. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Apr. 03, 2012

Jun. 30, 2014

Jun. 30, 2014

Jun. 27, 2014

Dec. 17, 2013

Dec. 16, 2013

Dec. 17, 2013

Jul. 24, 2014

Jul. 18, 2014

Business Acquisition Anadarko [Member]

Business Acquisition Anadarko [Member]

Business Acquisition, Various [Member]

Business Acquisition Devon [Member] [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

LinnCo [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Business Acquisition, Berry [Member]

Business Acquisition, Berry [Member]

Business Acquisition, Berry [Member]

Business Acquisition Pioneer [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 Combination, Consideration Transferred

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

Acquisition Contract Price

'

'

'

'

'

'

'

'

2,300,000,000

'

'

'

'

340,000,000

Business Acquisition Amount Of Cash Deposit

'

'

'

'

'

'

'

'

'

'

'

'

'

34,000,000

Divestiture Estimated Sales Price

'

'

'

'

'

'

'

'

'

'

'

'

90,000,000

'

Business acquisition interim financing

'

'

'

'

'

'

'

'

2,300,000,000

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Exchange Ratio

'

'

'

'

'

'

'

'

'

'

'

168.00%

'

'

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

'

'

'

'

'

'

'

'

'

93,756,674

'

93,756,674

'

'

Business Acqusition, Preliminary Value

'

'

'

'

'

'

'

'

'

4,600,000,000

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Long-term Debt

'

'

'

'

'

'

'

'

'

'

2,300,000,000

'

'

'

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

'

'

'

'

'

'

'

'

'

'

451,000,000

'

'

'

Impairment of Long-Lived Assets to be Disposed of

'

-14,851,000

57,000,000

'

42,202,000

'

'

'

'

'

'

'

'

'

Impairment of long-lived assets

0

-14,851,000

'

0

42,202,000

'

'

'

'

'

'

'

'

'

Proceeds from Sale of Property Held-for-sale

'

219,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Costs Associated With Sale of Oil and Gas Property and Equipment

'

$2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_JointVenture_Fund3

Acquisitions, Joint-Venture Funding and Divestitures Pro Forma Financial Information (Details) (USD $)	3 Months Ended	6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2013
Business Combinations [Abstract]	'	'
Property, Plant and Equipment, Useful Life	'	'20 years
Business Acquisition, Pro Forma Information [Abstract]	'	'
Total revenues and other	$1,161,137	$1,806,346
Total operating expenses	586,909	1,256,821
Net income	$441,935	$284,615
Net income per unit:	'	'
Basic	$1.34	$0.86
Diluted	$1.34	$0.86

Unitholders_Capital_Details

Unitholders' Capital (Details) (USD $)	3 Months Ended		6 Months Ended		1 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jul. 31, 2014	Jul. 31, 2014
					Dividend Declared [Member]	Dividend Paid [Member]
					Subsequent Event [Member]	Subsequent Event [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'
Per unit cash dividend declared (in usd per unit)	$0.73	$0.73	$1.45	$1.45	$0.73	'
Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit	'	'	'	'	$0.24	'
Distributions to unitholders	'	'	$480,583	$341,117	'	$80,000

Oil_and_Natural_Gas_Properties2

Oil and Natural Gas Properties (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Proved Property	'	'
Leasehold acquisition	$12,329,359	$12,277,089
Development	4,468,702	3,660,277
Unproved properties	1,886,148	1,951,193
Oil and natural gas properties (successful efforts method)	18,684,209	17,888,559
Less accumulated depletion and amortization	-4,051,761	-3,546,284
Oil and natural gas properties, successful efforts method, net	$14,632,448	$14,342,275

UnitBased_Compensation_Narrati

Unit-Based Compensation (Narrative) (Details) (USD $)	3 Months Ended			6 Months Ended	1 Months Ended	6 Months Ended	3 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014	Jun. 30, 2014	Jan. 31, 2014	Jun. 30, 2014	Mar. 31, 2013	Mar. 31, 2013
	Restricted Stock Units (RSUs) [Member]	Phantom Units [Member]	Share Based Compensation Arrangement Award [Member]	Share Based Compensation Arrangement Award [Member]	Performance Shares [Member]	Performance Shares [Member]	Share-based Compensation Award, Tranche One [Member]	Share-based Compensation Award, Tranche Two [Member]
							Performance Shares [Member]	Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'	'	'	'	'
Units granted to employees	1,447,577	214,875	'	'	212,524	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	'	'	'	'	'	'	50.00%	50.00%
Aggregate fair value of grants issued to employees	'	'	'	$56	'	$5	'	'
Vesting period of grants issued to employees	'	'	'3 years	'	'	'	'2 years	'3 years

UnitBased_Compensation_Compens

Unit-Based Compensation (Compensation Expenses) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	$11,083	$8,313	$32,583	$19,575
Income tax benefit	4,095	3,072	12,039	7,233
General and administrative expenses	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	9,496	7,136	27,719	17,001
Lease operating expenses	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs	'	'	'	'
Allocated Share Based Compensation Expense	$1,587	$1,177	$4,864	$2,574

Debt_Details

Debt (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Mar. 31, 2012

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Mar. 31, 2014

Jun. 30, 2014

Dec. 16, 2013

Jun. 30, 2014

Dec. 16, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Credit Facility

Credit Facility

Subordinated Debt [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Berry [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Linn Energy, LLC [Member]

Senior Notes Due November 2019

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Loans Payable [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Subordinated Debt [Member]

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Senior Notes Due 2014 [Member]

Senior Notes Due 2014 [Member]

Senior Notes Due 2014 [Member]

Senior Notes Due 2020

Senior Notes Due 2020

Senior Notes Due 2022 [Member]

Senior Notes Due 2022 [Member]

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Senior Notes Due May 2019

Senior Notes Due November 2019

Senior Notes Due 2020

Senior Notes Due 2021

Minimum

Maximum

LIBOR

LIBOR

ABR

ABR

Minimum

Maximum

LIBOR

LIBOR

ABR

ABR

LIBOR

ABR

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

Minimum

Maximum

Maximum

Maximum

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

2.66%

2.67%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.90%

1.92%

'

'

'

'

'

'

'

2.65%

'

'

'

'

'

'

Line of Credit Facility, redetermined borrowing base

'

'

'

'

'

$1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of Credit Outstanding, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80.00%

80.00%

'

'

'

'

'

'

Line Of Credit Facility Collateral Coverage Ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

