Berry Petroleum 10-Q 13 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014
Entity Registrant Name	'BERRY PETROLEUM COMPANY, LLC
Entity Central Index Key	'0000778438
Current Fiscal Year End Date	'--12-31
Document Type	'10-Q
Document Period End Date	30-Jun-14
Amendment Flag	'false
Entity Common Stock, Shares Outstanding	0
Entity Filer Category	'Non-accelerated Filer
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'Q2
Entity Well-known Seasoned Issuer	'No
Entity Voluntary Filers	'Yes
Entity Current Reporting Status	'Yes

Condensed_Balance_Sheets_unaud

Condensed Balance Sheets (unaudited) (Successor, USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Successor	'	'
Current assets:	'	'
Cash and cash equivalents	$2,489	$51,041
Accounts receivable – trade, net	156,577	122,855
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, 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
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	314,108	264,271
Derivative instruments	31,575	20,393
Other accrued liabilities	19,560	28,993
Current portion of long-term debt	0	211,558
Total current liabilities	365,243	525,215
Noncurrent liabilities:	'	'
Credit facility	1,173,175	1,173,175
Senior notes, net	914,680	916,428
Derivative instruments	0	4,649
Other noncurrent liabilities	184,591	192,091
Total noncurrent liabilities	2,272,446	2,286,343
Commitments and contingencies (Note 10)	'	'
Member’s equity:	'	'
Additional paid-in capital	2,493,923	2,315,460
Accumulated income (deficit)	138,733	-19,973
Total member's equity	2,632,656	2,295,487
Total liabilities and member’s equity	$5,270,345	$5,107,045

Condensed_Statements_of_Operat

Condensed Statements of Operations (unaudited) (USD $)	3 Months Ended	6 Months Ended	3 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2013
	Successor	Successor	Predecessor	Predecessor
Revenues and other:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$360,380	$693,496	$274,715	$541,487
Electricity sales	10,192	20,161	9,513	17,102
Gains (losses) on oil and natural gas derivatives	-25,562	-22,097	35,622	34,885
Marketing revenues	2,242	7,088	2,255	4,282
Other revenues	9	-7	233	705
Total revenues	347,261	698,641	322,338	598,461
Expenses:	'	'	'	'
Lease operating expenses	93,354	183,385	79,759	155,027
Electricity generation expenses	7,629	16,012	6,337	11,633
Transportation expenses	7,483	15,476	8,293	15,987
Marketing expenses	2,096	4,694	2,198	4,076
General and administrative expenses	28,322	71,813	19,371	41,597
Exploration costs	0	0	872	4,301
Depreciation, depletion and amortization	77,753	146,384	70,272	138,750
Taxes, other than income taxes	23,479	46,508	14,229	28,199
(Gains) losses on sale of assets and other, net	4,257	7,624	0	-23
Total expenses	244,373	491,896	201,331	399,547
Other income and (expenses):	'	'	'	'
Interest expense, net of amounts capitalized	-23,486	-47,487	-24,879	-49,566
Other, net	-445	-634	82	33
Total other income (expenses)	-23,931	-48,121	-24,797	-49,533
Income before income taxes	78,957	158,624	96,210	149,381
Income tax expense (benefit)	-51	-82	34,846	55,583
Net income	$79,008	$158,706	$61,364	$93,798

Condensed_Statement_of_Members

Condensed Statement of Member's Equity (unaudited) (Successor, USD $)	Successor	Successor	Successor
In Thousands	USD ($)	Additional paid-in capital	Accumulated income (deficit)
		USD ($)	USD ($)
Member's Equity at Dec. 31, 2013	$2,295,487	$2,315,460	($19,973)
Capital contribution from affiliate	220,000	220,000	0
Distribution to affiliate	-41,537	-41,537	0
Net income	158,706	0	158,706
Member's Equity at Jun. 30, 2014	2,632,656	2,493,923	138,733
Member's Equity at Mar. 31, 2014	'	'	'
Net income	79,008	'	'
Member's Equity at Jun. 30, 2014	$2,632,656	'	'

Condensed_Statements_of_Cash_F

Condensed Statements of Cash Flows (unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
	Successor	Predecessor
Cash flow from operating activities:	'	'
Net income	$158,706	$93,798
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	146,384	138,750
Stock-based compensation expense	0	5,903
Amortization and write-off of deferred financing fees	-5,492	3,438
Change in book overdraft	0	-14,885
Deferred income taxes	-82	61,639
Other, net	0	5,382
Derivatives activities:	'	'
Total (gains) losses	22,097	-34,885
Cash settlements	-10,472	4,844
Changes in assets and liabilities:	'	'
Increase in accounts receivable – trade, net	-34,294	-16,518
Decrease in other assets	1,486	242
Increase (decrease) in accounts payable and accrued expenses	11,869	-11,470
Decrease in other liabilities	-25,473	-4,278
Net cash provided by operating activities	264,729	231,960
Cash flow from investing activities:	'	'
Property acquisitions	0	-3,080
Development of oil and natural gas properties	-269,129	-302,724
Purchases of other property and equipment	-5,625	-3,954
Proceeds from sale of properties and equipment and other	0	11,511
Net cash used in investing activities	-274,754	-298,247
Cash flow from financing activities:	'	'
Proceeds from borrowings	0	490,700
Repayments of debt	-206,124	-407,600
Dividends paid	0	-8,803
Financing fees and other, net	-10,866	-223
Proceeds from stock option exercises	0	65
Capital contribution from affiliate	220,000	0
Distribution to affiliate	-41,537	0
Excess tax benefit from stock-based compensation	0	750
Net cash provided by (used in) financing activities	-38,527	74,889
Net increase (decrease) in cash and cash equivalents	-48,552	8,602
Cash and cash equivalents:	'	'
Beginning	51,041	312
Ending	$2,489	$8,914

