Pressburg (ROAN) 10-Q 12 May 16 2016 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2016	Apr. 30, 2016
Document and Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Entity Registrant Name	Linn Energy, LLC
Entity Central Index Key	1,326,428
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		355,199,905
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents		$ 1,059,556	$ 2,168
Accounts receivable – trade, net		186,052	216,556
Derivative instruments		1,096,224	1,220,230
Other current assets		101,911	95,593
Total current assets		2,443,743	1,534,547
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		18,149,355	18,121,155
Less accumulated depletion and amortization		(12,393,562)	(11,097,492)
Oil and natural gas properties, successful efforts method, net		5,755,793	7,023,663
Other property and equipment		714,730	708,711
Less accumulated depreciation		(209,491)	(195,661)
Other property and equipment, net		505,239	513,050
Derivative instruments		451,843	566,401
Restricted cash		257,820	257,363
Other noncurrent assets		25,059	33,234
Noncurrent assets, excluding property, total		734,722	856,998
Total noncurrent assets		6,995,754	8,393,711
Total assets		9,439,497	9,928,258
Current liabilities:
Accounts payable and accrued expenses		368,074	455,374
Derivative instruments		1,190	2,241
Current portion of long-term debt, net	[1]	4,593,332	3,714,693
Other accrued liabilities		170,517	119,593
Total current liabilities		5,133,113	4,291,901
Noncurrent liabilities:
Derivative instruments		474	857
Long-term debt, net		5,294,810	5,292,676
Other noncurrent liabilities		615,518	611,725
Total noncurrent liabilities		$ 5,910,802	$ 5,905,258
Commitments and contingencies (Note 10)
Unitholders’ deficit:
355,184,234 units and 355,017,428 units issued and outstanding at March 31, 2016, and December 31, 2015, respectively		$ 5,355,345	$ 5,343,116
Accumulated deficit		(6,959,763)	(5,612,017)
Total unitholders' deficit		(1,604,418)	(268,901)
Total liabilities and unitholders’ deficit		$ 9,439,497	$ 9,928,258
[1]	Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at March 31, 2016, and December 31, 2015. The current portion as of both March 31, 2016, and December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - shares	Mar. 31, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Unitholders’ capital: Units issued	355,184,234	355,017,428
Unitholders’ capital: Units outstanding	355,184,234	355,017,428

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenues and other:
Oil, natural gas and natural gas liquids sales	$ 283,315	$ 450,569
Gains on oil and natural gas derivatives	109,961	424,781
Marketing revenues	14,305	33,744
Other revenues	7,186	7,453
Total revenues	414,767	916,547
Expenses:
Lease operating expenses	137,645	173,021
Transportation expenses	54,923	53,540
Marketing expenses	12,288	28,841
General and administrative expenses	86,529	78,968
Exploration costs	2,693	396
Depreciation, depletion and amortization	164,058	215,014
Impairment of long-lived assets	1,153,904	532,617
Taxes, other than income taxes	34,067	54,045
(Gains) losses on sale of assets and other, net	1,077	(12,287)
Total expenses	1,647,184	1,124,155
Other income and (expenses):
Interest expense, net of amounts capitalized	(105,219)	(143,101)
Gain on extinguishment of debt	0	6,635
Other, net	134	(2,213)
Total other income and (expenses)	(105,085)	(138,679)
Loss before income taxes	(1,337,502)	(346,287)
Income tax expense (benefit)	10,244	(7,127)
Net loss	$ (1,347,746)	$ (339,160)
Net loss per unit:
Basic (in usd per unit)	$ (3.83)	$ (1.03)
Diluted (in usd per unit)	$ (3.83)	$ (1.03)
Weighted average units outstanding:
Basic (in units)	352,234	330,642
Diluted (in units)	352,234	330,642
Distributions declared per unit	$ 0	$ 0.313

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS' DEFICIT (Unaudited) Statement $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)shares
December 31, 2015 | shares	355,017,428
December 31, 2015	$ (268,901)
Issuance of units	0
Unit-based compensation expenses	12,425
Excess tax benefit from unit-based compensation and other	(196)
Net loss	$ (1,347,746)
March 31, 2016 | shares	355,184,234
March 31, 2016	$ (1,604,418)
Units
December 31, 2015 | shares	355,017,000
Issuance of units | shares	167,000
March 31, 2016 | shares	355,184,000
Unitholders’ Capital
December 31, 2015	$ 5,343,116
Issuance of units	0
Unit-based compensation expenses	12,425
Excess tax benefit from unit-based compensation and other	(196)
Net loss	0
March 31, 2016	5,355,345
Accumulated Deficit
December 31, 2015	(5,612,017)
Issuance of units	0
Unit-based compensation expenses	0
Excess tax benefit from unit-based compensation and other	0
Net loss	(1,347,746)
March 31, 2016	$ (6,959,763)

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flow from operating activities:
Net loss	$ (1,347,746)	$ (339,160)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	164,058	215,014
Impairment of long-lived assets	1,153,904	532,617
Unit-based compensation expenses	12,425	20,510
Gain on extinguishment of debt	0	(6,635)
Amortization and write-off of deferred financing fees	4,858	6,712
(Gains) losses on sale of assets and other, net	1,916	(7,100)
Deferred income taxes	9,420	(7,158)
Derivatives activities:
Total gains	(106,593)	(423,855)
Cash settlements	343,723	282,082
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	31,113	135,230
Increase in other assets	(8,289)	(12,399)
Decrease in accounts payable and accrued expenses	(14,527)	(29,868)
Increase in other liabilities	46,766	8,713
Net cash provided by operating activities	291,028	374,703
Cash flow from investing activities:
Development of oil and natural gas properties	(81,426)	(264,818)
Purchases of other property and equipment	(9,731)	(12,401)
Proceeds from sale of properties and equipment and other	(264)	27,500
Net cash used in investing activities	(91,421)	(249,719)
Cash flow from financing activities:
Proceeds from sale of units	0	15,900
Proceeds from borrowings	978,500	395,000
Repayments of debt	(100,000)	(280,287)
Distributions to unitholders	0	(104,815)
Financing fees and offering costs	(32)	(453)
Excess tax benefit from unit-based compensation	0	(8,867)
Other	(20,687)	(94,959)
Net cash provided by (used in) financing activities	857,781	(78,481)
Net increase in cash and cash equivalents	1,057,388	46,503
Cash and cash equivalents:
Beginning	2,168	1,809
Ending	$ 1,059,556	$ 48,312

Basis of Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation Nature of Business Linn Energy, LLC (“LINN Energy” or the “Company”) is an independent oil and natural gas company. LINN Energy’s mission is to acquire, develop and maximize cash flow from a growing portfolio of long-life oil and natural gas assets. The Company’s properties are located in eight operating regions in the United States (“U.S.”), in the Rockies, the Hugoton Basin, California, the Mid-Continent, east Texas and north Louisiana (“TexLa”), the Permian Basin, Michigan/Illinois and south Texas. Principles of Consolidation and Reporting The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year. The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The reference to “Berry” herein refers to Berry Petroleum Company, LLC, which is an indirect 100% wholly owned subsidiary of LINN Energy. The reference to “LinnCo” herein refers to LinnCo, LLC, which is an affiliate of LINN Energy. The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ deficit or cash flows. Use of Estimates The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods. Recently Issued Accounting Standards In March 2016, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Components of this ASU will be applied either prospectively, retrospectively or under a modified retrospective basis (as applicable for the respective provision) as of the date of adoption and is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. The Company is currently evaluating the impact of the adoption of this ASU on its consolidated financial statements and related disclosures. In February 2016, the FASB issued an ASU that is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2018, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its consolidated financial statements and related disclosures. In November 2015, the FASB issued an ASU that is intended to simplify the presentation of deferred taxes by requiring that all deferred taxes be classified as noncurrent, presented as a single noncurrent amount for each tax-paying component of an entity. The ASU is effective for fiscal years beginning after December 15, 2016; however, the Company early adopted it on January 1, 2016, on a retrospective basis. The adoption of this ASU resulted in the reclassification of previously-classified net current deferred taxes of approximately $22 million from “other current assets,” as well as previously-classified net noncurrent deferred tax liabilities of approximately $11 million from “other noncurrent liabilities,” to “other noncurrent assets” resulting in net noncurrent deferred taxes of approximately $11 million on the Company’s consolidated balance sheet at December 31, 2015. There was no impact to the consolidated statements of operations. In April 2015, the FASB issued an 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 on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The Company adopted this ASU on January 1, 2016, on a retrospective basis. The adoption of this ASU resulted in the reclassification of approximately $37 million of unamortized deferred financing fees (which excludes deferred financing fees associated with the Company’s Credit Facilities, as defined in Note 6, which were not reclassified) from an asset to a direct deduction from the carrying amount of the associated debt liability on the consolidated balance sheet at December 31, 2015. There was no impact to the consolidated statements of operations. In August 2014, the FASB issued an ASU that provides guidance about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. This ASU is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter (early adoption permitted). The Company does not expect the adoption of this ASU to have a material impact on its financial statements or related disclosures. In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 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 consolidated financial statements and related disclosures.