1.50%

2.50%

0.50%

1.50%

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

2.50%

0.50%

1.50%

'

'

2.50%

1.50%

'

'

'

'

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

599,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

750,000,000

1,800,000,000

1,300,000,000

1,000,000,000

Additional interest paid due to late registration

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.25%

6.75%

'

6.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.50%

6.25%

8.63%

7.75%

Long-term Debt, Fair Value

10,009,700,000

9,395,577,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

310,000,000

'

607,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number Of Days For Effective Registration Statement

'

'

'

'

'400 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

'

321,000,000

'

'

30,000,000

'

837,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

$205,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt_Schedule_of_Long_Term_Deb

Debt Schedule of Long Term Debt (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013		Dec. 16, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'		'		'
Credit facilities	$3,418,175		$2,733,175		'
Lines of Credit, Fair Value Disclosure	3,418,175		2,733,175		'
Term loan	500,000		500,000		'
Loans Payable, Fair Value Disclosure	500,000		500,000		'
Long-term Debt	9,644,351		9,170,216		'
Long-term Debt, Fair Value	10,009,700		9,395,577		'
Long-term Debt, Current Maturities	0		211,558		'
Long-term Debt, Excluding Current Maturities	9,644,351		8,958,658		'
Senior Notes	5,726,176		5,937,041		'
Senior Notes, Fair Value	6,091,525		6,162,402		'
Subordinated Debt [Member]	'		'		'
Debt Instrument [Line Items]	'		'		'
Debt Instrument, Unamortized Discount (Premium), Net	-22,957		-18,216		'
Linn Energy, LLC [Member] | Line of Credit | Credit Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Credit facilities	2,245,000	[1]	1,560,000	[1]	'
Linn Energy, LLC [Member] | Loans Payable [Member]	'		'		'
Debt Instrument [Line Items]	'		'		'
Term loan	500,000	[2]	500,000	[2]	'
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Term loan	500,000	[3]	'		'
Linn Energy, LLC [Member] | Subordinated Debt [Member] | Senior Notes Due May 2019	'		'		'
Debt Instrument [Line Items]	'		'		'
Senior Notes	750,000		750,000		'
Linn Energy, LLC [Member] | Subordinated Debt [Member] | Senior Notes Due November 2019	'		'		'
Debt Instrument [Line Items]	'		'		'
Senior Notes	1,800,000		1,800,000		'
Linn Energy, LLC [Member] | Subordinated Debt [Member] | Senior Notes Due 2020	'		'		'
Debt Instrument [Line Items]	'		'		'
Senior Notes	1,300,000		1,300,000		'
Linn Energy, LLC [Member] | Subordinated Debt [Member] | Senior Notes Due 2021	'		'		'
Debt Instrument [Line Items]	'		'		'
Senior Notes	1,000,000		1,000,000		'
Berry [Member] | Line of Credit | Credit Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Credit facilities	1,173,175	[3]	1,173,175	[3]	'
Berry [Member] | Subordinated Debt [Member] | Senior Notes Due 2014 [Member]	'		'		'
Debt Instrument [Line Items]	'		'		'
Senior Notes	0		205,257		'
Berry [Member] | Subordinated Debt [Member] | Senior Notes Due 2020	'		'		'
Debt Instrument [Line Items]	'		'		'
Long-term Debt, Fair Value	'		'		310,000
Senior Notes	299,970		300,000		'
Berry [Member] | Subordinated Debt [Member] | Senior Notes Due 2022 [Member]	'		'		'
Debt Instrument [Line Items]	'		'		'
Long-term Debt, Fair Value	'		'		607,000
Senior Notes	$599,163		$600,000		'
[1]	Variable interest rates of 1.90% and 1.92% at June 30, 2014, and December 31, 2013, respectively.
[2]	Variable interest rates of 2.65% and 2.67% at June 30, 2014, and December 31, 2013, respectively.
[3]	Variable interest rates of 2.66% and 2.67% at June 30, 2014, and December 31, 2013, respectively.

