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Document and Entity Information	6 Months Ended
Document and Entity Information	Jun. 30, 2015 shares
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	Jun. 30, 2015
Amendment Flag	false
Entity Common Stock, Shares Outstanding	0
Entity Filer Category	Non-accelerated Filer
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	Yes
Entity Current Reporting Status	Yes

Condensed Balance Sheets (unaudited) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 2,664	$ 1,586
Accounts receivable – trade, net	83,314	100,359
Derivative instruments	15,534	43,694
Other current assets	43,238	59,259
Total current assets	144,750	204,898
Noncurrent assets:
Oil and natural gas properties (successful efforts method)	4,967,722	4,872,059
Less accumulated depletion and amortization	(923,731)	(525,007)
Oil and natural gas properties, successful efforts method, net	4,043,991	4,347,052
Other property and equipment	121,511	115,999
Less accumulated depreciation	(13,749)	(8,452)
Other property and equipment, net	107,762	107,547
Derivative instruments	976	0
Advance to affiliate	171,044	293,627
Restricted cash	250,162	125
Other noncurrent assets	11,587	14,159
Noncurrent assets, excluding property, total	433,769	307,911
Total noncurrent assets	4,585,522	4,762,510
Total assets	4,730,272	4,967,408
Current liabilities:
Accounts payable and accrued expenses	218,534	242,350
Derivative instruments	3,333	0
Other accrued liabilities	17,798	19,087
Total current liabilities	239,665	261,437
Noncurrent liabilities:
Credit facility	1,173,175	1,173,175
Senior notes, net	860,680	913,777
Derivative instruments	588	0
Other noncurrent liabilities	195,940	200,015
Total noncurrent liabilities	2,230,383	2,286,967
Commitments and contingencies (Note 7)
Member’s equity:
Additional paid-in capital	2,609,158	2,416,381
Accumulated income (deficit)	(348,934)	2,623
Total member's equity	2,260,224	2,419,004
Total liabilities and member’s equity	$ 4,730,272	$ 4,967,408

Condensed Statements of Operations (unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues and other:
Oil, natural gas and natural gas liquids sales	$ 173,381	$ 360,380	$ 329,967	$ 693,496
Electricity sales	6,609	10,192	11,760	20,161
Losses on oil and natural gas derivatives	(4,474)	(25,562)	(1,207)	(22,097)
Marketing revenues	839	2,242	3,220	7,088
Other revenues	1,535	9	3,431	(7)
Total revenues	177,890	347,261	347,171	698,641
Expenses:
Lease operating expenses	49,896	93,354	117,085	183,385
Electricity generation expenses	4,993	7,629	9,563	16,012
Transportation expenses	12,978	7,483	25,584	15,476
Marketing expenses	1,005	2,096	2,080	4,694
General and administrative expenses	37,102	28,322	58,289	71,813
Depreciation, depletion and amortization	63,052	77,753	136,031	146,384
Impairment of long-lived assets	0	0	272,000	0
Taxes, other than income taxes	22,196	23,479	45,528	46,508
(Gains) losses on sale of assets and other, net	(811)	4,257	(5,284)	7,624
Total expenses	190,411	244,373	660,876	491,896
Other income and (expenses):
Interest expense, net of amounts capitalized	(22,690)	(23,486)	(44,111)	(47,487)
Gain on extinguishment of debt	6,831	0	6,831	0
Other, net	(463)	(445)	(633)	(634)
Total other income and (expenses)	(16,322)	(23,931)	(37,913)	(48,121)
Income (loss) before income taxes	(28,843)	78,957	(351,618)	158,624
Income tax benefit	(11)	(51)	(61)	(82)
Net income (loss)	$ (28,832)	$ 79,008	$ (351,557)	$ 158,706

Condensed Statement of Member's Equity (unaudited) - 6 months ended Jun. 30, 2015 - USD ($) $ in Thousands	Total	Additional paid-in capital	Accumulated income (deficit)
Members' Equity at Dec. 31, 2014	$ 2,419,004	$ 2,416,381	$ 2,623
Capital contribution from affiliate	250,000	250,000	0
Distributions to affiliate	(57,223)	(57,223)	0
Net loss	(351,557)	0	(351,557)
Members' Equity at Jun. 30, 2015	$ 2,260,224	$ 2,609,158	$ (348,934)