Chapter 11 Proceedings, Liquidi

Chapter 11 Proceedings, Liquidity and Ability to Continue as a Going Concern	3 Months Ended
	Mar. 31, 2016
Going Concern Uncertainty [Abstract]
Substantial Doubt about Going Concern [Text Block]	y Reorganization Under Chapter 11 On May 11, 2016, the Company and certain of the Company’s direct and indirect subsidiaries (collectively with the Company, the “LINN Debtors”), LinnCo and Berry (collectively with the LINN Debtors and LinnCo, the “Debtors”), filed voluntary petitions (“Bankruptcy Petitions”) for reorganization under Chapter 11 of the U.S. Bankruptcy Code (“Bankruptcy Code”) in the U.S. Bankruptcy Court for the Southern District of Texas (“Bankruptcy Court”). The Debtors have filed a motion with the Bankruptcy Court seeking joint administration of their Chapter 11 cases. Prior to the filing of the Bankruptcy Petitions, on May 10, 2016, the Debtors entered into a restructuring support agreement (“Restructuring Support Agreement”) with certain holders (“Consenting Creditors”) collectively holding or controlling at least 66.67% by aggregate outstanding principal amounts under (i) the Company’s Sixth Amended and Restated Credit Agreement (“LINN Credit Facility”) and (ii) Berry’s Second Amended and Restated Credit Agreement (“Berry Credit Facility”). The Restructuring Support Agreement sets forth, subject to certain conditions, the commitment of the Debtors and the Consenting Creditors to support a comprehensive restructuring of the Debtors’ long-term debt (“Restructuring Transactions”). The Restructuring Transactions will be effectuated through one or more plans of reorganization (“Plan”) to be filed in cases commenced under Chapter 11 of the Bankruptcy Code. The Restructuring Support Agreement provides that the Consenting Creditors will support the use of the LINN Debtors’ and Berry’s cash collateral under specified terms and conditions, including adequate protection terms. The Restructuring Support Agreement obligates the Debtors and the Consenting Creditors to, among other things, support and not interfere with consummation of the Restructuring Transactions and, as to the Consenting Creditors, vote their claims in favor of the Plan. The Restructuring Support Agreement may be terminated upon the occurrence of certain events, including the failure to meet specified milestones relating to the filing, confirmation and consummation of the Plan, among other requirements, and in the event of certain breaches by the parties under the Restructuring Support Agreement. The Restructuring Support Agreement is subject to termination if the effective date of the Plan has not occurred within 250 days of the bankruptcy filing. There can be no assurances that the Restructuring Transactions will be consummated. Subject to certain exceptions, under the Bankruptcy Code, the filing of the Bankruptcy Petitions automatically enjoined, or stayed, the continuation of most judicial or administrative proceedings or filing of other actions against the Debtors or their property to recover, collect or secure a claim arising prior to the date of the Bankruptcy Petitions. Accordingly, although the filing of the Bankruptcy Petitions triggered defaults on the Debtors’ debt obligations, creditors are stayed from taking any actions against the Debtors as a result of such defaults, subject to certain limited exceptions permitted by the Bankruptcy Code. Absent an order of the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities are subject to settlement under the Bankruptcy Code. Subject to certain exceptions, under the Bankruptcy Code, the Debtors may assume, assign or reject certain executory contracts and unexpired leases subject to the approval of the Court and certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a pre-petition breach of such executory contract or unexpired lease and, subject to certain exceptions, relieves the Debtors of performing their future obligations under such executory contract or unexpired lease but entitles the contract counterparty or lessor to a pre-petition general unsecured claim for damages caused by such deemed breach. Counterparties to such rejected contracts or leases may assert unsecured claims in the Bankruptcy Court against the applicable Debtors’ estate for such damages. Generally, the assumption of an executory contract or unexpired lease requires the Debtors to cure existing monetary defaults under such executory contract or unexpired lease and provide adequate assurance of future performance. Accordingly, any description of an executory contract or unexpired lease with the Debtor in this quarterly report, including where applicable a quantification of the Company’s obligations under any such executory contract or unexpired lease with the Debtor is qualified by any overriding rejection rights the Company has under the Bankruptcy Code. Further, nothing herein is or shall be deemed an admission with respect to any claim amounts or calculations arising from the rejection of any executory contract or unexpired lease and the Debtors expressly preserve all of their rights with respect thereto. Ability to Continue as a Going Concern Continued low commodity prices are expected to result in significantly lower levels of cash flow from operating activities in the future and have limited the Company’s ability to access the capital markets. In addition, each of the Company’s Credit Facilities is subject to scheduled redeterminations of its borrowing base, semi-annually in April and October, based primarily on reserve reports using lender commodity price expectations at such time. The lenders under the Credit Facilities agreed to defer the April 2016 borrowing base redeterminations to May 11, 2016. Continued low commodity prices, reductions in the Company’s capital budget and the resulting reserve write-downs, along with the termination of the Company’s hedges, are expected to adversely impact upcoming redeterminations and will likely have a significant negative impact on the Company’s liquidity. The Company’s filing of the Bankruptcy Petitions described above accelerated the Company’s obligations under its Credit Facilities, its 12.00% senior secured second lien notes due December 2020 (“Second Lien Notes”) and its senior notes. The significant risks and uncertainties related to the Company’s liquidity and Chapter 11 proceedings described above raise substantial doubt about the Company’s ability to continue as a going concern. The condensed consolidated financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The condensed consolidated financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Company cannot continue as a going concern, adjustments to the carrying values and classification of its assets and liabilities and the reported amounts of income and expenses could be required and could be material. In order to decrease the Company’s level of indebtedness and maintain the Company’s liquidity at levels sufficient to meet its commitments, the Company has undertaken a number of actions, including minimizing capital expenditures and further reducing its recurring operating expenses. The Company believes that even after taking these actions, it will not have sufficient liquidity to satisfy its debt service obligations, meet other financial obligations and comply with its debt covenants. As a result, the Debtors filed Bankruptcy Petitions for reorganization under Chapter 11 of the Bankruptcy Code. Covenant Violations As of March 31, 2016 , the Company was in default under certain of its debt instruments, which have subsequently been cured or a forbearance has been received. The Company’s filing of the Bankruptcy Petitions described above constitutes an event of default that accelerated the Company’s obligations under its Credit Facilities, its Second Lien Notes and its senior notes. Additionally, other events of default, including cross-defaults, are present, including the failure to make interest payments on certain of its senior notes and the receipt of a going concern explanatory paragraph from the Company’s independent registered public accounting firm on the Company’s consolidated financial statements for the year ended December 31, 2015. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Company as a result of an event of default. See Note 6 for additional details about the Company’s debt. Credit Facilities The Company’s Credit Facilities contain the requirement to deliver audited consolidated financial statements without a going concern or like qualification or exception. Consequently, the filing of the Company’s 2015 Annual Report on Form 10-K which included such explanatory paragraph resulted in a default under the LINN Credit Facility as of the filing date, March 15, 2016, subject to a 30 day grace period. On April 12, 2016, the Company entered into amendments to both the LINN Credit Facility and Berry Credit Facility. The amendments provided for, among other things, an agreement that (i) certain events (the “Specified Events”) would not become defaults or events of default until May 11, 2016, (ii) the borrowing bases would remain constant until May 11, 2016, unless reduced as a result of swap agreement terminations or collateral sales and (iii) the Company, the administrative agent and the lenders would negotiate in good faith the terms of a restructuring support agreement in furtherance of a restructuring of the capital structure of the Company and its subsidiaries. In addition, the amendment to the Berry Credit Facility provided Berry with access to $45 million in cash that was previously restricted in order to fund ordinary course operations. Pursuant to the terms of the foregoing amendments and as a result of the execution of the Restructuring Support Agreement, in May 2016, the Company made a $350 million permanent repayment of a portion of the borrowings outstanding under the LINN Credit Facility. Pursuant to the amendments, the Specified Events are: • The receipt of a going concern qualification or explanatory statement in the auditors’ report on the Company’s consolidated financial statements for the year ended December 31, 2015; • The receipt of a going concern qualification or explanatory statement in the auditors’ report on Berry’s financial statements for the year ended December 31, 2015; • The failure of the Company or Berry to make certain interest payments on their unsecured notes; • Any cross-defaults that may arise on account of any of the foregoing, provided that no event of default is continuing under any document giving rise to such cross default; and • Any failure to provide notice of any of the events described above. The amendment to the Berry Credit Facility also includes the Specified Event of the failure to maintain the ratio of Adjusted EBITDAX to Interest Expense (as each term is defined in the Berry Credit Facility) (“Interest Coverage Ratio”). As a condition to closing the amendments, in April 2016, (a) the Company made a $100 million permanent repayment of a portion of the borrowings outstanding under the LINN Credit Facility and (b) the Company and certain of its subsidiaries provided control agreements over certain deposit accounts. The filing of the Bankruptcy Petitions constitutes an event of default that accelerated the Company’s obligations under the Credit Facilities. However, under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Company as a result of the default. Second Lien Notes The indenture governing the Second Lien Notes (“Second Lien Indenture”) required the Company to deliver mortgages by February 18, 2016, subject to a 45 day grace period. The Company elected to exercise its right to the grace period, which resulted in the Company being in default under the Second Lien Indenture. On April 4, 2016, the Company entered into a settlement agreement with certain holders of the Second Lien Notes and agreed to deliver, and make arrangements for recordation of, the mortgages. The Company has since delivered and made arrangements for recordation of the mortgages and is no longer in default under the Second Lien Indenture. The settlement agreement provides that the parties will commence good faith negotiations with each other regarding the terms of a potential comprehensive and consensual restructuring, including a potential restructuring under a Chapter 11 plan of reorganization. If the parties are unable to reach agreement on the terms of a consensual restructuring on or before the date on which such Chapter 11 proceedings are commenced (or such later date as mutually agreed to by the parties), the parties will support entry by the bankruptcy court of a settlement order that, among other things, (i) approves the issuance of additional notes, in the principal amount of $1.0 billion plus certain accrued interest, on a proportionate basis to existing holders of the Second Lien Notes and (ii) releases the mortgages and other collateral upon the issuance of the additional notes (the “Settlement Order”). The settlement agreement terminates upon, among other events, (i) the expiration of 91 days after effectiveness of the settlement agreement, unless the Company has commenced Chapter 11 proceedings, or (ii) entry by the bankruptcy court of a final, non-appealable order denying the Company’s motion seeking entry of the Settlement Order. The filing of the Bankruptcy Petitions constitutes an event of default that accelerated the Company’s obligations under the Second Lien Indenture. However, under the Bankruptcy Code, holders of the Second Lien Notes are stayed from taking any action against the Company as a result of the default. Senior Notes The Company deferred making interest payments totaling approximately $60 million due March 15, 2016, including approximately $30 million on LINN Energy’s 7.75% senior notes due February 2021, approximately $12 million on LINN Energy’s 6.50% senior notes due September 2021 and approximately $18 million on Berry’s 6.375% senior notes due September 2022, which resulted in the Company being in default under these senior notes. The indentures governing each of the applicable series of notes permit the Company a 30 day grace period to make the interest payments. On April 14, 2016, within the 30 day interest payment grace period provided for in the indentures governing the notes, the Company and Berry made interest payments of approximately $60 million in satisfaction of their respective obligations. Furthermore, the Company decided to defer making interest payments of approximately $31 million due April 15, 2016, on LINN Energy’s 8.625% senior notes due April 2020, and interest payments due May 1, 2016, of approximately $18 million on LINN Energy’s 6.25% senior notes due November 2019 and approximately $9 million on Berry’s 6.75% senior notes due November 2020, which, as of the payment due dates, resulted in the Company being in default under these senior notes. The indentures governing each of the applicable series of notes permit the Company a 30 day grace period to make the interest payments. The filing of the Bankruptcy Petitions constitutes an event of default that accelerated the Company’s obligations under the indentures governing the senior notes. However, under the Bankruptcy Code, holders of the senior notes are stayed from taking any action against the Company as a result of the default.