Basis_of_Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Basis of Presentation [Abstract]	'
Basis of Presentation and Significant Accounting Policies [Text Block]	'
	Basis of Presentation
	Nature of Business
	Berry Petroleum Company, LLC (“Berry” or the “Company”) was formed as a Delaware limited liability company on December 16, 2013, and is an indirect wholly owned subsidiary of Linn Energy, LLC (“LINN Energy”) engaged in the production and development of oil and natural gas. The Company’s predecessor, Berry Petroleum Company, was publicly traded from 1987 until December 2013. On December 16, 2013, the Company completed the transactions contemplated by the merger agreement between LINN Energy, LinnCo, LLC (“LinnCo”), an affiliate of LINN Energy, and Berry under which LinnCo acquired all of the outstanding common shares of Berry and the contribution agreement between LinnCo and LINN Energy, under which LinnCo contributed Berry to LINN Energy in exchange for LINN Energy units (see Note 2). Linn Acquisition Company, LLC, a direct subsidiary of LINN Energy, is currently the Company’s sole member.
	The Company’s properties are located in the United States (“U.S.”), in California, which includes California (South Midway-Sunset (“SMWSS”)—Steam Floods, North Midway-Sunset (“NMWSS”)—Diatomite and NMWSS—New Steam Floods (“NSF”)), Texas (Permian Basin and east Texas), Utah (Uinta Basin) and Colorado (Piceance Basin).
	Principles of 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 financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method.
	The 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), member’s equity or cash flows.
	Predecessor and Successor Reporting
	The LINN Energy transaction was accounted for under the acquisition method of accounting. Under the acquisition method of accounting, LinnCo initially, and LINN Energy upon the contribution was treated as the accounting acquirer and the Company was treated as the acquired company for financial reporting purposes. As such, the assets and liabilities of the Company were provisionally recorded at their respective fair values as of the acquisition date. Fair value adjustments related to the transaction have been pushed down to the Company, resulting in assets and liabilities of the Company being recorded at their fair values at December 16, 2013. See Note 2 for additional information.
	The Company’s statements of operations subsequent to the transaction includes depreciation, depletion and amortization expense on the Company’s oil and natural gas properties, and other property and equipment balances resulting from the fair value adjustments made under the new basis of accounting. Certain other items of income and expense were also impacted. Therefore, the Company’s financial information prior to the transaction is not comparable to its financial information subsequent to the transaction.
	As a result of the impact of pushdown accounting, the financial statements and certain note presentations separate the Company’s presentations into two distinct periods, the period before the consummation of the transaction (labeled predecessor) and the period after that date (labeled successor), to indicate the application of different basis of accounting between the periods presented.
	Use of Estimates
	The preparation of the accompanying condensed 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 financial statements and related disclosures.

Properties_Exchange_and_LINN_E

Properties Exchange and LINN Energy Transaction	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Properties Exchange and LINN Energy Transaction	'
	Properties Exchange and LINN Energy Transaction
	Properties Exchange – Pending
	On May 20, 2014, the Company, along with a subsidiary of its indirect parent LINN Energy, 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.
	LINN Energy Transaction
	On December 16, 2013, the Company completed the transactions contemplated by the merger agreement between LINN Energy, LinnCo, an affiliate of LINN Energy, and Berry under which LinnCo acquired all of the outstanding common shares of Berry and the contribution agreement between LinnCo and LINN Energy, under which LinnCo contributed Berry to LINN Energy 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.
	On the Berry acquisition date, LinnCo contributed Berry to its affiliate, LINN Energy. As a result, the assets, liabilities and results of operations of Berry are not included in LinnCo’s financial statements.
	The 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 acquisition 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.
	As a result of being formed as a limited liability company on December 16, 2013, the date of the LINN Energy transaction, the Company ceased to be subject to federal and state income taxes, with the exception of the state of Texas. The Company’s net deferred income tax liabilities were assumed by LinnCo in the merger and were not transferred to LINN Energy in the contribution.