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

+ References + Details

Condensed Statements of Cash Flows (unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flow from operating activities:
Net income (loss)	$ (351,557)	$ 158,706
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	136,031	146,384
Impairment of long-lived assets	272,000	0
Gain on extinguishment of debt	(6,831)	0
Amortization and write-off of deferred financing fees	854	(5,492)
Gains on sale of assets and other, net	(2,991)	0
Deferred income taxes	(61)	(82)
Derivatives activities:
Total (gains) losses	(1,853)	22,097
Cash settlements	32,943	(10,472)
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	15,281	(34,294)
Decrease in other assets	3,515	1,486
Increase in accounts payable and accrued expenses	11,378	11,869
Decrease in other liabilities	(10,310)	(25,473)
Net cash provided by operating activities	98,399	264,729
Cash flow from investing activities:
Development of oil and natural gas properties	(3,076)	(269,129)
Purchases of other property and equipment	(2,982)	(5,625)
Proceeds from sale of properties and equipment and other	11,302	0
Net cash provided by (used in) investing activities	5,244	(274,754)
Cash flow from financing activities:
Repayments of debt	(45,353)	(206,124)
Financing fees and other, net	11	(10,866)
Capital contribution from affiliate	0	220,000
Distributions to affiliate	(57,223)	(41,537)
Net cash used in financing activities	(102,565)	(38,527)
Net increase (decrease) in cash and cash equivalents	1,078	(48,552)
Cash and cash equivalents:
Beginning	1,586	51,041
Ending	$ 2,664	$ 2,489

Basis of Presentation	6 Months Ended
Basis of Presentation	Jun. 30, 2015
Basis of Presentation [Abstract]
Basis of Presentation	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. 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 (San Joaquin Valley and Los Angeles basins), Kansas and the Oklahoma Panhandle (Hugoton Basin), Utah (Uinta Basin), Colorado (Piceance Basin) and east Texas. In August and November of 2014, the Company divested all of its properties located in the Permian 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, 2014. 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 condensed 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 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 April 2015, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify the presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2015, and interim periods within those years (early adoption permitted). The Company does not expect the adoption of this ASU to have a material impact on its financial statements. In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 2017, and interim periods within those years (early adoption permitted for fiscal years beginning after December 15, 2016, including interim periods within that year). 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 Properties

6 Months Ended

Jun. 30, 2015

Oil and Natural Gas Properties [Abstract]

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, 2015			December 31, 2014
	(in thousands)
Oil and natural gas:
Proved properties	$	4,128,644		$	4,025,595
Unproved properties	839,078			846,464
	4,967,722			4,872,059
Less accumulated depletion and amortization	(923,731		)	(525,007		)
	$	4,043,991		$	4,347,052

Impairment of Proved Properties

The Company evaluates the impairment of its proved oil and natural gas properties on a field-by-field basis whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of proved properties are reduced to fair value when the expected undiscounted future cash flows of proved and risk-adjusted probable and possible reserves are less than net book value. The fair values of proved properties are measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount. Significant inputs used to determine the fair values of proved properties include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.

Based on the analysis described above, the Company recorded no impairment charges for the three months ended June 30, 2015, or the six months ended June 30, 2014. During the first quarter of 2015, the Company recorded noncash impairment charges, before and after tax, of approximately $272 million associated with proved oil and natural gas properties. The impairment was due to a decline in commodity prices. The carrying values of the impaired proved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair value measurement. For the six months ended June 30, 2015, the following impairment charges are included in “impairment of long-lived assets” on the condensed statement of operations:


•	California operating area – $207 million; and


•	East Texas operating area – $65 million.

Debt

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Debt

The following summarizes the Company’s outstanding debt:



	June 30, 2015		December 31, 2014
	(in thousands, except percentages)

Credit facility ⁽¹⁾	$	1,173,175	$	1,173,175
6.75% senior notes due November 2020	275,177		299,970
6.375% senior notes due September 2022	572,700		599,163
Net unamortized premiums	12,803		14,644
Total debt, net	2,033,855		2,086,952
Less current maturities	—		—
Total long-term debt, net	$	2,033,855	$	2,086,952


⁽¹⁾	Variable interest rates of 2.69% and 2.67% at June 30, 2015, and December 31, 2014, 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.



	June 30, 2015				December 31, 2014
	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	860,680		664,672		913,777		699,462
Total debt, net	$	2,033,855	$	1,837,847	$	2,086,952	$	1,872,637

Credit Facility

The Company’s Second Amended and Restated Credit Agreement (“Credit Facility”) currently has a borrowing base of $1.2 billion, subject to lender commitments. The maturity date is April 2019. At June 30, 2015, lender commitments under the facility were $1.2 billion but there was less than $1 million of available borrowing capacity, including outstanding letters of credit.

Redetermination of the borrowing base under the Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. A super-majority of the lenders under the Credit Facility and Berry also have the right to request interim borrowing base redeterminations once between scheduled redeterminations. The spring 2015 semi-annual borrowing base redetermination was completed in May 2015, and the borrowing base under the Credit Facility decreased from $1.4 billion to $1.2 billion as a result of lower commodity prices. Continued low or further declining commodity prices, reductions in the Company’s capital budget and the resulting reserve write-downs are expected to result in further decreases in the borrowing base at the October 2015 redetermination and may also impact future redeterminations.