Unitholders' Deficit

Unitholders' Deficit	3 Months Ended
	Mar. 31, 2016
Equity [Abstract]
Unitholders' Deficit	Unitholders’ Deficit At-the-Market Offering Program The Company’s Board of Directors has authorized the sale of up to $500 million of units under an at-the-market offering program. Sales of units, if any, will be made under an equity distribution agreement by means of ordinary brokers’ transactions, through the facilities of the NASDAQ Global Select Market, any other national securities exchange or facility thereof, a trading facility of a national securities association or an alternate trading system, to or through a market maker or directly on or through an electronic communication network, a “dark pool” or any similar market venue, at market prices, in block transactions, or as otherwise agreed with a sales agent. The Company expects to use the net proceeds from any sale of units for general corporate purposes, which may include, among other things, capital expenditures, acquisitions and the repayment of debt. No sales were made under the equity distribution agreement during the three months ended March 31, 2016 . During the three months ended March 31, 2015 , the Company, under its equity distribution agreement, sold 1,328,192 units representing limited liability company interests at an average price of $11.97 per unit for net proceeds of approximately $16 million (net of approximately $159,000 in commissions). In connection with the issuance and sale of these units, the Company also incurred professional services expenses of approximately $435,000 . The Company used the net proceeds for general corporate purposes, including the open market repurchases of a portion of its senior notes (see Note 6). At March 31, 2016 , units totaling approximately $455 million in aggregate offering price remained available to be sold under the agreement. Distributions Under the Company’s limited liability company agreement, unitholders are entitled to receive a distribution of available cash, which includes cash on hand plus borrowings less any reserves established by the Company’s Board of Directors to provide for the proper conduct of the Company’s business (including reserves for future capital expenditures, including drilling, acquisitions and anticipated future credit needs) or to fund distributions, if any, over the next four quarters. Monthly distributions were paid by the Company through September 2015. In October 2015, the Company’s Board of Directors determined to suspend payment of the Company’s distribution. The Company’s Board of Directors will continue to evaluate the Company’s ability to reinstate the distribution. Distributions paid by the Company during 2015 are presented on the condensed consolidated statement of cash flows.

Oil and Natural Gas Properties

Oil and Natural Gas Properties	3 Months Ended
	Mar. 31, 2016
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Oil and Natural Gas Properties	Oil and Natural Gas Properties Oil and Natural Gas Capitalized Costs Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below: March 31, December 31, (in thousands) Proved properties: Leasehold acquisition $ 13,372,330 $ 13,361,171 Development 3,003,402 2,976,643 Unproved properties 1,773,623 1,783,341 18,149,355 18,121,155 Less accumulated depletion and amortization (12,393,562 ) (11,097,492 ) $ 5,755,793 $ 7,023,663 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 the following noncash impairment charges (before and after tax) associated with proved oil and natural gas properties: Three Months Ended 2016 2015 (in thousands) California region $ 984,288 $ 207,200 Mid-Continent region 129,703 5,703 Rockies region 26,677 — Hugoton Basin region — 277,914 TexLa region — 33,100 South Texas region — 8,700 $ 1,140,668 $ 532,617 The impairment charges in 2016 were due to a decline in commodity prices, changes in expected capital development and a decline in the Company’s estimates of proved reserves. The impairment charges in 2015 were due to a decline in commodity prices. The carrying values of the impaired proved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair value measurement. The impairment charges are included in “impairment of long-lived assets” on the condensed consolidated statements of operations. Impairment of Unproved Properties The Company evaluates the impairment of its unproved oil and natural gas properties whenever events or changes in circumstances indicate that the carrying value may not be recoverable. The carrying values of unproved properties are reduced to fair value based on management’s experience in similar situations and other factors such as the lease terms of the properties and the relative proportion of such properties on which proved reserves have been found in the past. For the three months ended March 31, 2016 , the Company recorded noncash impairment charges (before and after tax) of approximately $13 million associated with unproved oil and natural gas properties in California. The Company recorded no impairment charges for unproved properties for the three months ended March 31, 2015 . The impairment charges in 2016 were due to a decline in commodity prices and changes in expected capital development. The carrying values of the impaired unproved properties were reduced to fair value, estimated using inputs characteristic of a Level 3 fair value measurement. The impairment charges are included in “impairment of long-lived assets” on the condensed consolidated statement of operations.

Unit-Based Compensation

Unit-Based Compensation	3 Months Ended
	Mar. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Unit-Based Compensation	Unit-Based Compensation The Company granted no unit-based awards during the three months ended March 31, 2016 . A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below: Three Months Ended 2016 2015 (in thousands) General and administrative expenses $ 9,460 $ 16,633 Lease operating expenses 2,965 3,877 Total unit-based compensation expenses $ 12,425 $ 20,510 Income tax benefit $ 4,591 $ 7,579 Cash-Based Performance Unit Awards In January 2015, the Company granted 567,320 performance units (the maximum number of units available to be earned) to certain executive officers. The 2015 performance unit awards vest three years from the award date. The vesting of these units is determined based on the Company’s performance compared to the performance of a predetermined group of peer companies over a specified performance period, and the value of vested units is to be paid in cash. To date, no performance units have vested and no amounts have been paid to settle any such awards. Performance unit awards that are settled in cash are recorded as a liability with the changes in fair value recognized over the vesting period. Based on the performance criteria, there was no liability recorded for these performance unit awards at March 31, 2016 .