Oil_and_Natural_Gas_Properties

Oil and Natural Gas Properties	6 Months Ended
	Jun. 30, 2014
Oil and Natural Gas Properties [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:
		30-Jun-14			31-Dec-13
		(in thousands)
	Oil and natural gas:
	Proved properties	$	3,755,393		$	3,397,785
	Unproved properties	1,370,732			1,415,874
		5,126,125			4,813,659
	Less accumulated depletion and amortization	(150,631		)	(10,394		)
		$	4,975,494		$	4,803,265

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	The following summarizes the Company’s outstanding debt:
		30-Jun-14		31-Dec-13
		(in thousands, except percentages)
	Credit facility (1)	$	1,173,175	$	1,173,175
	10.25% senior notes due June 2014	—		205,257
	6.75% senior notes due November 2020	299,970		300,000
	6.375% senior notes due September 2022	599,163		600,000
	Net unamortized premiums	15,547		22,729
	Total debt, net	2,087,855		2,301,161
	Less current maturities	—		(211,558		)
	Total long-term debt, net	$	2,087,855	$	2,089,603
	(1)	Variable interest rates of 2.66% 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 balance sheets. The carrying amount of the Company’s Credit Facility, as defined below, approximates fair value because the interest rate is 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					31-Dec-13
		Carrying Value		Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facility	$	1,173,175	$	1,173,175		$	1,173,175	$	1,173,175
	Senior notes, net	914,680		948,212			1,127,986		1,128,527
	Total debt, net	$	2,087,855	$	2,121,387		$	2,301,161	$	2,301,702
	Credit Facility
	The Company’s Second Amended and Restated Credit Agreement (“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 the Company had less than $1 million of available borrowing capacity, including outstanding letters of credit. In February 2014, the Company entered into an amendment to the Credit Facility to amend the terms of certain financial and reporting covenants, and in April 2014, the Company entered into an amendment to the 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 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 Credit Facility and Berry also have the right to request interim borrowing base redeterminations once between scheduled redeterminations. Significant declines in commodity prices may result in a decrease in the borrowing base. The Company’s obligations under the Credit Facility are secured by mortgages on its oil and natural gas properties and other personal property. The Company is required to maintain mortgages on properties representing at least 80% of the present value of its oil and natural gas proved reserves.
	The Company is currently in compliance with all financial and other covenants of the Credit Facility. If an event of default would occur and were continuing, the Company would be unable to make borrowings and its financial condition and liquidity would be adversely affected.
	At the Company’s election, interest on borrowings under the 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 Credit Facility) or a Base Rate (as defined in the Credit Facility) plus an applicable margin between 0.5% and 1.5% per annum (depending on the then-current level of borrowings under the 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. The Company is required to pay a commitment fee to the lenders under the 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 Credit Facility) on the average daily unused amount of the maximum commitment amount of the lenders.
	Senior Notes Due November 2020
	The Company has $300 million in aggregate principal amount of 6.75% senior notes due November 2020 (the “November 2020 Senior Notes”). The November 2020 Senior Notes were recorded at their fair value of $310 million on the acquisition date including a $10 million premium which is being amortized to interest expense over the life of the related notes.
	Senior Notes Due September 2022
	The Company has $599 million aggregate principal amount of 6.375% senior notes due September 2022 (the “September 2022 Senior Notes”). The September 2022 Senior Notes were recorded at their fair value of $607 million on the acquisition date including a $7 million premium which is being amortized to interest expense over the life of the related notes.
	Repurchases of Senior Notes
	In February 2014, in accordance with the indentures related to the senior notes, the Company repurchased through cash tender offers $321,000, $30,000 and $837,000 of its 10.25% senior notes due June 2014 (the “June 2014 Senior Notes”), November 2020 Senior Notes and September 2022 Senior Notes, respectively.
	Payment of Senior Notes Due June 2014
	On May 30, 2014, in accordance with the provisions of the indenture related to its June 2014 Senior Notes, the Company paid in full the remaining outstanding principal amount of approximately $205 million using a cash capital contribution from LINN Energy (see Note 11).
	Senior Notes Covenants
	The Company’s senior notes contain covenants that, among other things, may limit its ability to: (i) incur or guarantee additional indebtedness; (ii) pay distributions on its equity or redeem its subordinated debt; (iii) create certain liens; (iv) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (v) sell assets; (vi) engage in transactions with affiliates; and (vii) consolidate, merge or transfer all or substantially all of the Company’s assets. The Company is in compliance with all financial and other covenants of its senior notes.