In connection with the reduction in Berry’s borrowing base, LINN Energy contributed $250 million to Berry to post as restricted cash with Berry’s lenders. As directed by LINN Energy, the $250 million was deposited on Berry’s behalf in a security account with the administrative agent subject to a security control agreement. Berry’s ability to withdraw funds from this account is subject to a concurrent reduction of the borrowing base under the Credit Facility or lender consent in connection with a redetermination of such borrowing base. The $250 million may be used to satisfy obligations under the Credit Facility or, subject to restrictions in the indentures governing Berry’s senior notes, may be returned to LINN Energy in the future. The amount is included in “restricted cash” on the condensed balance sheet.

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 in compliance with all financial and other covenants of the Credit Facility.

At the Company’s election, interest on borrowings under the 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 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 the 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.

Repurchases of Senior Notes

During the six months ended June 30, 2015, the Company repurchased on the open market approximately $51 million of its outstanding senior notes. The Company repurchased approximately $25 million and $26 million of its 6.75% senior notes due November 2020 and 6.375% senior notes due September 2022, respectively. In connection with the repurchases, the Company recorded a gain on extinguishment of debt of approximately $7 million for the six months ended June 30, 2015.

Repurchases of Senior Notes – Subsequent Event

In July 2015, the Company repurchased through a privately negotiated transaction approximately $14 million of its 6.75% senior notes due November 2020.

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 or dividends 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.

In addition, any cash generated by the Company is currently being used by the Company to fund its activities. To the extent that the Company generates cash in excess of its needs, the indentures governing its senior notes limit the amount it may distribute to LINN Energy to the amount available under a “restricted payments basket,” and the Company may not distribute any such amounts unless it is permitted by the indentures to incur additional debt pursuant to the consolidated coverage ratio test set forth in the Company’s indentures. The Company’s restricted payments basket may be increased in accordance with the terms of the Company’s indentures by, among other things, 50% of the Company’s future net income, reductions in its indebtedness and restricted investments, and future capital contributions.

The Company may from time to time seek to repurchase its outstanding debt through open market purchases, privately negotiated transactions or otherwise. Such repurchases, if any, may be material and will depend on prevailing market conditions, the Company’s liquidity requirements, contractual restrictions and other factors.

Derivative Instruments

6 Months Ended

Jun. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

The Company hedges a portion of its forecasted production to reduce exposure to commodity price fluctuations and provide long-term cash flow predictability to manage its business. The Company also, from time to time, enters into derivative contracts for a portion of its natural gas consumption. The direct NGL hedging market has been 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, the Company has not directly hedged its NGL production. The Company also hedges its exposure to natural gas differentials in certain operating areas but does not currently hedge exposure to oil differentials.

The Company enters into commodity hedging transactions primarily in the form of swap contracts, 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 or consumption to provide an economic hedge of the risk related to the future commodity prices received or paid. The Company does not enter into derivative contracts for trading purposes. The Company did not designate any of its contracts as cash flow hedges; therefore, the changes in fair value of these instruments are recorded in current earnings. See Note 5 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, 2015:



	July 1 - December 31, 2015			2016
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls)	1,963			—
Average price ($/Bbl)	$	59.97		$	—
Three-way collars (NYMEX WTI):
Hedged volume (MBbls)	552			—
Short put ($/Bbl)	$	70.00		$	—
Long put ($/Bbl)	$	90.00		$	—
Short call ($/Bbl)	$	101.62		$	—
Natural gas basis differential positions: ⁽¹⁾
NWPL Rockies basis swaps: ⁽²⁾
Hedged volume (MMMBtu)	5,152			11,712
Hedged differential ($/MMBtu)	$	(0.34	)	$	(0.34	)
SoCal basis swaps: ⁽³⁾
Hedged volume (MMMBtu)	16,560			32,940
Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.03	)


⁽¹⁾	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.


⁽²⁾	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.


⁽³⁾	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.

During the six months ended June 30, 2015, the Company entered into commodity derivative contracts consisting of natural gas basis swaps for May 2015 through December 2016, to hedge exposure to differentials in certain producing areas, and oil swaps for April 2015 through December 2015. In addition, the Company entered into natural gas basis swaps for May 2015 through December 2016 to hedge exposure to the differential in California, where it consumes natural gas in its heavy oil development operations.

Settled derivatives on oil production for the three months and six months ended June 30, 2015, included volumes of 1,074 MBbls and 1,344 MBbls, respectively, at average contract prices of $66.75 per Bbl and $70.86 per Bbl. Settled derivatives on oil production for the three months and six months ended June 30, 2014, included volumes of 2,275 MBbls and 4,525 MBbls, respectively, at an average contract price of $92.16 per Bbl. The oil derivatives are settled based on the average closing price of NYMEX WTI crude oil for each day of the delivery month.