Debt

Debt	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Debt	Debt The following summarizes the Company’s outstanding debt: March 31, 2016 December 31, 2015 (in thousands, except percentages) LINN credit facility (1) $ 3,093,500 $ 2,215,000 Berry credit facility (2) 873,175 873,175 Term loan (3) 500,000 500,000 6.50% senior notes due May 2019 562,234 562,234 6.25% senior notes due November 2019 581,402 581,402 8.625% senior notes due April 2020 718,596 718,596 6.75% Berry senior notes due November 2020 261,100 261,100 12.00% senior secured second lien notes due December 2020 (4) 1,000,000 1,000,000 Interest payable on senior secured second lien notes due December 2020 (4) 608,333 608,333 7.75% senior notes due February 2021 779,474 779,474 6.50% senior notes due September 2021 381,423 381,423 6.375% Berry senior notes due September 2022 572,700 572,700 Net unamortized discounts and premiums (8,318 ) (8,694 ) Net unamortized deferred financing fees (35,477 ) (37,374 ) Total debt, net 9,888,142 9,007,369 Less current portion, net (5) (4,593,332 ) (3,714,693 ) Long-term debt, net $ 5,294,810 $ 5,292,676 (1) Variable interest rates of 3.18% and 2.66% at March 31, 2016 , and December 31, 2015, respectively. (2) Variable interest rates of 5.25% and 3.17% at March 31, 2016 , and December 31, 2015, respectively. (3) Variable interest rates of 3.18% and 3.17% at March 31, 2016 , and December 31, 2015, respectively. (4) The issuance of the Second Lien Notes was accounted for as a troubled debt restructuring, which requires that interest payments on the Second Lien Notes reduce the carrying value of the debt with no interest expense recognized. (5) Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at March 31, 2016 , and December 31, 2015. The current portion as of both March 31, 2016 , and December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year. Fair Value The Company’s debt is recorded at the carrying amount on the condensed consolidated balance sheets. The carrying amounts of the Company’s credit facilities and term loan approximate fair value because the interest rates are variable and reflective of market rates. The Company uses a market approach to determine the fair value of its senior secured second lien notes and senior notes using estimates based on prices quoted from third-party financial institutions, which is a Level 2 fair value measurement. March 31, 2016 December 31, 2015 Carrying Value Fair Value Carrying Value Fair Value (in thousands) Senior secured second lien notes $ 1,000,000 $ 140,000 $ 1,000,000 $ 501,250 Senior notes, net 3,814,810 501,073 3,812,676 662,179 Credit Facilities LINN Credit Facility The Company’s Sixth Amended and Restated Credit Agreement (“LINN Credit Facility”) provides for (1) a senior secured revolving credit facility and (2) a $500 million senior secured term loan, in aggregate subject to the then-effective borrowing base. Borrowing capacity under the revolving credit facility is limited to the lesser of: (i) the then-effective borrowing base reduced by the $500 million term loan and (ii) the maximum commitment amount of $4.0 billion , and was $3.1 billion as of March 31, 2016 . The maturity date is April 2019, subject to a “springing maturity” based on the maturity of any outstanding LINN Energy junior lien debt. At March 31, 2016 , the borrowing base under the LINN Credit Facility was $3.6 billion and there was no remaining availability. In April 2016, the Company entered into an amendment to the LINN Credit Facility to provide for, among other things, an agreement that (i) certain Specified Events would not become defaults or events of default until May 11, 2016, (ii) the borrowing base would remain constant until May 11, 2016, unless reduced as a result of swap agreement terminations or collateral sales and (iii) the Company, the administrative agent and the lenders would negotiate in good faith the terms of a restructuring support agreement in furtherance of a restructuring of the capital structure of the Company and its subsidiaries. Pursuant to the terms of the foregoing amendments and as a result of the execution of the Restructuring Support Agreement, in May 2016, the Company made a $350 million permanent repayment of a portion of the borrowings outstanding under the LINN Credit Facility. Pursuant to the amendment, the Specified Events are: • The receipt of a going concern qualification or explanatory statement in the auditors’ report on the Company’s consolidated financial statements for the year ended December 31, 2015; • The receipt of a going concern qualification or explanatory statement in the auditors’ report on Berry’s financial statements for the year ended December 31, 2015; • The failure of the Company or Berry to make certain interest payments on their unsecured notes; • Any cross-defaults that may arise on account of any of the foregoing, provided that no event of default is continuing under any document giving rise to such cross default; and • Any failure to provide notice of any of the events described above. As a condition to closing the amendment, in April 2016, (a) the Company made a $100 million permanent repayment of a portion of the borrowings outstanding under the LINN Credit Facility and (b) the Company and certain of its subsidiaries provided control agreements over certain deposit accounts. Redetermination of the borrowing base under the LINN Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. The lenders under the LINN Credit Facility agreed to defer the April 2016 borrowing base redetermination to May 11, 2016. The Company’s obligations under the LINN Credit Facility are secured by mortgages on certain of its material subsidiaries’ oil and natural gas properties and other personal property as well as a pledge of all ownership interests in the Company’s direct and indirect material subsidiaries. The Company is required to maintain: 1) mortgages on properties representing at least 90% of the total value of oil and natural gas properties included on its most recent reserve report; 2) a minimum liquidity requirement equal to the greater of $500 million and 15% of the then effective available borrowing base after giving effect to certain redemptions or repurchases of certain debt; and 3) an EBITDA to Interest Expense ratio of at least 2.0 to 1.0 currently, 2.25 to 1.0 from March 31, 2017 through June 30, 2017 and 2.5 to 1.0 thereafter. Additionally, the obligations under the LINN Credit Facility are guaranteed by all of the Company’s material subsidiaries, other than Berry, and are required to be guaranteed by any future material subsidiaries. At the Company’s election, interest on borrowings under the LINN Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin between 1.75% and 2.75% per annum (depending on the then-current level of borrowings under the LINN Credit Facility) or the alternate base rate (“ABR”) plus an applicable margin between 0.75% and 1.75% per annum (depending on the then-current level of borrowings under the LINN Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at the LIBOR. The Company is required to pay a commitment fee to the lenders under the LINN Credit Facility, which accrues at a rate per annum of 0.50% on the average daily unused amount of the maximum commitment amount of the lenders. The $500 million term loan has a maturity date of April 2019, subject to a “springing maturity” based on the maturity of any outstanding LINN Energy junior lien debt, and incurs interest based on either the LIBOR plus a margin of 2.75% per annum or the ABR plus a margin of 1.75% per annum, at the Company’s election. Interest is generally payable quarterly for loans bearing interest based on the ABR and at the end of the applicable interest period for loans bearing interest at the LIBOR. The term loan may be repaid at the option of the Company without premium or penalty, subject to breakage costs. While the term loan is outstanding, the Company is required to maintain either: 1) mortgages on properties representing at least 80% of the total value of oil and natural gas properties included on its most recent reserve report, or 2) a Term Loan Collateral Coverage Ratio of at least 2.5 to 1.0 . The Term Loan Collateral Coverage Ratio is defined as the ratio of the present value of future cash flows from proved reserves from the currently mortgaged properties to the lesser of: (i) the then-effective borrowing base and (ii) the maximum commitment amount and the aggregate amount of the term loan outstanding. The other terms and conditions of the LINN Credit Facility, including the financial and other restrictive covenants set forth therein, are applicable to the term loan. Berry Credit Facility Berry’s Second Amended and Restated Credit Agreement (“Berry Credit Facility”) had a borrowing base of $900 million , subject to lender commitments, as of March 31, 2016 . The maturity date is April 2019. At March 31, 2016 , lender commitments under the facility were also $900 million but there was less than $1 million of available borrowing capacity, including outstanding letters of credit. In April 2016, Berry entered into an amendment to the Berry Credit Facility to provide for, among other things, an agreement that (i) certain Specified Events would not become defaults or events of default until May 11, 2016, (ii) the borrowing base would remain constant until May 11, 2016, unless reduced as a result of swap agreement terminations or collateral sales, (iii) Berry would have access to $45 million in cash that is currently restricted in order to fund ordinary course operations and (iv) Berry, the Berry administrative agent and the Berry lenders would negotiate in good faith the terms of a restructuring support agreement in furtherance of a restructuring of the capital structure of Berry. Pursuant to the amendment, the Berry Specified Events are: • The receipt of a going concern qualification or explanatory statement in the auditors’ report on Berry’s financial statements for the year ended December 31, 2015; • The receipt of a going concern qualification or explanatory statement in the auditors’ report on the Company’s consolidated financial statements for the year ended December 31, 2015; • The failure of Berry or the Company to make certain interest payments on their unsecured notes; • The failure to maintain the Interest Coverage Ratio; • Any cross-defaults that may arise on account of any of the foregoing, provided that no event of default is continuing under any document giving rise to such cross default; and • Any failure to provide notice of any of the events described above. As a condition to closing the amendment, Berry provided control agreements over certain deposit accounts. Redetermination of the borrowing base under the Berry Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October. The lenders under the Berry Credit Facility agreed to defer the April 2016 borrowing base redetermination to May 11, 2016. Berry’s obligations under the Berry Credit Facility are secured by mortgages on its oil and natural gas properties and other personal property. Berry is required to maintain: 1) mortgages on properties representing at least 90% of the present value of oil and natural gas properties included on its most recent reserve report, and 2) an EBITDAX to Interest Expense ratio of at least 2.0 to 1.0 currently, 2.25 to 1.0 from March 31, 2017 through June 30, 2017 and 2.5 to 1.0 thereafter. In accordance with the amendment described above, the lenders have agreed that the failure to maintain the EBITDAX to Interest Expense ratio would not be a default or event of default until May 11, 2016. At Berry’s election, interest on borrowings under the Berry Credit Facility is determined by reference to either the LIBOR plus an applicable margin between 1.75% and 2.75% per annum (depending on the then-current level of borrowings under the Berry Credit Facility) or a Base Rate (as defined in the Berry Credit Facility) plus an applicable margin between 0.75% and 1.75% per annum (depending on the then-current level of borrowings under the Berry Credit Facility). Interest is generally payable quarterly for loans bearing interest based on the Base Rate and at the end of the applicable interest period for loans bearing interest at the LIBOR. Berry is required to pay a commitment fee to the lenders under the Berry Credit Facility, which accrues at a rate per annum of 0.5% on the average daily unused amount of the maximum commitment amount of the lenders. The Company refers to the LINN Credit Facility and the Berry Credit Facility, collectively, as the “Credit Facilities.” The filing of the Bankruptcy Petitions constitutes an event of default that accelerated the Company’s obligations under the Credit Facilities. However, under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Company as a result of the default. Senior Secured Second Lien Notes Due December 2020 On November 20, 2015, the Company issued $1.0 billion in aggregate principal amount of 12.00% senior secured second lien notes due December 2020 (“Second Lien Notes”) in exchange for approximately $2.0 billion in aggregate principal amount of certain of its outstanding senior notes. The exchanges were accounted for as a troubled debt restructuring (“TDR”). TDR accounting requires that interest payments on the Second Lien Notes reduce the carrying value of the debt with no interest expense recognized. As a result, the Company’s reported interest expense will be significantly less than the contractual interest payments throughout the term of the Second Lien Notes. There were no interest payments made on the Second Lien Notes for the three months ended March 31, 2016 . In connection with the issuance of the Second Lien Notes, the Company entered into a Registration Rights Agreement with each of the holders (collectively, the “Registration Rights Agreements”), pursuant to the terms of the exchange agreements. Under the Registration Rights Agreements, the Company agreed to use its reasonable efforts to file with the U.S. Securities and Exchange Commission and cause to become effective a registration statement relating to an offer to issue new notes having terms substantially identical to the Second Lien Notes in exchange for outstanding Second Lien Notes within 370 days after the notes were issued. In certain circumstances, the Company may be required to file a shelf registration statement to cover resales of the Second Lien Notes. The Company will be obligated to file one or more registration statements as described above only if the restrictive legend on the Second Lien Notes has not been removed and the Second Lien Notes are not freely tradable pursuant to Rule 144 under the Securities Act of 1933, as amended, as of the 370th day after the notes were issued. If the Company fails to satisfy these obligations, the Company may be required to pay additional interest to holders of the Second Lien Notes under certain circumstances. Repurchases of Senior Notes The Company made no repurchases of its senior notes during the three months ended March 31, 2016 . During the three months ended March 31, 2015 , the Company repurchased on the open market approximately $79 million of its 8.625% senior notes due April 2020. In connection with the repurchases, the Company paid approximately $70 million and recorded a gain on extinguishment of debt of approximately $7 million for the three months ended March 31, 2015 . Notes Covenants The Second Lien Indenture contains covenants that, among other things, limit the Company’s ability and the ability of the Company’s restricted subsidiaries to: (i) declare or pay distributions on, purchase or redeem the Company’s units or purchase or redeem the Company’s or its restricted subsidiaries’ indebtedness secured by liens junior in priority to liens securing the Second Lien Notes, unsecured indebtedness or subordinated indebtedness; (ii) make investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create certain liens; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets; (vii) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries. The Company’s senior notes contain covenants that, among other things, may limit its ability to: (i) pay distributions on, purchase or redeem the Company’s units or redeem its subordinated debt; (ii) make investments; (iii) incur or guarantee additional indebtedness or issue certain types of equity securities; (iv) create certain liens; (v) sell assets; (vi) consolidate, merge or transfer all or substantially all of the Company’s assets; (vii) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (viii) engage in transactions with affiliates; and (ix) create unrestricted subsidiaries. Berry’s senior notes contain covenants that, among other things, may limit its ability to: (i) incur or guarantee additional indebtedness; (ii) pay distributions or dividends on Berry’s equity or redeem its subordinated debt; (iii) create certain liens; (iv) enter into agreements that restrict distributions or other payments from Berry’s restricted subsidiaries to Berry; (v) sell assets; (vi) engage in transactions with affiliates; and (vii) consolidate, merge or transfer all or substantially all of Berry’s assets. In addition, any cash generated by Berry is currently being used by Berry to fund its activities. To the extent that Berry generates cash in excess of its needs and determines to distribute such amounts to LINN Energy, the indentures governing Berry’s senior notes limit the amount it may distribute to LINN Energy to the amount available under a “restricted payments basket,” and Berry may not distribute any such amounts unless it is permitted by the indentures to incur additional debt pursuant to the consolidated coverage ratio test set forth in the Berry indentures. Berry’s restricted payments basket may be increased in accordance with the terms of the Berry indentures by, among other things, 50% of Berry’s future net income, reductions in its indebtedness and restricted investments, and future capital contributions. The filing of the Bankruptcy Petitions constitutes an event of default that accelerated the Company’s obligations under the Second Lien Indenture and the senior notes. However, under the Bankruptcy Code, holders of the Second Lien Notes and the senior notes are stayed from taking any action against the Company as a result of the default. Covenant Violations As of March 31, 2016 , the Company was in default under certain of its debt instruments, which have subsequently been cured or a forbearance has been received. The Company’s filing of the Bankruptcy Petitions described in Note 2 constitutes an event of default that accelerated the Company’s obligations under its Credit Facilities, its Second Lien Notes and its senior notes. Additionally, other events of default, including cross-defaults, are present, including the failure to make interest payments on certain of its senior notes and the receipt of a going concern explanatory paragraph from the Company’s independent registered public accounting firm on the Company’s consolidated financial statements for the year ended December 31, 2015. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Company as a result of an event of default.