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	The Company hedges a significant portion of its forecasted oil production to reduce exposure to commodity price fluctuations and provide long-term cash flow predictability to manage its business. 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 does not directly hedge its NGL production. The Company also, from time to time, enters into derivative contracts for a portion of its natural gas consumption.
	The Company enters into commodity hedging transactions primarily in the form of swap contracts, collars and three-way collars. Swap contracts are designed to provide a fixed price. Collar contracts specify floor and ceiling prices to be received as compared to floating market prices. Three-way collar contracts combine a short put (the lower price), a long put (the middle price) and a short call (the higher price) to provide a higher ceiling price as compared to a regular collar and limit downside risk to the market price plus the difference between the middle price and the lower price if the market price drops below the lower price.
	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. 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 6 for fair value disclosures about oil and natural gas commodity 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 5) on a recurring basis. The Company determines the fair value of its oil and natural gas derivatives utilizing pricing models that use a variety of techniques, including market quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those instruments trade in active markets. Assumed credit risk adjustments, based on published credit ratings, public bond yield spreads and credit default swap spreads, are applied to the Company’s commodity derivatives.
	Fair Value Hierarchy
	In accordance with applicable accounting standards, the Company has categorized its financial instruments, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:
		30-Jun-14
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	17,004	$	(13,724	)	$	3,280
	Liabilities:
	Commodity derivatives	$	45,299	$	(13,724	)	$	31,575
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	28,291	$	(20,184	)	$	8,107
	Liabilities:
	Commodity derivatives	$	45,226	$	(20,184	)	$	25,042
	(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 balance sheets. Accretion expense is included in “depreciation, depletion and amortization” on the 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 Company’s asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	94,830
	Liabilities added from drilling	2,842
	Current year accretion expense	2,649
	Settlements	(3,266		)
	Asset retirement obligations at June 30, 2014	$	97,055

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 disregarded entity for federal and state income tax purposes, with the exception of the state of Texas. As such, with the exception of the state of Texas, 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. Prior to the LINN Energy transaction, the Company was a Subchapter C-corporation subject to federal and state income taxes. Amounts recognized for income taxes purposes are reported in “income tax expense (benefit)” on the condensed statements of operations.

Equity_Incentive_Compensation_

Equity Incentive Compensation Plans	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity Incentive Compensation Plans	'
	Equity Incentive Compensation Plans
	The successor Company does not have any equity incentive compensation (“EIC”) plans under which it grants stock awards and, therefore, recognized no direct stock compensation expense for the six months ended June 30, 2014. Prior to the LINN Energy transaction, the Company granted equity awards to its employees under its EIC plans. The total compensation expense recognized by the predecessor Company in the condensed statements of operations for grants under the Company’s EIC plans was approximately $3 million and $6 million for the three months and six months ended June 30, 2013, respectively. In connection with the LINN Energy transaction, effective December 16, 2013, the predecessor Company’s equity awards were exchanged for LinnCo common shares or LINN Energy equity awards.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	East Texas Gathering System
	The Company has entered into certain long-term natural gas gathering agreements for its east Texas production. The agreements contain embedded leases and the transaction has been accounted for as a financing obligation. The fair value of the property associated with this transaction was recorded in the amount of approximately $13 million and is being depreciated over the remaining useful life of the asset. Under the agreements, portions of the payments are recorded as gathering expense and interest expense with the balance recorded as a reduction to the financing obligation. There are no minimum payments required under these agreements.
	Carry and Earning Agreement
	In January 2011, the Company entered into an amendment relating to certain contractual obligations to a third-party co-owner of certain Piceance Basin assets in Colorado. The amendment waives a $200,000 penalty for each well not spud by February 2011 and requires the Company to reassign to such third party, by January 31, 2020, all of the interest acquired by the Company from the third party in each 160-acre tract in which the Company has not drilled and completed a well that is producing or capable of producing from a designated formation, or deeper formation, on January 1, 2020. The amendment also requires the Company to pay the first $9 million of costs incurred in connection with the construction of either an extension of the existing access road or a new access road, including the third party’s 50% share. Pursuant to the terms of a further amendment entered into in April 2014, if by September 30, 2015, the Company does not expend $9 million on the construction of either the extension of the road or a new road, the Company is obligated to pay the third party 50% of the difference between $12 million and the actual amount expended on road construction as of such date. Under the terms of the 2014 amendment, this deadline is subject to further extension to no later than December 31, 2015. Due to the need to obtain regulatory approvals, among other reasons, the Company has not yet commenced construction of either an extension of the existing access road or a new access road and may be unable to do so by the extended deadline, thus triggering the payment obligation to the third party.
	Legal Matters
	Department of the Interior Notice of Proposed Debarment
	On June 14, 2012, the Company received a Notice of Proposed Debarment issued by the United States Department of the Interior (“DOI”). Pursuant to the notice, the DOI’s Office of the Inspector General proposed to debar the Company from participation in certain federal contracts and assistance activities, including oil and natural gas leases, for a period of three years. The basis for the proposed debarment relates to the Company’s purported noncompliance with Bureau of Land Management (“BLM”) regulations relating to the operation of certain equipment, and the submission of related site facility diagrams, in its Uinta operations. In 2011, the Company entered into a settlement agreement with the BLM and paid a $2 million civil penalty relating to the matter. The Company contested the proposed debarment and believes the matter is without merit; nevertheless, in June 2013, the Company entered into an agreement with the DOI to resolve the matter administratively through an independent compliance review. The independent compliance review has concluded and the final compliance review reports have been submitted to the DOI. The Company has been informed that the DOI intends to make follow-up inquiries to the Company in the near future, but has not received any further communications to date.
	Royalty Class Action
	The Company is 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, the Company anticipates distribution of settlement funds to begin late in the third quarter or early fourth quarter of 2014.
	Other
	The Company is involved in various other lawsuits, claims and inquiries, most of which are routine to the nature of its business. In the opinion of management, the resolution of these matters will not have a material adverse effect on its business, financial condition, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved.
	During the three months and 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.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	LINN Energy
	All former employees of the Company that were retained after the LINN Energy transaction are now employed by Linn Operating, Inc. (“LOI”), a subsidiary of LINN Energy, and along with other LOI personnel, provide services and support to the Company in accordance with an agency agreement and power of attorney between the Company and LOI. For the three months and six months ended June 30, 2014, the Company incurred management fee expenses of approximately $24 million and $60 million, respectively, for services provided by LOI.
	During the second quarter of 2014, LINN Energy made a cash capital contribution of $220 million to the Company which was used to pay in full the remaining outstanding principal amount of its approximately $205 million June 2014 Senior Notes plus accrued interest. During the same period, the Company made a cash distribution of approximately $42 million to LINN Energy. The Company also has affiliated accounts payable due to LOI of approximately $26 million and $17 million at June 30, 2014, and December 31, 2013, respectively, included in “accounts payable and accrued expenses” on the condensed balance sheets.
	Other
	One of LINN Energy’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 $98,000 and $176,000, respectively, to Superior or 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.