Balance Sheet Presentation

The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed balance sheets. The following summarizes the fair value of derivatives outstanding on a gross basis:



	June 30, 2015		December 31, 2014
	(in thousands)
Assets:
Commodity derivatives	$	23,636	$	60,843
Liabilities:
Commodity derivatives	$	11,047	$	17,149

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 Facility or were participants or affiliates of participants in its Credit Facility at the time it originally entered into the derivatives. The Credit Facility is 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 $24 million at June 30, 2015. The Company minimizes the credit risk in derivative instruments by: (i) limiting its exposure to any single counterparty; (ii) entering into derivative instruments only with counterparties that meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity derivatives are subject to counterparty netting under agreements governing such derivatives and therefore the risk of loss due to counterparty nonperformance is somewhat mitigated.

Gains (Losses) on Derivatives

A summary of gains and losses on derivatives included on the condensed statements of operations is presented below:



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(in thousands)

Losses on oil and natural gas derivatives	$	(4,474	)	$	(25,562	)	$	(1,207	)	$	(22,097	)
Lease operating expenses ⁽¹⁾	3,986			—			3,060			—
Total gains (losses) on oil and natural gas derivatives	$	(488	)	$	(25,562	)	$	1,853		$	(22,097	)


⁽¹⁾	Consists of gains and losses on derivatives used to hedge natural gas consumption which were entered into in March 2015.

For the three months and six months ended June 30, 2015, the Company received net cash settlements of approximately $5 million and $33 million, respectively. For the three months and six months ended June 30, 2014, the Company paid net cash settlements of approximately $8 million and $11 million, respectively.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 30
-Section 45
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-URI http://asc.fasb.org/extlink&oid=6441202&loc=d3e80720-113993

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
-Topic 815
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-Section 50
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-URI http://asc.fasb.org/extlink&oid=35736893&loc=d3e80784-113994

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+ Details

Fair Value Measurements on a Recurring Basis

6 Months Ended

Jun. 30, 2015

Fair Value Disclosures [Abstract]

Fair Value Measurements on a Recurring Basis

The Company accounts for its commodity derivatives at fair value (see Note 4) 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:



	June 30, 2015
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	23,636	$	(7,126	)	$	16,510
Liabilities:
Commodity derivatives	$	11,047	$	(7,126	)	$	3,921



	December 31, 2014
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	60,843	$	(17,149	)	$	43,694
Liabilities:
Commodity derivatives	$	17,149	$	(17,149	)	$	—


⁽¹⁾	Represents counterparty netting under agreements governing such derivatives.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Asset Retirement Obligations

6 Months Ended

Jun. 30, 2015

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

The Company has the obligation to plug and abandon oil and natural gas wells and related equipment at the end of production operations. Estimated asset retirement costs are recognized as liabilities with an increase to the carrying amounts of the related long-lived assets when the obligation is incurred. The liabilities are included in “other accrued liabilities” and “other noncurrent liabilities” on the condensed 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% for the six months ended June 30, 2015); and (iv) a credit-adjusted risk-free interest rate (average of 5.5% for the six months ended June 30, 2015). These inputs require significant judgments and estimates by the Company’s management at the time of the valuation and are the most sensitive and subject to change.

The following presents a reconciliation of the Company’s asset retirement obligations (in thousands):



Asset retirement obligations at December 31, 2014	$	121,760
Liabilities added from drilling	1,030
Current year accretion expense	3,340
Settlements	(284		)
Asset retirement obligations at June 30, 2015	$	125,846

Commitments and Contingencies	6 Months Ended
Commitments and Contingencies	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies East Texas Gathering System The Company is party to certain long-term natural gas gathering agreements for its East Texas production. The agreements contain embedded leases and the transaction was accounted for as a financing obligation. The asset is being depreciated over the remaining useful life and has a net book value of approximately $12 million at June 30, 2015. 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 The Company is involved in various 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 overall business, financial position, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved. During the six months ended June 30, 2015, and June 30, 2014, the Company made no significant payments to settle any legal, environmental or tax proceedings. The Company regularly analyzes current information and accrues for probable liabilities on the disposition of certain matters as necessary. Liabilities for loss contingencies arising from claims, assessments, litigation or other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated.

Income Taxes	6 Months Ended
Income Taxes	Jun. 30, 2015
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. Amounts recognized for income taxes are reported in “income tax benefit” on the condensed statements of operations.

Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows

6 Months Ended

Jun. 30, 2015

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

“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:



	June 30, 2015		December 31, 2014
	(in thousands)

Accrued interest	$	14,643	$	15,803
Asset retirement obligations	3,101		3,101
Other	54		183
	$	17,798	$	19,087

Supplemental disclosures to the condensed statements of cash flows are presented below:



	Six Months Ended June 30,
	2015		2014
	(in thousands)

Cash payments for interest, net of amounts capitalized	$	44,608	$	55,751
Cash payments for income taxes	$	—	$	—

Noncash investing activities:
Accrued capital expenditures	$	28,468	$	114,145

For the six months ended June 30, 2015, LINN Energy spent approximately $123 million of capital expenditures in respect of Berry’s operations. The Company recorded the $123 million to oil and natural gas properties with an offset to the advance due from LINN Energy. In addition, in May 2015, LINN Energy made a capital contribution of $250 million to Berry which was deposited on Berry’s behalf and posted as restricted cash with Berry’s lenders in connection with the reduction in its borrowing base (see Note 3).