Derivatives_Commodity_Derivati

Derivatives (Commodity Derivatives) (Details)	3 Months Ended			6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
	MMMBTU		MMMBTU	MMMBTU		MMMBTU
	MBbls		MBbls	MBbls		MBbls
Derivative [Line Items]	'		'	'		'
Volumes of natural gas production on settled derivatives (in MMMbtu)	44,136		43,253	87,787		86,031
Average contract price per MMBtu on settled derivatives	5.14		5.29	'		'
Volumes of oil production on settled derivatives (in MBbls)	6,230		3,734	12,391		7,426
Average contract price per barrel on settled derivatives	92.39		95.57	'		'
2014 | Natural Gas Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	49,100		'	49,100		'
Weighted Average Fixed Price (in usd per energy unit)	5.25		'	5.25		'
2014 | Natural Gas Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	40,141	[1]	'	40,141	[1]	'
Weighted Average Short Put Price (in usd per energy unit)	5	[1]	'	5	[1]	'
2014 | Oil Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	8,485	[2]	'	8,485	[2]	'
Weighted Average Fixed Price (in usd per energy unit)	92.44	[2]	'	92.44	[2]	'
2014 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	368	[2]	'	368	[2]	'
Derivative, Floor Price	90	[2]	'	90	[2]	'
Derivative, Cap Price	102.87	[2]	'	102.87	[2]	'
2014 | Oil Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	1,996	[2]	'	1,996	[2]	'
Weighted Average Short Put Price (in usd per energy unit)	91.3	[2]	'	91.3	[2]	'
2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	1,564	[2]	'	1,564	[2]	'
2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	184	[2]	'	184	[2]	'
2014 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	40,020	[3]	'	40,020	[3]	'
Hedged Differential (in usd per energy unit)	-0.33	[3]	'	-0.33	[3]	'
2014 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	20,619	[3]	'	20,619	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2014 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,784	[3]	'	4,784	[3]	'
Hedged Differential (in usd per energy unit)	0.08	[3]	'	0.08	[3]	'
2014 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	2,650	[3]	'	2,650	[3]	'
Hedged Differential (in usd per energy unit)	-0.1	[3]	'	-0.1	[3]	'
2014 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	2,466	[3]	'	2,466	[3]	'
Hedged Differential (in usd per energy unit)	-0.21	[3]	'	-0.21	[3]	'
2014 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	1,840		'	1,840		'
Hedged Differential (in usd per energy unit)	11.6		'	11.6		'
2014 | Oil Timing Differential Positions | Trade month roll swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,577	[3]	'	4,577	[3]	'
Hedged Differential (in usd per energy unit)	0.24	[3]	'	0.24	[3]	'
2015 | Natural Gas Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	118,041		'	118,041		'
Weighted Average Fixed Price (in usd per energy unit)	5.19		'	5.19		'
2015 | Natural Gas Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	71,854	[1]	'	71,854	[1]	'
Weighted Average Short Put Price (in usd per energy unit)	5	[1]	'	5	[1]	'
2015 | Oil Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	11,599	[2]	'	11,599	[2]	'
Weighted Average Fixed Price (in usd per energy unit)	96.23	[2]	'	96.23	[2]	'
2015 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
2015 | Oil Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	3,426	[2]	'	3,426	[2]	'
Weighted Average Short Put Price (in usd per energy unit)	90	[2]	'	90	[2]	'
2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	1,095	[2]	'	1,095	[2]	'
2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2015 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	87,162	[3]	'	87,162	[3]	'
Hedged Differential (in usd per energy unit)	-0.33	[3]	'	-0.33	[3]	'
2015 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	43,292	[3]	'	43,292	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2015 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	9,344	[3]	'	9,344	[3]	'
Hedged Differential (in usd per energy unit)	0.06	[3]	'	0.06	[3]	'
2015 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,891	[3]	'	4,891	[3]	'
Hedged Differential (in usd per energy unit)	-0.1	[3]	'	-0.1	[3]	'
2015 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	5,074	[3]	'	5,074	[3]	'
Hedged Differential (in usd per energy unit)	-0.21	[3]	'	-0.21	[3]	'
2015 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	2,920		'	2,920		'
Hedged Differential (in usd per energy unit)	11.6		'	11.6		'
2015 | Oil Timing Differential Positions | Trade month roll swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	7,251	[3]	'	7,251	[3]	'
Hedged Differential (in usd per energy unit)	0.24	[3]	'	0.24	[3]	'
2016 | Natural Gas Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	121,841		'	121,841		'
Weighted Average Fixed Price (in usd per energy unit)	4.2		'	4.2		'
2016 | Natural Gas Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	76,269	[1]	'	76,269	[1]	'
Weighted Average Short Put Price (in usd per energy unit)	5	[1]	'	5	[1]	'
2016 | Oil Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	11,465	[2]	'	11,465	[2]	'
Weighted Average Fixed Price (in usd per energy unit)	90.56	[2]	'	90.56	[2]	'
2016 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
2016 | Oil Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	3,271	[2]	'	3,271	[2]	'
Weighted Average Short Put Price (in usd per energy unit)	90	[2]	'	90	[2]	'
2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2016 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	59,954	[3]	'	59,954	[3]	'
Hedged Differential (in usd per energy unit)	-0.32	[3]	'	-0.32	[3]	'
2016 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	46,294	[3]	'	46,294	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2016 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	7,768	[3]	'	7,768	[3]	'
Hedged Differential (in usd per energy unit)	0.05	[3]	'	0.05	[3]	'
2016 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,575	[3]	'	4,575	[3]	'
Hedged Differential (in usd per energy unit)	-0.1	[3]	'	-0.1	[3]	'
2016 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,219	[3]	'	4,219	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2016 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0		'	0		'
Hedged Differential (in usd per energy unit)	0		'	0		'
2016 | Oil Timing Differential Positions | Trade month roll swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	7,446	[3]	'	7,446	[3]	'
Hedged Differential (in usd per energy unit)	0.25	[3]	'	0.25	[3]	'
2017 | Natural Gas Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	120,122		'	120,122		'
Weighted Average Fixed Price (in usd per energy unit)	4.26		'	4.26		'
2017 | Natural Gas Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	66,886	[1]	'	66,886	[1]	'
Weighted Average Short Put Price (in usd per energy unit)	4.88	[1]	'	4.88	[1]	'
2017 | Oil Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,755	[2]	'	4,755	[2]	'
Weighted Average Fixed Price (in usd per energy unit)	89.02	[2]	'	89.02	[2]	'
2017 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
2017 | Oil Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	384	[2]	'	384	[2]	'
Weighted Average Short Put Price (in usd per energy unit)	90	[2]	'	90	[2]	'
2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2017 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Weighted Average Fixed Price (in usd per energy unit)	100		'	100		'
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384		'	5,384		'
2017 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	59,138	[3]	'	59,138	[3]	'
Hedged Differential (in usd per energy unit)	-0.33	[3]	'	-0.33	[3]	'
2017 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	38,880	[3]	'	38,880	[3]	'
Hedged Differential (in usd per energy unit)	-0.19	[3]	'	-0.19	[3]	'
2017 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	7,437	[3]	'	7,437	[3]	'
Hedged Differential (in usd per energy unit)	0.05	[3]	'	0.05	[3]	'
2017 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	3,604	[3]	'	3,604	[3]	'
Hedged Differential (in usd per energy unit)	-0.08	[3]	'	-0.08	[3]	'
2017 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	4,819	[3]	'	4,819	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2017 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0		'	0		'
Hedged Differential (in usd per energy unit)	0		'	0		'
2017 | Oil Timing Differential Positions | Trade month roll swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	6,486	[3]	'	6,486	[3]	'
Hedged Differential (in usd per energy unit)	0.25	[3]	'	0.25	[3]	'
2018 | Natural Gas Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	36,500		'	36,500		'
Weighted Average Fixed Price (in usd per energy unit)	5		'	5		'
2018 | Natural Gas Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[1]	'	0	[1]	'
Weighted Average Short Put Price (in usd per energy unit)	0	[1]	'	0	[1]	'
2018 | Oil Derivative Instruments | Fixed price swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Weighted Average Fixed Price (in usd per energy unit)	0	[2]	'	0	[2]	'
2018 | Oil Derivative Instruments | Crude Oil Sales - Collars [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
2018 | Oil Derivative Instruments | Puts	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
Weighted Average Short Put Price (in usd per energy unit)	0	[2]	'	0	[2]	'
2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[2]	'	0	[2]	'
2018 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384		'	5,384		'
2018 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	16,425	[3]	'	16,425	[3]	'
Hedged Differential (in usd per energy unit)	-0.33	[3]	'	-0.33	[3]	'
2018 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	10,804	[3]	'	10,804	[3]	'
Hedged Differential (in usd per energy unit)	-0.19	[3]	'	-0.19	[3]	'
2018 | Natural Gas Basis Differential Positions | MichCon Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	2,044	[3]	'	2,044	[3]	'
Hedged Differential (in usd per energy unit)	0.05	[3]	'	0.05	[3]	'
2018 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	986	[3]	'	986	[3]	'
Hedged Differential (in usd per energy unit)	-0.08	[3]	'	-0.08	[3]	'
2018 | Natural Gas Basis Differential Positions | Permian Basis Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	1,314	[3]	'	1,314	[3]	'
Hedged Differential (in usd per energy unit)	-0.2	[3]	'	-0.2	[3]	'
2018 | Oil Basis Differential Commodity Contract [Member] | ICE Brent - NYMEX WTI basis swaps [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0		'	0		'
Hedged Differential (in usd per energy unit)	0		'	0		'
2018 | Oil Timing Differential Positions | Trade month roll swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Annual Hedged Volume (in energy unit)	0	[3]	'	0	[3]	'
Hedged Differential (in usd per energy unit)	0	[3]	'	0	[3]	'
2019 | Oil Derivative Instruments | Extendible Fixed Price Swaps	'		'	'		'
Derivative [Line Items]	'		'	'		'
Weighted Average Fixed Price (in usd per energy unit)	90		'	90		'
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls)	5,384		'	5,384		'
Short [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	72.11	[2]	'	72.11	[2]	'
Derivative, Cap Price	109.79	[2]	'	109.79	[2]	'
Short [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	80	[2]	'	80	[2]	'
Derivative, Cap Price	114.05	[2]	'	114.05	[2]	'
Short [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	70	[2]	'	70	[2]	'
Derivative, Cap Price	101.62	[2]	'	101.62	[2]	'
Short [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Short [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Derivative, Cap Price	0	[2]	'	0	[2]	'
Long [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	93.76	[2]	'	93.76	[2]	'
Long [Member] | 2014 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	100	[2]	'	100	[2]	'
Long [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	90	[2]	'	90	[2]	'
Long [Member] | 2015 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2016 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2017 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 1 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
Long [Member] | 2018 | Oil Derivative Instruments | Crude Oil Sales - Three-way collars - Derivative 2 [Member]	'		'	'		'
Derivative [Line Items]	'		'	'		'
Derivative, Floor Price	0	[2]	'	0	[2]	'
[1]	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for each of the years ending December 31, 2017, and December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, if the counterparties determine that the strike prices are in-the-money on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other years.
[2]	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
[3]	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).