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives Commodity Derivatives Historically, the Company has hedged a portion of its forecasted production to reduce exposure to fluctuations in oil and natural gas prices and provide long-term cash flow predictability to manage its business, service debt and, if and when resumed, pay distributions. The current direct NGL hedging market is constrained in terms of price, volume, duration and number of counterparties, which limits the Company’s ability to effectively hedge its NGL production. The Company has also hedged its exposure to natural gas differentials in certain operating areas but does not currently hedge exposure to oil differentials. The Company has historically entered into commodity hedging transactions primarily in the form of swap contracts that are designed to provide a fixed price and, from time to time, put options that are designed to provide a fixed price floor with the opportunity for upside. The Company enters into these transactions with respect to a portion of its projected production or consumption to provide an economic hedge of the risk related to the future commodity prices received or paid. The Company does not enter into derivative contracts for trading purposes. The Company did not designate any of its contracts as cash flow hedges; therefore, the changes in fair value of these instruments are recorded in current earnings. See Note 8 for fair value disclosures about oil and natural gas commodity derivatives. The following table presents derivative positions for the periods indicated as of March 31, 2016 : April 1 - December 31, 2016 2017 2018 Natural gas positions: Fixed price swaps (NYMEX Henry Hub): Hedged volume (MMMBtu) 91,548 120,122 36,500 Average price ($/MMBtu) $ 4.20 $ 4.26 $ 5.00 Put options (NYMEX Henry Hub): Hedged volume (MMMBtu) 57,306 66,886 — Average price ($/MMBtu) $ 5.00 $ 4.88 $ — Oil positions: Fixed price swaps (NYMEX WTI): (1) Hedged volume (MBbls) 8,614 4,755 — Average price ($/Bbl) $ 90.56 $ 89.02 $ — Put options (NYMEX WTI): Hedged volume (MBbls) 2,457 384 — Average price ($/Bbl) $ 90.00 $ 90.00 $ — Natural gas basis differential positions: (2) Panhandle basis swaps: (3) Hedged volume (MMMBtu) 45,049 59,138 16,425 Hedged differential ($/MMBtu) $ (0.32 ) $ (0.33 ) $ (0.33 ) April 1 - December 31, 2016 2017 2018 NWPL Rockies basis swaps: (3) Hedged volume (MMMBtu) 50,143 38,880 10,804 Hedged differential ($/MMBtu) $ (0.24 ) $ (0.19 ) $ (0.19 ) MichCon basis swaps: (3) Hedged volume (MMMBtu) 5,830 7,437 2,044 Hedged differential ($/MMBtu) $ 0.05 $ 0.05 $ 0.05 Houston Ship Channel basis swaps: (3) Hedged volume (MMMBtu) 26,128 36,730 986 Hedged differential ($/MMBtu) $ (0.02 ) $ (0.02 ) $ (0.08 ) Permian basis swaps: (3) Hedged volume (MMMBtu) 2,274 2,629 1,314 Hedged differential ($/MMBtu) $ (0.20 ) $ (0.20 ) $ (0.20 ) SoCal basis swaps: (4) Hedged volume (MMMBtu) 24,750 — — Hedged differential ($/MMBtu) $ (0.03 ) $ — $ — Oil timing differential positions: Trade month roll swaps (NYMEX WTI): (5) Hedged volume (MBbls) 1,992 2,654 — Hedged differential ($/Bbl) $ 0.25 $ 0.25 $ — (1) Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for the year ending December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, at counterparty election on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other year. (2) Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price. (3) For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis. (4) For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis. (5) The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”). The Company did not enter into any commodity derivative contracts during the three months ended March 31, 2016 . During the three months ended March 31, 2015 , the Company entered into commodity derivative contracts consisting of natural gas basis swaps for May 2015 through December 2017 to hedge exposure to differentials in certain producing areas and oil swaps for April 2015 through December 2015. In addition, the Company entered into natural gas basis swaps for May 2015 through December 2016 to hedge exposure to the differential in California, where it consumes natural gas in its heavy oil development operations. Settled derivatives on natural gas production for the three months ended March 31, 2016 , included volumes of 49,257 MMMBtu at an average contract price of $4.51 per MMBtu. Settled derivatives on oil production for the three months ended March 31, 2016 , included volumes of 3,664 MBbls at an average contract price of $90.44 per Bbl. Settled derivatives on natural gas production for the three months ended March 31, 2015 , included volumes of 46,823 MMMBtu at an average contract price of $5.12 per MMBtu. Settled derivatives on oil production for the three months ended March 31, 2015 , included volumes of 3,975 MBbls at an average contract price of $94.29 per Bbl. The natural gas derivatives are settled based on the closing price of NYMEX Henry Hub natural gas on the last trading day for the delivery month, which occurs on the third business day preceding the delivery month, or the relevant index prices of natural gas published in Inside FERC’s Gas Market Report on the first business day of the delivery month. The oil derivatives are settled based on the average closing price of NYMEX WTI crude oil for each day of the delivery month. Balance Sheet Presentation The Company’s commodity derivatives are presented on a net basis in “derivative instruments” on the condensed consolidated balance sheets. The following summarizes the fair value of derivatives outstanding on a gross basis: March 31, 2016 December 31, 2015 (in thousands) Assets: Commodity derivatives $ 1,569,054 $ 1,812,375 Liabilities: Commodity derivatives $ 22,651 $ 28,842 By using derivative instruments to economically hedge exposures to changes in commodity prices, the Company exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Company, which creates credit risk. The Company’s counterparties are current participants or affiliates of participants in its Credit Facilities or were participants or affiliates of participants in its Credit Facilities at the time it originally entered into the derivatives. The Credit Facilities are secured by the Company’s oil, natural gas and NGL reserves; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties. The maximum amount of loss due to credit risk that the Company would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of financial instruments, was approximately $1.6 billion at March 31, 2016 . 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 consolidated statements of operations is presented below: Three Months Ended 2016 2015 (in thousands) Gains on oil and natural gas derivatives $ 109,961 $ 424,781 Lease operating expenses (1) (3,368 ) (926 ) Total gains on oil and natural gas derivatives $ 106,593 $ 423,855 (1) Consists of gains and (losses) on derivatives entered into in March 2015 to hedge exposure to differentials in consuming areas. For the three months ended March 31, 2016 , and March 31, 2015 , the Company received net cash settlements of approximately $344 million and $282 million , respectively. Commodity Derivatives – Subsequent Event In April 2016 and May 2016, in connection with the Company’s restructuring efforts, the Company canceled (prior to the contract settlement dates) all of its derivative contracts (with the exception of Berry’s current remaining 26,108 MMMBtu of natural gas basis swaps for 2016) for net cash proceeds of approximately $1.2 billion . All net cash proceeds received were used to make permanent repayments of a portion of the borrowings outstanding under the LINN Credit Facility. Berry’s derivative contracts may be terminated unilaterally by the counterparty as a result of the bankruptcy filing or, if not automatically terminated, Berry may elect to monetize or terminate its derivative contracts.

Fair Value Measurements on a Re

Fair Value Measurements on a Recurring Basis	3 Months Ended
	Mar. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements on a Recurring Basis	Fair Value Measurements on a Recurring Basis The Company accounts for its commodity derivatives at fair value (see Note 7) on a recurring basis. The Company determines the fair value of its oil and natural gas derivatives utilizing pricing models that use a variety of techniques, including market quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties. Company management validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming that those instruments trade in active markets. Assumed credit risk adjustments, based on published credit ratings, public bond yield spreads and credit default swap spreads are applied to the Company’s commodity derivatives. Fair Value Hierarchy In accordance with applicable accounting standards, the Company has categorized its financial instruments, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis: March 31, 2016 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 1,569,054 $ (20,987 ) $ 1,548,067 Liabilities: Commodity derivatives $ 22,651 $ (20,987 ) $ 1,664 December 31, 2015 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 1,812,375 $ (25,744 ) $ 1,786,631 Liabilities: Commodity derivatives $ 28,842 $ (25,744 ) $ 3,098 (1) Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company has the obligation to plug and abandon oil and natural gas wells and related equipment at the end of production operations. Estimated asset retirement costs are recognized as liabilities with an increase to the carrying amounts of the related long-lived assets when the obligation is incurred. The liabilities are included in “other accrued liabilities” and “other noncurrent liabilities” on the condensed consolidated balance sheets. Accretion expense is included in “depreciation, depletion and amortization” on the condensed consolidated statements of operations. The fair value of additions to the asset retirement obligations is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plug and abandon costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors ( 2% for the three months ended March 31, 2016 ); and (iv) a credit-adjusted risk-free interest rate (average of 5.9% for the three months ended March 31, 2016 ). 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 table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2015 $ 523,541 Liabilities added from drilling 307 Current year accretion expense 7,641 Settlements (2,756 ) Asset retirement obligations at March 31, 2016 $ 528,733

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies For a certain statewide class action royalty payment dispute where a reserve has not yet been established, the court denied plaintiffs’ motion for class certification, which the plaintiffs subsequently appealed. The Company has denied that it has any liability on the claims and has raised arguments and defenses that, if accepted by the courts, will result in no loss to the Company. In another statewide class action royalty payment dispute where a reserve has not yet been established, the parties have stayed the dispute pending resolution of royalty disputes between other parties. In addition, the Company is involved in various other disputes arising in the ordinary course of business. The Company is not currently a party to any litigation or pending claims that it believes would have a material adverse effect on its overall business, financial position, results of operations or liquidity; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved. During the three months ended March 31, 2016 , and March 31, 2015 , 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. The commencement of the Chapter 11 proceedings automatically stayed certain actions against the Company, including actions to collect pre-petition liabilities or to exercise control over the property of the Company’s bankruptcy estates, and the Company intends to seek authority to pay all general claims in the ordinary course of business notwithstanding the commencement of the Chapter 11 proceedings in a manner consistent with the Restructuring Support Agreement. The Plan in the Chapter 11 proceedings, if confirmed, will provide for the treatment of claims against the Company’s bankruptcy estates, including pre-petition liabilities that have not otherwise been satisfied or addressed during the Chapter 11 proceedings. See Note 2 for additional information.