Related Party Transactions	6 Months Ended
Related Party Transactions	Jun. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions LINN Energy The Company has no employees. The employees of Linn Operating, Inc. (“LOI”), a subsidiary of LINN Energy, 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, 2015, the Company incurred management fee expenses of approximately $33 million and $53 million, respectively, for services provided by 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. The Company also had affiliated accounts payable due to LINN Energy of approximately $29 million and $13 million at June 30, 2015, and December 31, 2014, respectively, included in “accounts payable and accrued expenses” on the condensed balance sheets. During the three months and six months ended June 30, 2015, the Company made cash distributions of approximately $13 million and $57 million, respectively, to LINN Energy. In 2014, the Company advanced approximately $352 million, to a subsidiary of LINN Energy, of net cash proceeds from the sale of certain of the Company’s Wolfberry properties in Ector and Midland counties in the Permian Basin to Fleur de Lis Energy, LLC. These proceeds must be used by LINN Energy on capital expenditures in respect of Berry’s operations, to repay Berry’s indebtedness or as otherwise permitted under the terms of Berry’s indentures and Credit Facility. During the six months ended June 30, 2015, and three months ended December 31, 2014, LINN Energy spent approximately $123 million and $58 million, respectively, of capital expenditures in respect of Berry’s operations. At June 30, 2015, the remaining advance balance was approximately $171 million. In May 2015, Linn Energy made a capital contribution of $250 million to Berry which was deposited on Berry’s behalf and posted as restricted cash with Berry’s lenders in connection with the reduction in its borrowing base (see Note 3). The $250 million may be used to satisfy obligations under the Credit Facility or may be returned to LINN Energy in the future if commodity prices improve. 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, 2015, the Company incurred expenditures of approximately $218,000 and $318,000, respectively, and for the three months and six months ended June 30, 2014, the Company incurred expenditures of approximately $98,000 and $176,000, respectively, related to services rendered by Superior and its subsidiaries.

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References + Details

Basis of Presentation (Policies)	6 Months Ended
Basis of Presentation (Policies)	Jun. 30, 2015
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, 2014. 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 condensed 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	Recently Issued Accounting Standards In April 2015, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify the presentation of debt issuance costs by requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2015, and interim periods within those years (early adoption permitted). The Company does not expect the adoption of this ASU to have a material impact on its financial statements. In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 2017, and interim periods within those years (early adoption permitted for fiscal years beginning after December 15, 2016, including interim periods within that year). 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 Properties (Tables)

6 Months Ended

Jun. 30, 2015

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:



	June 30, 2015			December 31, 2014
	(in thousands)
Oil and natural gas:
Proved properties	$	4,128,644		$	4,025,595
Unproved properties	839,078			846,464
	4,967,722			4,872,059
Less accumulated depletion and amortization	(923,731		)	(525,007		)
	$	4,043,991		$	4,347,052

Debt (Tables)

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

The following summarizes the Company’s outstanding debt:



	June 30, 2015		December 31, 2014
	(in thousands, except percentages)

Credit facility ⁽¹⁾	$	1,173,175	$	1,173,175
6.75% senior notes due November 2020	275,177		299,970
6.375% senior notes due September 2022	572,700		599,163
Net unamortized premiums	12,803		14,644
Total debt, net	2,033,855		2,086,952
Less current maturities	—		—
Total long-term debt, net	$	2,033,855	$	2,086,952


⁽¹⁾	Variable interest rates of 2.69% and 2.67% at June 30, 2015, and December 31, 2014, respectively.

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments



	June 30, 2015				December 31, 2014
	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	860,680		664,672		913,777		699,462
Total debt, net	$	2,033,855	$	1,837,847	$	2,086,952	$	1,872,637

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
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Reference 2: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2015

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, 2015:



	July 1 - December 31, 2015			2016
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls)	1,963			—
Average price ($/Bbl)	$	59.97		$	—
Three-way collars (NYMEX WTI):
Hedged volume (MBbls)	552			—
Short put ($/Bbl)	$	70.00		$	—
Long put ($/Bbl)	$	90.00		$	—
Short call ($/Bbl)	$	101.62		$	—
Natural gas basis differential positions: ⁽¹⁾
NWPL Rockies basis swaps: ⁽²⁾
Hedged volume (MMMBtu)	5,152			11,712
Hedged differential ($/MMBtu)	$	(0.34	)	$	(0.34	)
SoCal basis swaps: ⁽³⁾
Hedged volume (MMMBtu)	16,560			32,940
Hedged differential ($/MMBtu)	$	(0.03	)	$	(0.03	)


⁽¹⁾	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.