Supplemental_Disclosures_to_th

Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows	6 Months Ended
	Jun. 30, 2014
Supplemental disclosures to the condensed balance sheets and condensed statements of cash flows [Abstract]	'
Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows	'
	Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows
	“Other current assets” reported on the condensed balance sheets primarily consist of inventories. “Other accrued liabilities” reported on the condensed balance sheets include the following:
		30-Jun-14		31-Dec-13
		(in thousands)
	Accrued interest	$	16,232	$	18,926
	Accrued compensation	—		6,749
	Asset retirement obligations (current portion)	3,318		3,318
	Other	10		—
		$	19,560	$	28,993
	Supplemental disclosures to the condensed statements of cash flows are presented below:
		Successor			Predecessor
		Six Months Ended			Six Months Ended
		30-Jun-14			30-Jun-13
	(in thousands)
	Cash payments for interest, net of amounts capitalized	$	55,751		$	43,197
	Cash payments for income taxes	$	—		$	600
	Noncash investing activities:
	Accrued capital expenditures	$	38,969		$	40,607
	Asset retirement obligations	$	2,842		$	10,607

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2014
Basis of Presentation [Abstract]	'
Principles of Reporting	'
	Principles of 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 financial statements should not necessarily be taken as indicative of results that may be expected for the entire year.
	Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method.
	The 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), member’s equity or cash flows.
Use of Estimates	'
	Use of Estimates
	The preparation of the accompanying condensed 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 financial statements and related disclosures.

Oil_and_Natural_Gas_Properties1

Oil and Natural Gas Properties (Tables)	6 Months Ended
	Jun. 30, 2014
Oil and Natural Gas Properties [Abstract]	'
Capitalized Costs Relating to Oil and Natural Gas Producing Activities Disclosure	'
	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
		30-Jun-14			31-Dec-13
		(in thousands)
	Oil and natural gas:
	Proved properties	$	3,755,393		$	3,397,785
	Unproved properties	1,370,732			1,415,874
		5,126,125			4,813,659
	Less accumulated depletion and amortization	(150,631		)	(10,394		)
		$	4,975,494		$	4,803,265

Debt_Tables

Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments	'
	The following summarizes the Company’s outstanding debt:
		30-Jun-14		31-Dec-13
		(in thousands, except percentages)
	Credit facility (1)	$	1,173,175	$	1,173,175
	10.25% senior notes due June 2014	—		205,257
	6.75% senior notes due November 2020	299,970		300,000
	6.375% senior notes due September 2022	599,163		600,000
	Net unamortized premiums	15,547		22,729
	Total debt, net	2,087,855		2,301,161
	Less current maturities	—		(211,558		)
	Total long-term debt, net	$	2,087,855	$	2,089,603
	(1)	Variable interest rates of 2.66% 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					31-Dec-13
		Carrying Value		Fair Value			Carrying Value		Fair Value
		(in thousands)
	Credit facility	$	1,173,175	$	1,173,175		$	1,173,175	$	1,173,175
	Senior notes, net	914,680		948,212			1,127,986		1,128,527
	Total debt, net	$	2,087,855	$	2,121,387		$	2,301,161	$	2,301,702