Derivatives_Balance_Sheet_Pres

Derivatives (Balance Sheet Presentation) (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$552,000,000	'
Assets:	'	'
Commodity derivatives	551,636,000	1,048,212,000
Liabilities:	'	'
Commodity derivatives	$353,222,000	$222,905,000

Derivatives_Gains_Losses_On_De

Derivatives (Gains (Losses) On Derivatives) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'	'
Gains (losses) on oil and natural gas derivatives	($408,788)	$326,733	($650,281)	$218,363
Cash settlements	($9,000)	$58,708	($23,123)	$144,502

Fair_Value_Measurements_on_a_R2

Fair Value Measurements on a Recurring Basis (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets:	'	'
Commodity derivatives	$551,636	$1,048,212
Commodity derivatives	-284,488	-190,080	[1]
Commodity derivatives	267,148	858,132
Liabilities:	'	'
Commodity derivatives	353,222	222,905
Commodity derivatives	-284,488	-190,080	[1]
Commodity derivatives	$68,734	$32,825
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Future inflation factor used in the calculation of the asset retirement obligations	2.00%
Credit adjusted risk-free interest rate for the calculation of the asset retirement obligations	5.40%
Asset retirement obligations rollforward	'
Asset retirement obligations at December 31, 2013	$289,321
Liabilities added from drilling	5,673
Current year accretion expense	9,570
Settlements	-9,947
Revision of estimates	9,130
Asset retirement obligations at June 30, 2014	$303,747

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	1 Months Ended			6 Months Ended		26 Months Ended
	Apr. 30, 2014	Apr. 30, 2013	Mar. 31, 2011	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014
Loss Contingency, Estimate [Abstract]	'	'	'	'	'	'
Litigation Settlement, Amount	'	'	'	$2,400,000	'	'
Payments for Legal Settlements	'	'	'	0	0	'
General Unsecured Claims Amount From Termination Agreement	'	'	51,000,000	'	'	'
Distribution Under Termination Agreement	3,000,000	5,000,000	'	'	'	42,000,000
Pending Litigation [Member]	'	'	'	'	'	'
Loss Contingency, Estimate [Abstract]	'	'	'	'	'	'
Loss Contingency, Range of Possible Loss, Minimum	'	'	'	1,000,000	'	1,000,000
Loss Contingency, Range of Possible Loss, Maximum	'	'	'	$4,500,000	'	$4,500,000

Earnings_Per_Unit_Details

Earnings Per Unit (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net income (loss)	($207,870)	'	($293,207)	$123,272
Allocated to participating securities	-2,154	'	-4,306	-2,599
Net loss available to common unitholders, basic	($210,024)	$342,528	($297,513)	$120,673
Earnings per share reconciliation	'	'	'	'
Basic loss per unit (in usd per unit)	($0.64)	$1.47	($0.91)	$0.52
Diluted loss per unit (in usd per unit)	($0.64)	$1.46	($0.91)	$0.52
Weighted average units outstanding	'	'	'	'
Basic weighted average units outstanding	328,844,000	233,448,000	328,588,000	233,313,000
Dilutive effect of unit equivalents	0	462,000	0	487,000
Diluted weighted average units outstanding	328,844,000	233,910,000	328,588,000	233,800,000
Unit options and warrants	'	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'	'
Weighted average anti-dilutive unit equivalents excluded from computation of earnings per unit (in units)	6,000,000	3,000,000	6,000,000	3,000,000

Supplemental_Disclosures_to_th2

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Balance Sheets) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Balance Sheet and Cash Flow Supplemental Disclosures [Abstract]	'	'
Restricted cash	$6,000,000	$6,000,000
Accrued Liabilities and Other Liabilities [Abstract]	'	'
Accrued compensation	31,702,000	55,257,000
Accrued interest	92,019,000	93,998,000
Asset retirement obligations	12,616,000	6,270,000
Other	2,041,000	7,850,000
Other accrued liabilities	$138,378,000	$163,375,000