⁽²⁾	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.


⁽³⁾	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.

Schedule of derivatives assets and liabilities



	June 30, 2015		December 31, 2014
	(in thousands)
Assets:
Commodity derivatives	$	23,636	$	60,843
Liabilities:
Commodity derivatives	$	11,047	$	17,149

Derivative Instruments, Gain (Loss)

A summary of gains and losses on derivatives included on the condensed statements of operations is presented below:



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(in thousands)

Losses on oil and natural gas derivatives	$	(4,474	)	$	(25,562	)	$	(1,207	)	$	(22,097	)
Lease operating expenses ⁽¹⁾	3,986			—			3,060			—
Total gains (losses) on oil and natural gas derivatives	$	(488	)	$	(25,562	)	$	1,853		$	(22,097	)


⁽¹⁾	Consists of gains and losses on derivatives used to hedge natural gas consumption which were entered into in March 2015.

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5624171-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5579240-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41620-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Fair Value Measurements on a Recurring Basis (Tables)

6 Months Ended

Jun. 30, 2015

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:



	June 30, 2015
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	23,636	$	(7,126	)	$	16,510
Liabilities:
Commodity derivatives	$	11,047	$	(7,126	)	$	3,921



	December 31, 2014
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	60,843	$	(17,149	)	$	43,694
Liabilities:
Commodity derivatives	$	17,149	$	(17,149	)	$	—


⁽¹⁾	Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2015

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, 2014	$	121,760
Liabilities added from drilling	1,030
Current year accretion expense	3,340
Settlements	(284		)
Asset retirement obligations at June 30, 2015	$	125,846

Supplemental Disclosures to the Condensed Balance Sheets and Condensed Statements of Cash Flows (Tables)

6 Months Ended

Jun. 30, 2015

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:



	June 30, 2015		December 31, 2014
	(in thousands)

Accrued interest	$	14,643	$	15,803
Asset retirement obligations	3,101		3,101
Other	54		183
	$	17,798	$	19,087

Supplemental Cash Flow Disclosures

Supplemental disclosures to the condensed statements of cash flows are presented below:



	Six Months Ended June 30,
	2015		2014
	(in thousands)

Cash payments for interest, net of amounts capitalized	$	44,608	$	55,751
Cash payments for income taxes	$	—	$	—

Noncash investing activities:
Accrued capital expenditures	$	28,468	$	114,145

Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2015	Mar. 31, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets	$ 0	$ 272,000	$ 0	$ 272,000	$ 0
Oil and natural gas:
Proved properties	4,128,644			4,128,644		$ 4,025,595
Unproved properties	839,078			839,078		846,464
Oil and natural gas properties (successful efforts method)	4,967,722			4,967,722		4,872,059
Less accumulated depletion and amortization	(923,731)			(923,731)		(525,007)
Oil and natural gas properties, successful efforts method, net	$ 4,043,991			$ 4,043,991		$ 4,347,052
California operating area [Member]
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets		207,000
East Texas operating area [Member]
Property, Plant and Equipment [Line Items]
Impairment of long-lived assets		$ 65,000

Debt Schedule of long term debt (Details) - USD ($)
$ in Thousands

Jun. 30, 2015

Dec. 31, 2014

Debt Instruments [Abstract]

Credit facility

$ 1,173,175

Senior notes, net

860,680

913,777

Net unamortized premiums

12,803

14,644

Total debt, net

2,033,855

2,086,952

Less current maturities

Total long-term debt, net

2,033,855

2,086,952

Credit Facility

Debt Instruments [Abstract]

Credit facility

^[1]

1,173,175

November 2020 Senior Notes

Debt Instruments [Abstract]

Senior notes, net

$ 275,177

299,970

Debt Instrument, Interest Rate, Stated Percentage

6.75%

September 2022 Senior Notes

Debt Instruments [Abstract]

Senior notes, net

$ 572,700

$ 599,163

Debt Instrument, Interest Rate, Stated Percentage

6.375%

Credit Facility

Debt Instruments [Abstract]

Debt Instrument, Interest Rate at Period End

2.69%

2.67%

[1]	Variable interest rates of 2.69% and 2.67% at June 30, 2015, and December 31, 2014, respectively.