Earnings Per Unit

Earnings Per Unit	3 Months Ended
	Mar. 31, 2016
Earnings Per Share [Abstract]
Earnings Per Unit	Earnings Per Unit Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted earnings per unit is computed by adjusting the average number of units outstanding for the dilutive effect, if any, of unit equivalents. The Company uses the treasury stock method to determine the dilutive effect. The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net loss: Three Months Ended March 31, 2016 2015 (in thousands, except per unit data) Net loss $ (1,347,746 ) $ (339,160 ) Allocated to participating securities — (1,781 ) $ (1,347,746 ) $ (340,941 ) Basic net loss per unit $ (3.83 ) $ (1.03 ) Diluted net loss per unit $ (3.83 ) $ (1.03 ) Basic weighted average units outstanding 352,234 330,642 Dilutive effect of unit equivalents — — Diluted weighted average units outstanding 352,234 330,642 Basic units outstanding excludes the effect of weighted average anti-dilutive unit equivalents related to approximately 1 million and 5 million unit options and warrants for the three months ended March 31, 2016 , and March 31, 2015 , respectively. All equivalent units were antidilutive for both the three months ended March 31, 2016 , and March 31, 2015 .

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company is a limited liability company treated as a partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits are passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Company’s subsidiaries are Subchapter C-corporations subject to federal and state income taxes. As such, with the exception of the state of Texas and certain subsidiaries, the Company is not a taxable entity, it does not directly pay federal and state income taxes and recognition has not been given to federal and state income taxes for the operations of the Company. Amounts recognized for income taxes are reported in “income tax expense (benefit)” on the condensed consolidated statements of operations.

Supplemental Disclosures to the

Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows	3 Months Ended
	Mar. 31, 2016
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows [Abstract]
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows	Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Three Months Ended 2016 2015 (in thousands) Cash payments for interest, net of amounts capitalized $ 30,135 $ 98,541 Cash payments for income taxes $ 1,228 $ 57 Noncash investing activities: Accrued capital expenditures $ 31,348 $ 161,247 For purposes of the condensed consolidated statements of cash flows, the Company considers all highly liquid short-term investments with original maturities of three months or less to be cash equivalents. At March 31, 2016 , and December 31, 2015, “restricted cash” on the condensed consolidated balance sheets includes $250 million that LINN Energy borrowed under the LINN Credit Facility and contributed to Berry in May 2015 to post with Berry’s lenders in connection with the reduction in the Berry Credit Facility’s borrowing base, as well as associated interest income. Restricted cash also includes approximately $7 million at both March 31, 2016 , and December 31, 2015, of cash deposited by the Company into a separate account designated for asset retirement obligations in accordance with contractual agreements. At December 31, 2015, net outstanding checks of approximately $21 million were reclassified and included in “accounts payable and accrued expenses” on the condensed consolidated balance sheets. At March 31, 2016 , no net outstanding checks were reclassified. Net outstanding checks are presented as cash flows from financing activities and included in “other” on the condensed consolidated statements of cash flows.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions LinnCo LinnCo, an affiliate of LINN Energy, was formed on April 30, 2012. LinnCo’s initial sole purpose was to own units in LINN Energy. In connection with the 2013 acquisition of Berry, LinnCo amended its limited liability company agreement to permit, among other things, the acquisition and subsequent contribution of assets to LINN Energy. All of LinnCo’s common shares are held by the public. As of March 31, 2016 , LinnCo had no significant assets or operations other than those related to its interest in LINN Energy and owned approximately 36% of LINN Energy’s outstanding units. In March 2016, LinnCo filed a Registration Statement on Form S-4 related to an offer to exchange each outstanding unit representing limited liability company interests of LINN Energy for one common share representing limited liability company interests of LinnCo. In April 2016, LinnCo extended the offer to April 25, 2016. The offer expired on April 25, 2016, and on April 26, 2016, LinnCo commenced a subsequent offering period that will expire on May 23, 2016, unless extended. During April 2016, 104,719,468 LINN Energy units were exchanged for an equal number of LinnCo shares. As a result of the exchange of LINN Energy units for LinnCo shares, LinnCo’s ownership of LINN Energy’s outstanding units increased from approximately 36% to approximately 66% as of April 30, 2016. LINN Energy has agreed to provide to LinnCo, or to pay on LinnCo’s behalf, any financial, legal, accounting, tax advisory, financial advisory and engineering fees, and other administrative and out-of-pocket expenses incurred by LinnCo, along with any other expenses incurred in connection with any public offering of shares in LinnCo or incurred as a result of being a publicly traded entity. These expenses include costs associated with annual, quarterly and other reports to holders of LinnCo shares, tax return and Form 1099 preparation and distribution, NASDAQ listing fees, printing costs, independent auditor fees and expenses, legal counsel fees and expenses, limited liability company governance and compliance expenses and registrar and transfer agent fees. In addition, the Company has agreed to indemnify LinnCo and its officers and directors for damages suffered or costs incurred (other than income taxes payable by LinnCo) in connection with carrying out LinnCo’s activities. All expenses and costs paid by LINN Energy on LinnCo’s behalf are expensed by LINN Energy. For the three months ended March 31, 2016 , LinnCo incurred total general and administrative expenses and certain offering costs of approximately $1.7 million , of which approximately $918,000 had been paid by LINN Energy on LinnCo’s behalf as of March 31, 2016 . The expenses for the three months ended March 31, 2016 , include approximately $603,000 related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses. For the three months ended March 31, 2015 , LinnCo incurred total general and administrative expenses and certain offering costs of approximately $1.4 million , of which approximately $1.1 million had been paid by LINN Energy on LinnCo’s behalf as of March 31, 2015 . The expenses for the three months ended March 31, 2015 , include approximately $491,000 related to services provided by LINN Energy necessary for the conduct of LinnCo’s business, such as accounting, legal, tax, information technology and other expenses. The Company did not pay any distributions to LinnCo during the three months ended March 31, 2016 . During the three months ended March 31, 2015 , the Company paid approximately $40 million in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy. Other One of the Company’s directors is the President and Chief Executive Officer of Superior Energy Services, Inc. (“Superior”), which provides oilfield services to the Company. For the three months ended March 31, 2016 , and March 31, 2015 , the Company incurred expenditures of approximately $2 million and $3 million , respectively, related to services rendered by Superior and its subsidiaries.