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Summary of derivatives instruments	'
	The following table summarizes derivative positions for the periods indicated as of June 30, 2014:
		July 1 - December 31, 2014		2015
	Oil positions:
	Fixed price swaps (NYMEX WTI):
	Hedged volume (MBbls)	2,484		—
	Average price ($/Bbl)	$	91.26	$	—
	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
	Three-way collars (ICE Brent):
	Hedged volume (MBbls)	184		—
	Short put ($/Bbl)	$	80	$	—
	Long put ($/Bbl)	$	100	$	—
	Short call ($/Bbl)	$	114.05	$	—
	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): (1)
	Hedged volume (MBbls)	920		—
	Hedged differential ($/Bbl)	$	0.32	$	—
	(1)	The Company hedges the timing risk associated with the sales price of oil in the Permian Basin. In this operating area, 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”).
Schedule of derivatives assets and liabilities	'
	The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed balance sheets. The following summarizes the fair value of derivatives outstanding on a gross basis:
		30-Jun-14		31-Dec-13
		(in thousands)
	Assets:
	Commodity derivatives	$	17,004	$	28,291
	Liabilities:
	Commodity derivatives	$	45,299	$	45,226

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 on a 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	$	17,004	$	(13,724	)	$	3,280
	Liabilities:
	Commodity derivatives	$	45,299	$	(13,724	)	$	31,575
		31-Dec-13
		Level 2		Netting (1)			Total
		(in thousands)
	Assets:
	Commodity derivatives	$	28,291	$	(20,184	)	$	8,107
	Liabilities:
	Commodity derivatives	$	45,226	$	(20,184	)	$	25,042
	(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]	'
Summary of change in asset retirement obligations	'
	The following presents a reconciliation of the Company’s asset retirement obligations (in thousands):
	Asset retirement obligations at December 31, 2013	$	94,830
	Liabilities added from drilling	2,842
	Current year accretion expense	2,649
	Settlements	(3,266		)
	Asset retirement obligations at June 30, 2014	$	97,055

Supplemental_Disclosures_to_th1

Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows (Tables)	6 Months Ended
	Jun. 30, 2014
Supplemental disclosures to the condensed balance sheets and condensed statements of cash flows [Abstract]	'
Schedule of Accrued Liabilities	'
	“Other accrued liabilities” reported on the condensed balance sheets include the following:
		30-Jun-14		31-Dec-13
		(in thousands)
	Accrued interest	$	16,232	$	18,926
	Accrued compensation	—		6,749
	Asset retirement obligations (current portion)	3,318		3,318
	Other	10		—
		$	19,560	$	28,993
Supplemental Cash Flow Disclosures	'
	Supplemental disclosures to the condensed statements of cash flows are presented below:
		Successor			Predecessor
		Six Months Ended			Six Months Ended
		30-Jun-14			30-Jun-13
	(in thousands)
	Cash payments for interest, net of amounts capitalized	$	55,751		$	43,197
	Cash payments for income taxes	$	—		$	600
	Noncash investing activities:
	Accrued capital expenditures	$	38,969		$	40,607
	Asset retirement obligations	$	2,842		$	10,607

Properties_Exchange_and_LINN_E1

Properties Exchange and LINN Energy Transaction (Details) (USD $)	0 Months Ended
	Dec. 16, 2013
Berry and LinnCo	'
LINN Energy Transaction	'
Exchange ratio	168.00%
Number of shares issued	93,756,674
LINN Energy LLC and LinnCo	'
LINN Energy Transaction	'
Number of shares issued	93,756,674
LINN Transaction	'
LINN Energy Transaction	'
Preliminary value of transaction	4,600,000,000
Debt assumed in transaction, including current portion	2,300,000,000
Cash assumed in transaction	451,000,000

Oil_and_Natural_Gas_Properties2

Oil and Natural Gas Properties (Details) (Successor, USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Successor	'	'
Oil and natural gas:	'	'
Proved properties	$3,755,393	$3,397,785
Unproved properties	1,370,732	1,415,874
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, net	$4,975,494	$4,803,265

Debt_Details

Debt (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013		Dec. 16, 2013
In Thousands, unless otherwise specified
Debt Instruments [Abstract]	'		'		'
Senior notes	$914,680		$1,127,986		'
Net unamortized premiums	15,547		22,729		'
Total debt, net	2,087,855		2,301,161		'
Less current maturities	0		-211,558		'
Total long-term debt, net	2,087,855		2,089,603		'
Credit Facility	'		'		'
Debt Instruments [Abstract]	'		'		'
Credit facility	1,173,175	[1]	1,173,175	[1]	'
June 2014 Senior Notes	'		'		'
Debt Instruments [Abstract]	'		'		'
Senior notes	0		205,257		'
November 2020 Senior Notes	'		'		'
Debt Instruments [Abstract]	'		'		'
Senior notes	299,970		300,000		'
Net unamortized premiums	'		'		10,000
September 2022 Senior Notes	'		'		'
Debt Instruments [Abstract]	'		'		'
Senior notes	599,163		600,000		'
Net unamortized premiums	'		'		$7,000
Credit Facility	'		'		'
Debt Instruments [Abstract]	'		'		'
Debt Instrument, Interest Rate at Period End	2.66%		2.67%		'
[1]	(1) Variable interest rates of 2.66% and 2.67% at June 30, 2014, and December 31, 2013, respectively.