Debt Debt fair value disclosure (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Carrying Value
Credit facility	$ 1,173,175	$ 1,173,175
Senior notes, net	860,680	913,777
Total debt, net	2,033,855	2,086,952
Fair Value
Credit facility	1,173,175	1,173,175
Senior notes, net	664,672	699,462
Total debt, net	$ 1,837,847	$ 1,872,637

- Definition

The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

+ References + Details

Debt (Details 2) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
Debt (Details 2) - USD ($) $ in Thousands	May 31, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Mar. 31, 2015
Debt instrument
Extinguishment of Debt, Amount				$ 51,000
Gain on extinguishment of debt		$ 6,831	$ 0	6,831	$ 0
Line of Credit Facility, Maximum Borrowing Capacity		1,200,000		1,200,000		$ 1,400,000
Capital contribution from affiliate				250,000
Line of Credit Facility, Current Borrowing Capacity		1,200,000		1,200,000
Line of Credit Facility, Remaining Borrowing Capacity		$ 1,000		$ 1,000
LineOfCreditFacilityPortionOfPropertiesRequiredToMaintainMortgages		80.00%		80.00%
Percent of future net income allowable to increase Berry restricted payments basket		50.00%		50.00%
November 2020 Senior Notes
Debt instrument
Debt Instrument, Interest Rate, Stated Percentage		6.75%		6.75%
Extinguishment of Debt, Amount				$ 25,000
September 2022 Senior Notes
Debt instrument
Debt Instrument, Interest Rate, Stated Percentage		6.375%		6.375%
Extinguishment of Debt, Amount				$ 26,000
Minimum [Member]
Debt instrument
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage				0.375%
Minimum [Member] \| Prime Rate [Member]
Debt instrument
Debt Instrument, Basis Spread on Variable Rate				0.50%
Minimum [Member] \| London Interbank Offered Rate (LIBOR) [Member]
Debt instrument
Debt Instrument, Basis Spread on Variable Rate				1.50%
Maximum [Member]
Debt instrument
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage				0.50%
Maximum [Member] \| Prime Rate [Member]
Debt instrument
Debt Instrument, Basis Spread on Variable Rate				1.50%
Maximum [Member] \| London Interbank Offered Rate (LIBOR) [Member]
Debt instrument
Debt Instrument, Basis Spread on Variable Rate				2.50%
Linn Energy, LLC [Member]
Debt instrument
Capital contribution from affiliate	$ 250,000			$ 250,000

Derivative Instruments (Details)

Jun. 30, 2015

mmbls

$ / mmbls

2015 | Oil derivative instruments | Swap

Derivative

Hedged volume (MBbls) | mmbls

1,963

Average price ($/Bbl)

59.97

2015 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Hedged volume (MBbls) | mmbls

552

2015 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Derivative, floor price ($/Bbl)

70.00

Derivative, cap price ($/Bbl)

101.62

2015 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Derivative, floor price ($/Bbl)

90.00

2015 | Natural gas basis differential commodity contract [Member] | NWPL Rockies basis swap [Member]

Derivative

Hedged volume (MBbls) | mmbls

5,152

^[1],[2]

Hedged differential ($/Bbl)

(0.34)

^[1],[2]

2015 | Natural gas basis differential commodity contract [Member] | SoCal basis swap [Member]

Derivative

Hedged volume (MBbls) | mmbls

16,560

^[2],[3]

Hedged differential ($/Bbl)

(0.03)

^[2],[3]

2016 | Oil derivative instruments | Swap

Derivative

Hedged volume (MBbls) | mmbls

Average price ($/Bbl)

2016 | Oil derivative instruments | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Hedged volume (MBbls) | mmbls

2016 | Oil derivative instruments | Short | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Derivative, floor price ($/Bbl)

0.00

Derivative, cap price ($/Bbl)

0.00

2016 | Oil derivative instruments | Long | Crude Oil Sales - Three-way collars - Derivative 1

Derivative

Derivative, floor price ($/Bbl)

0.00

2016 | Natural gas basis differential commodity contract [Member] | NWPL Rockies basis swap [Member]

Derivative

Hedged volume (MBbls) | mmbls

11,712

^[1],[2]

Hedged differential ($/Bbl)

(0.34)

^[1],[2]

2016 | Natural gas basis differential commodity contract [Member] | SoCal basis swap [Member]

Derivative

Hedged volume (MBbls) | mmbls

32,940

^[2],[3]

Hedged differential ($/Bbl)

(0.03)

^[2],[3]

[1]	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.
[2]	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
[3]	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.

Derivative Instruments Derivative Instruments Balance Sheet Presentation (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Assets:
Commodity derivatives	$ 23,636	$ 60,843
Liabilities:
Commodity derivatives	11,047	$ 17,149
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 24,000

Derivative Instruments (Details 2) $ in Thousands	3 Months Ended		6 Months Ended
Derivative Instruments (Details 2) $ in Thousands	Jun. 30, 2015 USD ($) MBbl $ / bbl	Jun. 30, 2014 USD ($) MBbl $ / bbl	Jun. 30, 2015 USD ($) MBbl $ / bbl	Jun. 30, 2014 USD ($) MBbl $ / bbl
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Volume Of Oil On Settled Derivatives \| MBbl	1,074	2,275	1,344	4,525
Average contract price on oil settled derivatives per unit \| $ / bbl	66.75	92.16	70.86	92.16
Cash settlements \| $	$ 5,000	$ (8,000)	$ 32,943	$ (10,472)