Supplemental_Disclosures_to_th3

Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows (Cash Flows) (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013
Supplemental Cash Flow Information [Abstract]	'	'
Cash payments for interest, net of amounts capitalized	$264,141,000	$192,517,000
Cash payments for income taxes	0	14,000
In connection with the acquisition of oil and natural gas properties and joint-venture funding, assets were acquired and liabilities were assumed as follows:	'	'
Fair value of assets acquired	4,242,000	7,655,000
Cash (paid) received	-1,139,000	3,231,000
Receivables from sellers	0	1,792,000
Payables to sellers	0	-6,854,000
Liabilities assumed	3,103,000	5,824,000
Joint-venture funding	$25,000,000	$68,000,000

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses	$66,906,000	$46,305,000	$146,134,000	$104,871,000
Distributions to unitholders	'	'	480,583,000	341,117,000
LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Ownership percentage	39.00%	'	39.00%	'
General and administrative expenses	749,000	'	1,500,000	'
General and Administrative Expenses and Offering Costs	'	3,000,000	'	15,000,000
Related Party Transaction, Expenses from Transactions with Related Party	471,000	344,000,000	941,000	806,000,000
Director [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Related party transaction, amounts of transaction	8,000,000	7,000,000	12,000,000	13,000,000
FY 2014 [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses paid on behalf of LinnCo	'	'	'	8,000,000
FY 2013 [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses paid on behalf of LinnCo	'	'	11,000,000	'
Business Acquisition, Berry [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and Administrative Expenses and Offering Costs	'	2,000,000	'	13,000,000
Dividend Paid [Member] | LinnCo [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Distributions to unitholders	$93,000,000	$25,000,000	$186,000,000	$50,000,000