Subsidiary Guarantors

Subsidiary Guarantors	3 Months Ended
	Mar. 31, 2016
Condensed Consolidating Financial Information [Abstract]
Subsidiary Guarantors	Subsidiary Guarantors Linn Energy, LLC’s senior notes due May 2019, senior notes due November 2019, senior notes due April 2020, Second Lien Notes, senior notes due February 2021 and senior notes due September 2021 are guaranteed by all of the Company’s material subsidiaries, other than Berry Petroleum Company, LLC, which is an indirect 100% wholly owned subsidiary of the Company. The following condensed consolidating financial information presents the financial information of Linn Energy, LLC, the guarantor subsidiaries and the non-guarantor subsidiary in accordance with SEC Regulation S-X Rule 3‑10. The condensed consolidating financial information for the co-issuer, Linn Energy Finance Corp., is not presented as it has no assets, operations or cash flows. The financial information may not necessarily be indicative of the financial position or results of operations had the guarantor subsidiaries or non-guarantor subsidiary operated as independent entities. There are no restrictions on the Company’s ability to obtain cash dividends or other distributions of funds from the guarantor subsidiaries. CONDENSED CONSOLIDATING BALANCE SHEETS March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) ASSETS Current assets: Cash and cash equivalents $ 917,814 $ 134,408 $ 7,334 $ — $ 1,059,556 Accounts receivable – trade, net — 145,297 40,755 — 186,052 Accounts receivable – affiliates 2,885,185 50,518 — (2,935,703 ) — Derivative instruments — 1,095,929 295 — 1,096,224 Other current assets 23,159 59,170 19,582 — 101,911 Total current assets 3,826,158 1,485,322 67,966 (2,935,703 ) 2,443,743 Noncurrent assets: Oil and natural gas properties (successful efforts method) — 13,129,776 5,019,579 — 18,149,355 Less accumulated depletion and amortization — (9,776,724 ) (2,682,011 ) 65,173 (12,393,562 ) — 3,353,052 2,337,568 65,173 5,755,793 Other property and equipment — 600,783 113,947 — 714,730 Less accumulated depreciation — (194,874 ) (14,617 ) — (209,491 ) — 405,909 99,330 — 505,239 Derivative instruments — 451,843 — — 451,843 Restricted cash — 7,208 250,612 — 257,820 Notes receivable – affiliates 162,700 — — (162,700 ) — Investments in consolidated subsidiaries 2,675,208 — — (2,675,208 ) — Other noncurrent assets — 8,223 16,836 — 25,059 2,837,908 467,274 267,448 (2,837,908 ) 734,722 Total noncurrent assets 2,837,908 4,226,235 2,704,346 (2,772,735 ) 6,995,754 Total assets $ 6,664,066 $ 5,711,557 $ 2,772,312 $ (5,708,438 ) $ 9,439,497 LIABILITIES AND UNITHOLDERS’ CAPITAL (DEFICIT) Current liabilities: Accounts payable and accrued expenses $ — $ 269,911 $ 98,163 $ — $ 368,074 Accounts payable – affiliates — 2,885,185 50,518 (2,935,703 ) — Derivative instruments — — 1,190 — 1,190 Current portion of long-term debt, net 3,720,157 — 873,175 — 4,593,332 Other accrued liabilities 107,536 32,985 29,996 — 170,517 Total current liabilities 3,827,693 3,188,081 1,053,042 (2,935,703 ) 5,133,113 Noncurrent liabilities: Derivative instruments — 474 — — 474 Long-term debt, net 4,449,883 — 844,927 — 5,294,810 Notes payable – affiliates — 162,700 — (162,700 ) — Other noncurrent liabilities — 402,515 213,003 — 615,518 Total noncurrent liabilities 4,449,883 565,689 1,057,930 (162,700 ) 5,910,802 Unitholders’ capital (deficit): Units issued and outstanding 5,346,253 4,831,568 2,798,713 (7,621,189 ) 5,355,345 Accumulated deficit (6,959,763 ) (2,873,781 ) (2,137,373 ) 5,011,154 (6,959,763 ) (1,613,510 ) 1,957,787 661,340 (2,610,035 ) (1,604,418 ) Total liabilities and unitholders’ capital (deficit) $ 6,664,066 $ 5,711,557 $ 2,772,312 $ (5,708,438 ) $ 9,439,497 CONDENSED CONSOLIDATING BALANCE SHEETS December 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) ASSETS Current assets: Cash and cash equivalents $ 1,073 $ 72 $ 1,023 $ — $ 2,168 Accounts receivable – trade, net — 170,503 46,053 — 216,556 Accounts receivable – affiliates 2,920,082 8,621 — (2,928,703 ) — Derivative instruments — 1,207,012 13,218 — 1,220,230 Other current assets 25,090 49,606 20,897 — 95,593 Total current assets 2,946,245 1,435,814 81,191 (2,928,703 ) 1,534,547 Noncurrent assets: Oil and natural gas properties (successful efforts method) — 13,110,094 5,011,061 — 18,121,155 Less accumulated depletion and amortization — (9,557,283 ) (1,596,165 ) 55,956 (11,097,492 ) — 3,552,811 3,414,896 55,956 7,023,663 Other property and equipment — 597,216 111,495 — 708,711 Less accumulated depreciation — (183,139 ) (12,522 ) — (195,661 ) — 414,077 98,973 — 513,050 Derivative instruments — 566,401 — — 566,401 Restricted cash — 7,004 250,359 — 257,363 Notes receivable – affiliates 175,100 — — (175,100 ) — Investments in consolidated subsidiaries 3,940,444 — — (3,940,444 ) — Other noncurrent assets — 17,178 16,057 (1 ) 33,234 4,115,544 590,583 266,416 (4,115,545 ) 856,998 Total noncurrent assets 4,115,544 4,557,471 3,780,285 (4,059,589 ) 8,393,711 Total assets $ 7,061,789 $ 5,993,285 $ 3,861,476 $ (6,988,292 ) $ 9,928,258 LIABILITIES AND UNITHOLDERS’ CAPITAL (DEFICIT) Current liabilities: Accounts payable and accrued expenses $ 1,285 $ 336,962 $ 117,127 $ — $ 455,374 Accounts payable – affiliates — 2,920,082 8,621 (2,928,703 ) — Derivative instruments — — 2,241 — 2,241 Current portion of long-term debt, net 2,841,518 — 873,175 — 3,714,693 Other accrued liabilities 49,861 52,997 16,735 — 119,593 Total current liabilities 2,892,664 3,310,041 1,017,899 (2,928,703 ) 4,291,901 Noncurrent liabilities: Derivative instruments — 857 — — 857 Long-term debt, net 4,447,308 — 845,368 — 5,292,676 Notes payable – affiliates — 175,100 — (175,100 ) — Other noncurrent liabilities — 399,676 212,050 (1 ) 611,725 Total noncurrent liabilities 4,447,308 575,633 1,057,418 (175,101 ) 5,905,258 Unitholders’ capital (deficit): Units issued and outstanding 5,333,834 4,831,758 2,798,713 (7,621,189 ) 5,343,116 Accumulated deficit (5,612,017 ) (2,724,147 ) (1,012,554 ) 3,736,701 (5,612,017 ) (278,183 ) 2,107,611 1,786,159 (3,884,488 ) (268,901 ) Total liabilities and unitholders’ capital (deficit) $ 7,061,789 $ 5,993,285 $ 3,861,476 $ (6,988,292 ) $ 9,928,258 CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Revenues and other: Oil, natural gas and natural gas liquids sales $ — $ 199,849 $ 83,466 $ — $ 283,315 Gains on oil and natural gas derivatives — 109,453 508 — 109,961 Marketing revenues — 9,061 5,244 — 14,305 Other revenues — 5,138 2,048 — 7,186 — 323,501 91,266 — 414,767 Expenses: Lease operating expenses — 87,552 50,093 — 137,645 Transportation expenses — 41,994 12,929 — 54,923 Marketing expenses — 7,833 4,455 — 12,288 General and administrative expenses — 61,357 25,172 — 86,529 Exploration costs — 2,693 — — 2,693 Depreciation, depletion and amortization — 108,045 58,843 (2,830 ) 164,058 Impairment of long-lived assets — 129,703 1,030,588 (6,387 ) 1,153,904 Taxes, other than income taxes 2 19,752 14,313 — 34,067 (Gains) losses on sale of assets and other, net — 1,269 (192 ) — 1,077 2 460,198 1,196,201 (9,217 ) 1,647,184 Other income and (expenses): Interest expense, net of amounts capitalized (85,472 ) 205 (19,952 ) — (105,219 ) Interest expense – affiliates — (2,969 ) — 2,969 — Interest income – affiliates 2,969 — — (2,969 ) — Equity in losses from consolidated subsidiaries (1,265,236 ) — — 1,265,236 — Other, net (5 ) 73 66 — 134 (1,347,744 ) (2,691 ) (19,886 ) 1,265,236 (105,085 ) Loss before income taxes (1,347,746 ) (139,388 ) (1,124,821 ) 1,274,453 (1,337,502 ) Income tax expense (benefit) — 10,246 (2 ) — 10,244 Net loss $ (1,347,746 ) $ (149,634 ) $ (1,124,819 ) $ 1,274,453 $ (1,347,746 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended March 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Revenues and other: Oil, natural gas and natural gas liquids sales $ — $ 293,983 $ 156,586 $ — $ 450,569 Gains on oil and natural gas derivatives — 421,514 3,267 — 424,781 Marketing revenues — 26,212 7,532 — 33,744 Other revenues — 5,557 1,896 — 7,453 — 747,266 169,281 — 916,547 Expenses: Lease operating expenses — 105,832 67,189 — 173,021 Transportation expenses — 40,934 12,606 — 53,540 Marketing expenses — 23,196 5,645 — 28,841 General and administrative expenses — 57,781 21,187 — 78,968 Exploration costs — 396 — — 396 Depreciation, depletion and amortization — 140,699 72,979 1,336 215,014 Impairment of long-lived assets — 325,417 272,000 (64,800 ) 532,617 Taxes, other than income taxes 2 30,711 23,332 — 54,045 Gains on sale of assets and other, net — (7,814 ) (4,473 ) — (12,287 ) 2 717,152 470,465 (63,464 ) 1,124,155 Other income and (expenses): Interest expense, net of amounts capitalized (123,386 ) 1,706 (21,421 ) — (143,101 ) Interest expense – affiliates — (2,382 ) — 2,382 — Interest income – affiliates 2,382 — — (2,382 ) — Gain on extinguishment of debt 6,635 — — — 6,635 Equity in losses from consolidated subsidiaries (222,811 ) — — 222,811 — Other, net (1,978 ) (65 ) (170 ) — (2,213 ) (339,158 ) (741 ) (21,591 ) 222,811 (138,679 ) Income (loss) before income taxes (339,160 ) 29,373 (322,775 ) 286,275 (346,287 ) Income tax benefit — (7,077 ) (50 ) — (7,127 ) Net income (loss) $ (339,160 ) $ 36,450 $ (322,725 ) $ 286,275 $ (339,160 ) CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS For the Three Months Ended March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from operating activities: Net loss $ (1,347,746 ) $ (149,634 ) $ (1,124,819 ) $ 1,274,453 $ (1,347,746 ) Adjustments to reconcile net loss to net cash provided by operating activities: Depreciation, depletion and amortization — 108,045 58,843 (2,830 ) 164,058 Impairment of long-lived assets — 129,703 1,030,588 (6,387 ) 1,153,904 Unit-based compensation expenses — 12,425 — — 12,425 Amortization and write-off of deferred financing fees 4,676 — 182 — 4,858 (Gains) losses on sale of assets and other, net — 2,226 (310 ) — 1,916 Equity in losses from consolidated subsidiaries 1,265,236 — — (1,265,236 ) — Deferred income taxes — 9,422 (2 ) — 9,420 Derivatives activities: Total (gains) losses — (109,454 ) 2,861 — (106,593 ) Cash settlements — 334,712 9,011 — 343,723 Changes in assets and liabilities: Decrease in accounts receivable – trade, net — 25,815 5,298 — 31,113 (Increase) decrease in accounts receivable – affiliates 49,034 (41,897 ) — (7,137 ) — Increase in other assets — (8,225 ) (64 ) — (8,289 ) Decrease in accounts payable and accrued expenses (36 ) (594 ) (13,897 ) — (14,527 ) Increase (decrease) in accounts payable and accrued expenses – affiliates — (49,034 ) 41,897 7,137 — Increase (decrease) in other liabilities 56,876 (21,163 ) 11,053 — 46,766 Net cash provided by operating activities 28,040 242,347 20,641 — 291,028 Cash flow from investing activities: Development of oil and natural gas properties — (70,407 ) (11,019 ) — (81,426 ) Purchases of other property and equipment — (6,404 ) (3,327 ) — (9,731 ) Change in notes receivable with affiliate 12,400 — — (12,400 ) — Proceeds from sale of properties and equipment and other (918 ) 638 16 — (264 ) Net cash provided by (used in) investing activities 11,482 (76,173 ) (14,330 ) (12,400 ) (91,421 ) Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from financing activities: Proceeds from borrowings 978,500 — — — 978,500 Repayments of debt (100,000 ) — — — (100,000 ) Financing fees and offering costs (32 ) — — — (32 ) Change in notes payable with affiliate — (12,400 ) — 12,400 — Other (1,249 ) (19,438 ) — — (20,687 ) Net cash provided by (used in) financing activities 877,219 (31,838 ) — 12,400 857,781 Net increase in cash and cash equivalents 916,741 134,336 6,311 — 1,057,388 Cash and cash equivalents: Beginning 1,073 72 1,023 — 2,168 Ending $ 917,814 $ 134,408 $ 7,334 $ — $ 1,059,556 CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS For the Three Months Ended March 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from operating activities: Net income (loss) $ (339,160 ) $ 36,450 $ (322,725 ) $ 286,275 $ (339,160 ) Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: Depreciation, depletion and amortization — 140,699 72,979 1,336 215,014 Impairment of long-lived assets — 325,417 272,000 (64,800 ) 532,617 Unit-based compensation expenses — 20,510 — — 20,510 Gain on extinguishment of debt (6,635 ) — — — (6,635 ) Amortization and write-off of deferred financing fees 6,453 — 259 — 6,712 Gains on sale of assets and other, net — (5,243 ) (1,857 ) — (7,100 ) Equity in losses from consolidated subsidiaries 222,811 — — (222,811 ) — Deferred income taxes — (7,108 ) (50 ) — (7,158 ) Derivatives activities: Total gains — (421,514 ) (2,341 ) — (423,855 ) Cash settlements — 254,569 27,513 — 282,082 Changes in assets and liabilities: Decrease in accounts receivable – trade, net 21,921 96,917 16,392 — 135,230 (Increase) decrease in accounts receivable – affiliates 17,082 (19,856 ) — 2,774 — Increase in other assets — (8,521 ) (3,878 ) — (12,399 ) Decrease in accounts payable and accrued expenses (290 ) (3,844 ) (25,734 ) — (29,868 ) Increase (decrease) in accounts payable and accrued expenses – affiliates — (17,082 ) 19,856 (2,774 ) — Increase (decrease) in other liabilities 42,695 (24,057 ) (9,925 ) — 8,713 Net cash provided by (used in) operating activities (35,123 ) 367,337 42,489 — 374,703 Cash flow from investing activities: Development of oil and natural gas properties — (263,209 ) (1,609 ) — (264,818 ) Purchases of other property and equipment — (11,309 ) (1,092 ) — (12,401 ) Investment in affiliates 43,778 — — (43,778 ) — Change in notes receivable with affiliate (16,400 ) — — 16,400 — Proceeds from sale of properties and equipment and other (1,121 ) 24,808 3,813 — 27,500 Net cash provided by (used in) investing activities 26,257 (249,710 ) 1,112 (27,378 ) (249,719 ) Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from financing activities: Proceeds from sale of units 15,900 — — — 15,900 Proceeds from borrowings 395,000 — — — 395,000 Repayments of debt (280,287 ) — — — (280,287 ) Distributions to unitholders (104,815 ) — — — (104,815 ) Financing fees and offering costs (453 ) — — — (453 ) Change in notes payable with affiliate — 16,400 — (16,400 ) — Distribution to affiliate — — (43,778 ) 43,778 — Excess tax benefit from unit-based compensation (8,867 ) — — — (8,867 ) Other (3,786 ) (91,188 ) 15 — (94,959 ) Net cash provided by (used in) financing activities 12,692 (74,788 ) (43,763 ) 27,378 (78,481 ) Net increase (decrease) in cash and cash equivalents 3,826 42,839 (162 ) — 46,503 Cash and cash equivalents: Beginning 38 185 1,586 — 1,809 Ending $ 3,864 $ 43,024 $ 1,424 $ — $ 48,312