Debt_Details_2

Debt (Details 2) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Feb. 28, 2014

Jun. 30, 2014

Dec. 31, 2013

Feb. 28, 2014

Jun. 30, 2014

Dec. 31, 2013

Dec. 16, 2013

Feb. 28, 2014

Jun. 30, 2014

Dec. 31, 2013

Dec. 16, 2013

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Credit Facility

Credit Facility

June 2014 Senior Notes

June 2014 Senior Notes

June 2014 Senior Notes

November 2020 Senior Notes

November 2020 Senior Notes

November 2020 Senior Notes

November 2020 Senior Notes

September 2022 Senior Notes

September 2022 Senior Notes

September 2022 Senior Notes

September 2022 Senior Notes

Gross

Low end of the range

High end of the range

LIBOR

LIBOR

Prime

Prime

June 2014 Senior Notes

Credit Facility

Credit Facility

Low end of the range

High end of the range

Low end of the range

High end of the range

Credit Facility

Credit Facility

Credit Facility

Credit Facility

Debt Instrument, Fair Value Disclosure [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility

'

'

$1,173,175,000

[1]

$1,173,175,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility

1,173,175,000

1,173,175,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes, net

914,680,000

1,127,986,000

'

'

'

0

205,257,000

'

299,970,000

300,000,000

'

'

599,163,000

600,000,000

'

'

'

'

'

'

'

'

Senior notes, net

948,212,000

1,128,527,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total debt, net

2,087,855,000

2,301,161,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total debt, net

2,121,387,000

2,301,702,000

'

'

'

'

'

'

'

'

310,000,000

'

'

'

607,000,000

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

1,400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Agreement Lender Commitment Amount

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LineOfCreditFacilityPortionOfPropertiesRequiredToMaintainMortgages

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

2.50%

0.50%

1.50%

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

300,000,000

'

'

'

599,000,000

'

'

205,000,000

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

10.25%

'

'

6.75%

'

'

'

6.38%

'

'

'

'

'

'

'

'

'

Net unamortized premiums

15,547,000

22,729,000

'

'

'

'

'

'

'

'

10,000,000

'

'

'

7,000,000

'

'

'

'

'

'

'

Extinguishment of Debt, Amount

'

'

'

'

$321,000

'

'

$30,000

'

'

'

$837,000

'

'

'

'

'

'

'

'

'

'

[1]

(1) Variable interest rates of 2.66% and 2.67% at June 30, 2014, and December 31, 2013, respectively.

Derivative_Instruments_Details

Derivative Instruments (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
2014 | Oil derivative instruments | Swap	'		'
Derivative	'		'
Hedged volume (MBbls)	2,484		'
Average price ($/Bbl)	91.26		'
2014 | Oil derivative instruments | Crude Oil Sales - Collars	'		'
Derivative	'		'
Hedged volume (MBbls)	368		'
Derivative, floor price ($/Bbl)	90		'
Derivative, cap price ($/Bbl)	102.87		'
2014 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Hedged volume (MBbls)	1,564		'
2014 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Hedged volume (MBbls)	184		'
2014 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	72.11		'
Derivative, cap price ($/Bbl)	109.79		'
2014 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	80		'
Derivative, cap price ($/Bbl)	114.05		'
2014 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	93.76		'
2014 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	100		'
2014 | Oil basis differential commodity contract | ICE Brent - NYMEX WTI basis swaps	'		'
Derivative	'		'
Hedged volume (MBbls)	1,840		'
Hedged differential ($/Bbl)	11.6		'
2014 | Oil timing differential positions | Trade month roll swaps	'		'
Derivative	'		'
Hedged volume (MBbls)	920	[1]	'
Hedged differential ($/Bbl)	0.32	[1]	'
2015 | Oil derivative instruments | Swap	'		'
Derivative	'		'
Hedged volume (MBbls)	0		'
Average price ($/Bbl)	0		'
2015 | Oil derivative instruments | Crude Oil Sales - Collars	'		'
Derivative	'		'
Hedged volume (MBbls)	0		'
Derivative, floor price ($/Bbl)	0		'
Derivative, cap price ($/Bbl)	0		'
2015 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Hedged volume (MBbls)	1,095		'
2015 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Hedged volume (MBbls)	0		'
2015 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	70		'
Derivative, cap price ($/Bbl)	101.62		'
2015 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	0		'
Derivative, cap price ($/Bbl)	0		'
2015 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 1	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	90		'
2015 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 2	'		'
Derivative	'		'
Derivative, floor price ($/Bbl)	0		'
2015 | Oil basis differential commodity contract | ICE Brent - NYMEX WTI basis swaps	'		'
Derivative	'		'
Hedged volume (MBbls)	2,920		'
Hedged differential ($/Bbl)	11.6		'
2015 | Oil timing differential positions | Trade month roll swaps	'		'
Derivative	'		'
Hedged volume (MBbls)	0	[1]	'
Hedged differential ($/Bbl)	0	[1]	'
Fair Value, Inputs, Level 2	'		'
Derivative	'		'
Commodity derivatives	$17,004		$28,291
Commodity derivatives	$45,299		$45,226
[1]	(1) The Company hedges the timing risk associated with the sales price of oil in the Permian Basin. In this operating area, 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”).