Subsidiary_Guarantors_Condense

Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'	'	'
Cash and cash equivalents	$38,339	$52,171	$1,152	$1,243
Accounts receivable – trade, net	549,589	488,202	'	'
Accounts receivable – affiliates	0	0	'	'
Derivative instruments	91,611	176,130	'	'
Other current assets	107,882	99,437	'	'
Total current assets	787,421	815,940	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	18,684,209	17,888,559	'	'
Less accumulated depletion and amortization	-4,051,761	-3,546,284	'	'
Oil and natural gas properties, successful efforts method, net	14,632,448	14,342,275	'	'
Other property and equipment	676,294	647,882	'	'
Less accumulated depreciation	-135,316	-110,939	'	'
Other property and equipment, net	540,978	536,943	'	'
Derivative instruments	175,537	682,002	'	'
Notes receivable – affiliates	0	0	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	132,280	127,804	'	'
Noncurrent assets, excluding property, total	307,817	809,806	'	'
Total noncurrent assets	15,481,243	15,689,024	'	'
Total assets	16,268,664	16,504,964	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	860,171	849,624	'	'
Accounts payable – affiliates	0	0	'	'
Derivative instruments	59,907	28,176	'	'
Other accrued liabilities	138,378	163,375	'	'
Current portion of long-term debt	0	211,558	'	'
Total current liabilities	1,058,456	1,252,733	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	3,418,175	2,733,175	'	'
Term loan	500,000	500,000	'	'
Senior notes, net	5,726,176	5,725,483	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	8,827	4,649	'	'
Other noncurrent liabilities	395,907	397,497	'	'
Total noncurrent liabilities	10,049,085	9,360,804	'	'
Unitholders’ capital:	'	'	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	5,854,727	6,291,824	'	'
Accumulated deficit	-693,604	-400,397	'	'
Total unitholders' capital	5,161,123	5,891,427	'	'
Total liabilities and unitholders’ capital	16,268,664	16,504,964	'	'
Reportable Legal Entities [Member] | Parent Company [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	32	52	30	107
Accounts receivable – trade, net	0	0	'	'
Accounts receivable – affiliates	4,025,707	4,212,348	'	'
Derivative instruments	0	0	'	'
Other current assets	476	330	'	'
Total current assets	4,026,215	4,212,730	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	0	0	'	'
Less accumulated depletion and amortization	0	0	'	'
Oil and natural gas properties, successful efforts method, net	0	0	'	'
Other property and equipment	0	0	'	'
Less accumulated depreciation	0	0	'	'
Other property and equipment, net	0	0	'	'
Derivative instruments	0	0	'	'
Notes receivable – affiliates	114,400	86,200	'	'
Investments in consolidated subsidiaries	8,540,562	8,433,290	'	'
Other noncurrent assets	105,004	108,785	'	'
Noncurrent assets, excluding property, total	8,759,966	8,628,275	'	'
Total noncurrent assets	8,759,966	8,628,275	'	'
Total assets	12,786,181	12,841,005	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	1,822	14,529	'	'
Accounts payable – affiliates	0	0	'	'
Derivative instruments	0	0	'	'
Other accrued liabilities	75,773	75,071	'	'
Current portion of long-term debt	'	0	'	'
Total current liabilities	77,595	89,600	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	2,245,000	1,560,000	'	'
Term loan	500,000	500,000	'	'
Senior notes, net	4,811,496	4,809,055	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	0	0	'	'
Other noncurrent liabilities	0	0	'	'
Total noncurrent liabilities	7,556,496	6,869,055	'	'
Unitholders’ capital:	'	'	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	5,845,694	6,282,747	'	'
Accumulated deficit	-693,604	-400,397	'	'
Total unitholders' capital	5,152,090	5,882,350	'	'
Total liabilities and unitholders’ capital	12,786,181	12,841,005	'	'
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	35,818	1,078	1,122	1,136
Accounts receivable – trade, net	393,012	365,347	'	'
Accounts receivable – affiliates	26,914	16,950	'	'
Derivative instruments	89,541	170,534	'	'
Other current assets	77,171	68,274	'	'
Total current assets	622,456	622,183	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	13,558,084	13,074,900	'	'
Less accumulated depletion and amortization	-3,901,130	-3,535,890	'	'
Oil and natural gas properties, successful efforts method, net	9,656,954	9,539,010	'	'
Other property and equipment	586,438	564,756	'	'
Less accumulated depreciation	-131,526	-110,706	'	'
Other property and equipment, net	454,912	454,050	'	'
Derivative instruments	174,327	679,491	'	'
Notes receivable – affiliates	0	0	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	11,072	10,968	'	'
Noncurrent assets, excluding property, total	185,399	690,459	'	'
Total noncurrent assets	10,297,265	10,683,519	'	'
Total assets	10,919,721	11,305,702	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	570,680	587,774	'	'
Accounts payable – affiliates	4,026,182	4,212,348	'	'
Derivative instruments	28,332	7,783	'	'
Other accrued liabilities	43,045	59,311	'	'
Current portion of long-term debt	'	0	'	'
Total current liabilities	4,668,239	4,867,216	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	0	0	'	'
Term loan	0	0	'	'
Senior notes, net	0	0	'	'
Notes payable – affiliates	114,400	86,200	'	'
Derivative instruments	8,827	0	'	'
Other noncurrent liabilities	211,316	205,406	'	'
Total noncurrent liabilities	334,543	291,606	'	'
Unitholders’ capital:	'	'	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	4,833,310	4,833,354	'	'
Accumulated deficit	1,083,629	1,313,526	'	'
Total unitholders' capital	5,916,939	6,146,880	'	'
Total liabilities and unitholders’ capital	10,919,721	11,305,702	'	'
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	2,489	51,041	0	0
Accounts receivable – trade, net	156,577	122,855	'	'
Accounts receivable – affiliates	0	0	'	'
Derivative instruments	2,070	5,596	'	'
Other current assets	30,235	30,833	'	'
Total current assets	191,371	210,325	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	5,126,125	4,813,659	'	'
Less accumulated depletion and amortization	-150,631	-10,394	'	'
Oil and natural gas properties, successful efforts method, net	4,975,494	4,803,265	'	'
Other property and equipment	89,856	83,126	'	'
Less accumulated depreciation	-3,790	-233	'	'
Other property and equipment, net	86,066	82,893	'	'
Derivative instruments	1,210	2,511	'	'
Notes receivable – affiliates	0	0	'	'
Investments in consolidated subsidiaries	0	0	'	'
Other noncurrent assets	16,204	8,051	'	'
Noncurrent assets, excluding property, total	17,414	10,562	'	'
Total noncurrent assets	5,078,974	4,896,720	'	'
Total assets	5,270,345	5,107,045	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	287,669	247,321	'	'
Accounts payable – affiliates	26,439	16,950	'	'
Derivative instruments	31,575	20,393	'	'
Other accrued liabilities	19,560	28,993	'	'
Current portion of long-term debt	'	211,558	'	'
Total current liabilities	365,243	525,215	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	1,173,175	1,173,175	'	'
Term loan	0	0	'	'
Senior notes, net	914,680	916,428	'	'
Notes payable – affiliates	0	0	'	'
Derivative instruments	0	4,649	'	'
Other noncurrent liabilities	184,591	192,091	'	'
Total noncurrent liabilities	2,272,446	2,286,343	'	'
Unitholders’ capital:	'	'	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	2,493,923	2,315,460	'	'
Accumulated deficit	138,733	-19,973	'	'
Total unitholders' capital	2,632,656	2,295,487	'	'
Total liabilities and unitholders’ capital	5,270,345	5,107,045	'	'
Consolidation, Eliminations [Member]	'	'	'	'
Current assets:	'	'	'	'
Cash and cash equivalents	0	0	0	0
Accounts receivable – trade, net	0	0	'	'
Accounts receivable – affiliates	-4,052,621	-4,229,298	'	'
Derivative instruments	0	0	'	'
Other current assets	0	0	'	'
Total current assets	-4,052,621	-4,229,298	'	'
Noncurrent assets:	'	'	'	'
Oil and natural gas properties (successful efforts method)	0	0	'	'
Less accumulated depletion and amortization	0	0	'	'
Oil and natural gas properties, successful efforts method, net	0	0	'	'
Other property and equipment	0	0	'	'
Less accumulated depreciation	0	0	'	'
Other property and equipment, net	0	0	'	'
Derivative instruments	0	0	'	'
Notes receivable – affiliates	-114,400	-86,200	'	'
Investments in consolidated subsidiaries	-8,540,562	-8,433,290	'	'
Other noncurrent assets	0	0	'	'
Noncurrent assets, excluding property, total	-8,654,962	-8,519,490	'	'
Total noncurrent assets	-8,654,962	-8,519,490	'	'
Total assets	-12,707,583	-12,748,788	'	'
Current liabilities:	'	'	'	'
Accounts payable and accrued expenses	0	0	'	'
Accounts payable – affiliates	-4,052,621	-4,229,298	'	'
Derivative instruments	0	0	'	'
Other accrued liabilities	0	0	'	'
Current portion of long-term debt	'	0	'	'
Total current liabilities	-4,052,621	-4,229,298	'	'
Noncurrent liabilities:	'	'	'	'
Credit facilities	0	0	'	'
Term loan	0	0	'	'
Senior notes, net	0	0	'	'
Notes payable – affiliates	-114,400	-86,200	'	'
Derivative instruments	0	0	'	'
Other noncurrent liabilities	0	0	'	'
Total noncurrent liabilities	-114,400	-86,200	'	'
Unitholders’ capital:	'	'	'	'
331,667,975 units and 329,661,161 units issued and outstanding at June 30, 2014, and December 31, 2013, respectively	-7,318,200	-7,139,737	'	'
Accumulated deficit	-1,222,362	-1,293,553	'	'
Total unitholders' capital	-8,540,562	-8,433,290	'	'
Total liabilities and unitholders’ capital	($12,707,583)	($12,748,788)	'	'