Derivative Instruments Derivative Instruments Income Statement Presentation (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Losses on oil and natural gas derivatives	$ (488)	$ (25,562)	$ 1,853	$ (22,097)
Losses on oil and natural gas derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Losses on oil and natural gas derivatives	(4,474)	(25,562)	(1,207)	(22,097)
Lease operating expenses
Derivative Instruments, Gain (Loss) [Line Items]
Losses on oil and natural gas derivatives	$ 3,986	$ 0	$ 3,060	$ 0

Fair Value Measurements on a Recurring Basis Fair Value Measurements on a Recurring Basis (Details) - USD ($)
$ in Thousands

Jun. 30, 2015

Dec. 31, 2014

Assets:

Commodity derivatives

$ 23,636

$ 60,843

Commodity derivatives

^[1]

(7,126)

(17,149)

Commodity derivatives

16,510

43,694

Liabilities:

Commodity derivatives

11,047

17,149

Commodity derivatives

^[1]

(7,126)

(17,149)

Commodity derivatives

$ 3,921

$ 0

[1]	Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (Details) $ in Thousands	6 Months Ended
Asset Retirement Obligations (Details) $ in Thousands	Jun. 30, 2015 USD ($)
Asset Retirement Obligation Disclosure [Abstract]
Fair Value Inputs, Discount Rate	5.50%
Asset Retirement Obligation Future Inflation Factor	2.00%
Change in the asset retirement obligations
Asset retirement obligations at December 31, 2014	$ 121,760
Liabilities added from drilling	1,030
Current year accretion expense	3,340
Settlements	(284)
Asset retirement obligations at June 30, 2015	$ 125,846

Commitments and Contingencies (Details) $ in Thousands	6 Months Ended
Commitments and Contingencies (Details) $ in Thousands	Jun. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Jan. 14, 2011 USD ($) a
Loss Contingencies [Line Items]
Gathering System, Book Value	$ 12,000
Payments for Legal Settlements	$ 0	$ 0
Performance Guarantee [Member]
Loss Contingencies [Line Items]
Contractual Obligation Amount, Penalty Waived Per Well			$ 200
Contractual Obligation, Acre Of Tracts \| a			160
Contractual Obligation, Contingent Construction Expense			$ 9,000
Third Party Share of Construction Costs, Percentage			50.00%
Contractual Obligation, Penalty as Percentage of Difference Between Specified Amount and Actual Expended			50.00%
Contractual Obligation, Specified Amount for Penalty Calculation			$ 12,000

Supplemental Disclosures to the Condensed Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Supplemental disclosures to the condensed balance sheets and condensed statements of cash flows [Abstract]
Accrued interest	$ 14,643	$ 15,803
Asset retirement obligations	3,101	3,101
Other	54	183
Other accrued liabilities	$ 17,798	$ 19,087

Supplemental Disclosures to the Condensed Statements of Cash Flows (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	6 Months Ended
	May 31, 2015	Dec. 31, 2014	Jun. 30, 2015	Jun. 30, 2014
Supplemental disclosures to the statements of cash flows [Line Items]
Cash payments for interest, net of amounts capitalized			$ 44,608	$ 55,751
Cash payments for income taxes			0	0
Noncash investing activities:
Accrued capital expenditures			28,468	$ 114,145
Capital contribution from affiliate			250,000
Linn Energy, LLC [Member]
Noncash investing activities:
Capital expenditures paid by affiliate		$ 58,000	123,000
Decrease in advance due from LINN Energy			123,000
Capital contribution from affiliate	$ 250,000		$ 250,000

Related Party Transactions (Details) $ in Thousands	1 Months Ended	3 Months Ended			6 Months Ended		12 Months Ended
Related Party Transactions (Details) $ in Thousands	May 31, 2015 USD ($)	Jun. 30, 2015 USD ($)	Dec. 31, 2014 USD ($)	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Dec. 31, 2014 USD ($)
Related Party Transactions
Entity Number of Employees		0			0
Distributions to affiliate					$ 57,223	$ 41,537
Proceeds from sale of properties and equipment and other							$ 352,000
Advance to affiliate		$ 171,044	$ 293,627		171,044		293,627
Capital contribution from affiliate					250,000
Linn Operating, Inc.
Related Party Transactions
Due to Affiliate, Current		29,000	13,000		29,000		$ 13,000
Management fee expense		33,000		$ 24,000	53,000	60,000
Linn Energy, LLC [Member]
Related Party Transactions
Distributions to affiliate		13,000			57,000
Capital expenditures paid by affiliate			$ 58,000		123,000
Advance to affiliate		171,000			171,000
Capital contribution from affiliate	$ 250,000				250,000
Superior Energy Services, Inc.
Related Party Transactions
Amount of related party transaction		$ 218		$ 98	$ 318	$ 176