Derivative_Instruments_Details1

Derivative Instruments (Details 2) (USD $)	3 Months Ended	6 Months Ended	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2013
	Successor	Successor	Predecessor	Predecessor
	MBbl	MBbl
Derivative	'	'	'	'
Volume of oil on settled derivatives (MBbls)	2,275	4,525	'	'
Average contract price on oil settled derivatives per unit ($/Bbl)	92.16	92.16	'	'
Maximum loss if all counterparties fail	'	$17,000,000	'	'
Gains (losses) on oil and natural gas derivatives	-25,562,000	-22,097,000	35,622,000	34,885,000
Cash settlements	($8,082,000)	($10,472,000)	$2,435,000	$4,844,000

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 and liabilities measured at fair value on a recurring basis	'		'
Commodity derivatives assets, net	$3,280		$8,107
Commodity derivative liability, net	31,575		25,042
Fair Value, Inputs, Level 2	'		'
Assets and liabilities measured at fair value on a recurring basis	'		'
Commodity derivatives, gross asset	17,004		28,291
Commodity derivatives	45,299		45,226
Counterparty netting under agreements governing derivatives	'		'
Assets and liabilities measured at fair value on a recurring basis	'		'
Commodity derivatives assets, netting	-13,724	[1]	-20,184	[1]
Commodity derivatives liability, netting	($13,724)	[1]	($20,184)	[1]
[1]	(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 Obligations	'
Asset Retirement Obligation Future Inflation Factor	2.00%
Fair Value Inputs, Discount Rate	5.40%
Change in the asset retirement obligations	'
Asset retirement obligations at December 31, 2013	$94,830
Liabilities added from drilling	2,842
Current year accretion expense	2,649
Settlements	-3,266
Asset retirement obligations at June 30, 2014	$97,055

Equity_Incentive_Compensation_1

Equity Incentive Compensation Plans (Details) (USD $)	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'	'	'
Total compensation cost	$3	$0	$6

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	3 Months Ended		6 Months Ended				12 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 16, 2013	Jan. 14, 2011	Dec. 31, 2011
						Carry And Earning Agreement	Non Compliance To Regulations
						acre
Commitments and Contingencies	'	'	'	'	'	'	'
Fair value of gathering system	'	'	'	'	$13,000,000	'	'
Contractual Obligation Amount, Penalty Waived Per Well	'	'	'	'	'	200,000	'
Litigation settlement expense	'	'	'	'	'	'	2,000,000
Litigation Settlement, Amount	'	'	2,400,000	'	'	'	'
E. Texas Gathering System	'	'	'	'	'	'	'
Contractual obligation, acre of tracts	'	'	'	'	'	160	'
Contractual obligation, contingent construction expense	'	'	'	'	'	9,000,000	'
Penalty payable as a percentage of the difference between specified amount and actual expended (as a percent)	'	'	'	'	'	50.00%	'
Contractual obligation, specified amount for penalty calculation	'	'	'	'	'	12,000,000	'
Third party share of construction costs, percentage	'	'	'	'	'	50.00%	'
Payments for Legal Settlements	$0	$0	$0	$0	'	'	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (Successor, USD $)	6 Months Ended			3 Months Ended	6 Months Ended	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
			June 2014 Senior Notes	Linn Operating, Inc.	Linn Operating, Inc.	Linn Energy, LLC [Member]	Superior Energy Services, Inc.	Superior Energy Services, Inc.
Related Party Transactions	'	'	'	'	'	'	'	'
Due to Affiliate, Current	'	'	'	$26,000,000	$26,000,000	'	'	'
Management fee expense	'	'	'	24,000,000	60,000,000	'	'	'
Capital contribution from affiliate	220,000,000	'	'	'	'	220,000,000	'	'
Debt Instrument, Face Amount	'	'	205,000,000	'	'	'	'	'
Payments of Distributions to Affiliates	41,537,000	'	'	'	'	'	'	'
Senior notes, current	0	211,558,000	'	'	'	'	'	'
Amount of related party transaction	'	'	'	'	'	'	$98,000	$176,000

Supplemental_Disclosures_to_th2

Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Accrued Liabilities [Abstract]	'	'	'
Accrued interest	$16,232	'	$18,926
Accrued compensation	0	'	6,749
Asset retirement obligations (current portion)	3,318	'	3,318
Other	10	'	0
Other accrued liabilities	19,560	'	28,993
Supplemental Cash Flow Information [Abstract]	'	'	'
Cash payments for interest, net of amounts capitalized	55,751	43,197	'
Cash payments for income taxes	0	600	'
Noncash investing activities [Abstract]	'	'	'
Accrued capital expenditures	38,969	40,607	'
Asset retirement obligations	$2,842	$10,607	'