Subsidiary_Guarantors_Condense1

Subsidiary Guarantors Condensed Consolidating Statements of Operations (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$967,850	$488,207	$1,906,727	$950,939
Gains (losses) on oil and natural gas derivatives	-408,788	326,733	-650,281	218,363
Marketing revenues	30,273	17,222	60,819	27,074
Other revenues	7,616	6,663	13,273	11,509
Total revenues	596,951	838,825	1,330,538	1,207,885
Expenses:	'	'	'	'
Lease operating expenses	184,901	83,584	378,934	172,305
Transportation expenses	44,854	29,298	90,484	56,481
Marketing expenses	23,274	9,360	44,346	16,734
General and administrative expenses	66,906	46,305	146,134	104,871
Exploration costs	1,551	818	2,642	3,044
Depreciation, depletion and amortization	274,435	198,629	542,236	396,070
Impairment of long-lived assets	0	-14,851	0	42,202
Taxes, other than income taxes	68,531	32,397	134,244	72,068
(Gains) losses on sale of assets and other, net	5,467	-959	8,053	2,213
Total expenses	669,919	384,581	1,347,073	865,988
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-134,300	-103,847	-268,113	-204,206
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	0	-4,187	0	-4,187
Equity in losses from consolidated subsidiaries	0	0	0	0
Other, net	-2,549	-2,182	-4,852	-3,825
Total other income and (expenses)	-136,849	-110,216	-272,965	-212,218
Income (loss) before income taxes	-209,817	344,028	-289,500	129,679
Income tax expense (benefit)	-1,947	-1,129	3,707	6,407
Net income (loss)	-207,870	345,157	-293,207	123,272
Reportable Legal Entities [Member] | Parent Company [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	0	0	0	0
Gains (losses) on oil and natural gas derivatives	0	0	0	0
Marketing revenues	0	0	0	0
Other revenues	0	0	0	0
Total revenues	0	0	0	0
Expenses:	'	'	'	'
Lease operating expenses	0	0	0	0
Transportation expenses	0	0	0	0
Marketing expenses	0	0	0	0
General and administrative expenses	0	0	0	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment of long-lived assets	'	0	'	0
Taxes, other than income taxes	0	0	0	0
(Gains) losses on sale of assets and other, net	0	0	0	724
Total expenses	0	0	0	724
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-111,603	-103,207	-221,253	-204,064
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	1,859	1,412	3,409	2,554
Loss on extinguishment of debt	'	-4,187	'	-4,187
Equity in losses from consolidated subsidiaries	-96,084	453,288	-71,191	333,469
Other, net	-2,042	-2,149	-4,172	-3,776
Total other income and (expenses)	-207,870	345,157	-293,207	123,996
Income (loss) before income taxes	-207,870	345,157	-293,207	123,272
Income tax expense (benefit)	0	0	0	0
Net income (loss)	-207,870	345,157	-293,207	123,272
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	607,470	488,207	1,213,231	950,939
Gains (losses) on oil and natural gas derivatives	-383,226	326,733	-628,184	218,363
Marketing revenues	17,839	17,222	33,570	27,074
Other revenues	7,607	6,663	13,280	11,509
Total revenues	249,690	838,825	631,897	1,207,885
Expenses:	'	'	'	'
Lease operating expenses	91,547	83,584	195,549	172,305
Transportation expenses	37,371	29,298	75,008	56,481
Marketing expenses	13,549	9,360	23,640	16,734
General and administrative expenses	38,584	46,305	74,321	104,871
Exploration costs	1,551	818	2,642	3,044
Depreciation, depletion and amortization	196,682	198,629	395,852	396,070
Impairment of long-lived assets	'	-14,851	'	42,202
Taxes, other than income taxes	45,052	32,397	87,736	72,068
(Gains) losses on sale of assets and other, net	1,210	-959	429	1,489
Total expenses	425,546	384,581	855,177	865,264
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	789	-640	627	-142
Interest expense – affiliates	-1,859	-1,412	-3,409	-2,554
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	'	0	'	0
Equity in losses from consolidated subsidiaries	0	0	0	0
Other, net	-62	-33	-46	-49
Total other income and (expenses)	-1,132	-2,085	-2,828	-2,745
Income (loss) before income taxes	-176,988	452,159	-226,108	339,876
Income tax expense (benefit)	-1,896	-1,129	3,789	6,407
Net income (loss)	-175,092	453,288	-229,897	333,469
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	360,380	0	693,496	0
Gains (losses) on oil and natural gas derivatives	-25,562	0	-22,097	0
Marketing revenues	12,434	0	27,249	0
Other revenues	9	0	-7	0
Total revenues	347,261	0	698,641	0
Expenses:	'	'	'	'
Lease operating expenses	93,354	0	183,385	0
Transportation expenses	7,483	0	15,476	0
Marketing expenses	9,725	0	20,706	0
General and administrative expenses	28,322	0	71,813	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	77,753	0	146,384	0
Impairment of long-lived assets	'	0	'	0
Taxes, other than income taxes	23,479	0	46,508	0
(Gains) losses on sale of assets and other, net	4,257	0	7,624	0
Total expenses	244,373	0	491,896	0
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-23,486	0	-47,487	0
Interest expense – affiliates	0	0	0	0
Interest income – affiliates	0	0	0	0
Loss on extinguishment of debt	'	0	'	0
Equity in losses from consolidated subsidiaries	0	0	0	0
Other, net	-445	0	-634	0
Total other income and (expenses)	-23,931	0	-48,121	0
Income (loss) before income taxes	78,957	0	158,624	0
Income tax expense (benefit)	-51	0	-82	0
Net income (loss)	79,008	0	158,706	0
Consolidation, Eliminations [Member]	'	'	'	'
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	0	0	0	0
Gains (losses) on oil and natural gas derivatives	0	0	0	0
Marketing revenues	0	0	0	0
Other revenues	0	0	0	0
Total revenues	0	0	0	0
Expenses:	'	'	'	'
Lease operating expenses	0	0	0	0
Transportation expenses	0	0	0	0
Marketing expenses	0	0	0	0
General and administrative expenses	0	0	0	0
Exploration costs	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment of long-lived assets	'	0	'	0
Taxes, other than income taxes	0	0	0	0
(Gains) losses on sale of assets and other, net	0	0	0	0
Total expenses	0	0	0	0
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	0	0	0	0
Interest expense – affiliates	1,859	1,412	3,409	2,554
Interest income – affiliates	-1,859	-1,412	-3,409	-2,554
Loss on extinguishment of debt	'	0	'	0
Equity in losses from consolidated subsidiaries	96,084	-453,288	71,191	-333,469
Other, net	0	0	0	0
Total other income and (expenses)	96,084	-453,288	71,191	-333,469
Income (loss) before income taxes	96,084	-453,288	71,191	-333,469
Income tax expense (benefit)	0	0	0	0
Net income (loss)	$96,084	($453,288)	$71,191	($333,469)

Subsidiary_Guarantors_Condense2

Subsidiary Guarantors Condensed Consolidating Statements of Cash Flow (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash flow from operating activities:	'	'
Net loss	($293,207)	$123,272
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	542,236	396,070
Impairment of long-lived assets	0	42,202
Unit-based compensation expenses	32,583	19,575
Loss on extinguishment of debt	0	4,187
Amortization and write-off of deferred financing fees	6,202	10,905
Losses on sale of assets and other, net	3,506	16,814
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	3,475	5,725
Derivatives activities:	'	'
Total losses	650,281	-218,363
Cash settlements	-23,123	144,502
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-61,891	36,174
(Increase) decrease in accounts receivable – affiliates	0	0
(Increase) decrease in other assets	-6,947	2,260
Increase (decrease) in accounts payable and accrued expenses	113,582	-5,319
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Decrease in other liabilities	-51,062	-16,648
Net cash provided by operating activities	915,635	561,356
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-25,891	-64,381
Development of oil and natural gas properties	-805,617	-495,899
Purchases of other property and equipment	-31,411	-55,147
Payments of Distributions to Affiliates	0	'
Proceeds from Contributions from Affiliates	0	'
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	-11,730	210,899
Net cash used in investing activities	-874,649	-404,528
Cash flow from financing activities:	'	'
Proceeds from borrowings	1,095,000	775,000
Repayments of debt	-616,124	-560,737
Distributions to unitholders	-480,583	-341,117
Financing fees and other, net	-56,127	-30,656
Change in notes payable with affiliate	0	0
Excess tax benefit from unit-based compensation	3,016	591
Net cash used in financing activities	-54,818	-156,919
Net decrease in cash and cash equivalents	-13,832	-91
Cash and cash equivalents:	'	'
Beginning	52,171	1,243
Ending	38,339	1,152
Reportable Legal Entities [Member] | Parent Company [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-293,207	123,272
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	'	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	4,187
Amortization and write-off of deferred financing fees	11,694	10,905
Losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	71,191	-333,469
Deferred income taxes	0	0
Derivatives activities:	'	'
Total losses	0	0
Cash settlements	0	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	0	0
(Increase) decrease in accounts receivable – affiliates	220,694	366,386
(Increase) decrease in other assets	-146	-100
Increase (decrease) in accounts payable and accrued expenses	2	0
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Decrease in other liabilities	702	771
Net cash provided by operating activities	10,930	171,952
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
Payments of Distributions to Affiliates	-178,463	'
Proceeds from Contributions from Affiliates	0	'
Change in notes receivable with affiliate	-28,200	-27,400
Proceeds from sale of properties and equipment and other	-12,983	-8,409
Net cash used in investing activities	-219,646	-35,809
Cash flow from financing activities:	'	'
Proceeds from borrowings	1,095,000	775,000
Repayments of debt	-410,000	-560,737
Distributions to unitholders	-480,583	-341,117
Financing fees and other, net	1,263	-9,366
Change in notes payable with affiliate	0	0
Excess tax benefit from unit-based compensation	3,016	0
Net cash used in financing activities	208,696	-136,220
Net decrease in cash and cash equivalents	-20	-77
Cash and cash equivalents:	'	'
Beginning	52	107
Ending	32	30
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	-229,897	333,469
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	395,852	396,070
Impairment of long-lived assets	'	42,202
Unit-based compensation expenses	32,583	19,575
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	0	0
Losses on sale of assets and other, net	3,506	16,814
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	3,557	5,725
Derivatives activities:	'	'
Total losses	628,184	-218,363
Cash settlements	-12,651	144,502
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-27,597	36,174
(Increase) decrease in accounts receivable – affiliates	-9,964	0
(Increase) decrease in other assets	-8,287	2,360
Increase (decrease) in accounts payable and accrued expenses	111,675	-5,319
Increase (decrease) in accounts payable and accrued expenses – affiliates	-220,694	-366,386
Decrease in other liabilities	-26,291	-17,419
Net cash provided by operating activities	639,976	389,404
Cash flow from investing activities:	'	'
Acquisition of oil and natural gas properties and joint-venture funding	-25,891	-64,381
Development of oil and natural gas properties	-536,488	-495,899
Purchases of other property and equipment	-25,786	-55,147
Payments of Distributions to Affiliates	0	'
Proceeds from Contributions from Affiliates	0	'
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	1,253	219,308
Net cash used in investing activities	-586,912	-396,119
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and other, net	-46,524	-21,290
Change in notes payable with affiliate	28,200	27,400
Excess tax benefit from unit-based compensation	0	591
Net cash used in financing activities	-18,324	6,701
Net decrease in cash and cash equivalents	34,740	-14
Cash and cash equivalents:	'	'
Beginning	1,078	1,136
Ending	35,818	1,122
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	158,706	0
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	146,384	0
Impairment of long-lived assets	'	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	-5,492	0
Losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	-82	0
Derivatives activities:	'	'
Total losses	22,097	0
Cash settlements	-10,472	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	-34,294	0
(Increase) decrease in accounts receivable – affiliates	0	0
(Increase) decrease in other assets	1,486	0
Increase (decrease) in accounts payable and accrued expenses	1,905	0
Increase (decrease) in accounts payable and accrued expenses – affiliates	9,964	0
Decrease in other liabilities	-25,473	0
Net cash provided by operating activities	264,729	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	-269,129	0
Purchases of other property and equipment	-5,625	0
Payments of Distributions to Affiliates	0	'
Proceeds from Contributions from Affiliates	178,463	'
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	-274,754	0
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	-206,124	0
Distributions to unitholders	0	0
Financing fees and other, net	-10,866	0
Change in notes payable with affiliate	0	0
Excess tax benefit from unit-based compensation	0	0
Net cash used in financing activities	-38,527	0
Net decrease in cash and cash equivalents	-48,552	0
Cash and cash equivalents:	'	'
Beginning	51,041	0
Ending	2,489	0
Consolidation, Eliminations [Member]	'	'
Cash flow from operating activities:	'	'
Net loss	71,191	-333,469
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	'	0
Unit-based compensation expenses	0	0
Loss on extinguishment of debt	'	0
Amortization and write-off of deferred financing fees	0	0
Losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	-71,191	333,469
Deferred income taxes	0	0
Derivatives activities:	'	'
Total losses	0	0
Cash settlements	0	0
Changes in assets and liabilities:	'	'
(Increase) decrease in accounts receivable – trade, net	0	0
(Increase) decrease in accounts receivable – affiliates	-210,730	-366,386
(Increase) decrease in other assets	0	0
Increase (decrease) in accounts payable and accrued expenses	0	0
Increase (decrease) in accounts payable and accrued expenses – affiliates	210,730	366,386
Decrease 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
Payments of Distributions to Affiliates	178,463	'
Proceeds from Contributions from Affiliates	-178,463	'
Change in notes receivable with affiliate	28,200	27,400
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	206,663	27,400
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders	0	0
Financing fees and other, net	0	0
Change in notes payable with affiliate	-28,200	-27,400
Excess tax benefit from unit-based compensation	0	0
Net cash used in financing activities	-206,663	-27,400
Net decrease in cash and cash equivalents	0	0
Cash and cash equivalents:	'	'
Beginning	0	0
Ending	$0	$0