Basis of Presentation (Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business Linn Energy, LLC (“LINN Energy” or the “Company”) is an independent oil and natural gas company. LINN Energy’s mission is to acquire, develop and maximize cash flow from a growing portfolio of long-life oil and natural gas assets. The Company’s properties are located in eight operating regions in the United States (“U.S.”), in the Rockies, the Hugoton Basin, California, the Mid-Continent, east Texas and north Louisiana (“TexLa”), the Permian Basin, Michigan/Illinois and south Texas.
Principles of Consolidation and Reporting	Principles of Consolidation and Reporting The information reported herein reflects all normal recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results for the interim periods. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted under Securities and Exchange Commission (“SEC”) rules and regulations; as such, this report should be read in conjunction with the financial statements and notes in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. The results reported in these unaudited condensed consolidated financial statements should not necessarily be taken as indicative of results that may be expected for the entire year. The condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. All significant intercompany transactions and balances have been eliminated upon consolidation. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. The reference to “Berry” herein refers to Berry Petroleum Company, LLC, which is an indirect 100% wholly owned subsidiary of LINN Energy. The reference to “LinnCo” herein refers to LinnCo, LLC, which is an affiliate of LINN Energy. The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. Such reclassifications have no impact on previously reported net income (loss), unitholders’ deficit or cash flows.
Use of Estimates	Use of Estimates The preparation of the accompanying condensed consolidated financial statements in conformity with GAAP requires management of the Company to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the amount of assets and liabilities reported, disclosures about contingent assets and liabilities, and reported amounts of revenues and expenses. The estimates that are particularly significant to the financial statements include estimates of the Company’s reserves of oil, natural gas and natural gas liquids (“NGL”), future cash flows from oil and natural gas properties, depreciation, depletion and amortization, asset retirement obligations, certain revenues and operating expenses, fair values of commodity derivatives and fair values of assets acquired and liabilities assumed. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best estimates and judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from these estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
Recently Issued Accounting Standards	Recently Issued Accounting Standards In March 2016, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Components of this ASU will be applied either prospectively, retrospectively or under a modified retrospective basis (as applicable for the respective provision) as of the date of adoption and is effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. The Company is currently evaluating the impact of the adoption of this ASU on its consolidated financial statements and related disclosures. In February 2016, the FASB issued an ASU that is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2018, and interim periods within those years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its consolidated financial statements and related disclosures. In November 2015, the FASB issued an ASU that is intended to simplify the presentation of deferred taxes by requiring that all deferred taxes be classified as noncurrent, presented as a single noncurrent amount for each tax-paying component of an entity. The ASU is effective for fiscal years beginning after December 15, 2016; however, the Company early adopted it on January 1, 2016, on a retrospective basis. The adoption of this ASU resulted in the reclassification of previously-classified net current deferred taxes of approximately $22 million from “other current assets,” as well as previously-classified net noncurrent deferred tax liabilities of approximately $11 million from “other noncurrent liabilities,” to “other noncurrent assets” resulting in net noncurrent deferred taxes of approximately $11 million on the Company’s consolidated balance sheet at December 31, 2015. There was no impact to the consolidated statements of operations. In April 2015, the FASB issued an 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 on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The Company adopted this ASU on January 1, 2016, on a retrospective basis. The adoption of this ASU resulted in the reclassification of approximately $37 million of unamortized deferred financing fees (which excludes deferred financing fees associated with the Company’s Credit Facilities, as defined in Note 6, which were not reclassified) from an asset to a direct deduction from the carrying amount of the associated debt liability on the consolidated balance sheet at December 31, 2015. There was no impact to the consolidated statements of operations. In August 2014, the FASB issued an ASU that provides guidance about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. This ASU is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter (early adoption permitted). The Company does not expect the adoption of this ASU to have a material impact on its financial statements or related disclosures. In May 2014, the FASB issued an ASU that is intended to improve and converge the financial reporting requirements for revenue from contracts with customers. This ASU will be applied either retrospectively or as a cumulative-effect adjustment as of the date of adoption and is effective for fiscal years beginning after December 15, 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 consolidated financial statements and related disclosures.

Oil and Natural Gas Properties

Oil and Natural Gas Properties (Tables)	3 Months Ended
	Mar. 31, 2016
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities	Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below: March 31, December 31, (in thousands) Proved properties: Leasehold acquisition $ 13,372,330 $ 13,361,171 Development 3,003,402 2,976,643 Unproved properties 1,773,623 1,783,341 18,149,355 18,121,155 Less accumulated depletion and amortization (12,393,562 ) (11,097,492 ) $ 5,755,793 $ 7,023,663
Details of Impairment of Long-Lived Assets Held and Used by Asset	Based on the analysis described above, the Company recorded the following noncash impairment charges (before and after tax) associated with proved oil and natural gas properties: Three Months Ended 2016 2015 (in thousands) California region $ 984,288 $ 207,200 Mid-Continent region 129,703 5,703 Rockies region 26,677 — Hugoton Basin region — 277,914 TexLa region — 33,100 South Texas region — 8,700 $ 1,140,668 $ 532,617

Unit-Based Compensation (Tables

Unit-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Employee Service Share-Based Compensation Expense	A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below: Three Months Ended 2016 2015 (in thousands) General and administrative expenses $ 9,460 $ 16,633 Lease operating expenses 2,965 3,877 Total unit-based compensation expenses $ 12,425 $ 20,510 Income tax benefit $ 4,591 $ 7,579

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Summary of Outstanding Debt	The following summarizes the Company’s outstanding debt: March 31, 2016 December 31, 2015 (in thousands, except percentages) LINN credit facility (1) $ 3,093,500 $ 2,215,000 Berry credit facility (2) 873,175 873,175 Term loan (3) 500,000 500,000 6.50% senior notes due May 2019 562,234 562,234 6.25% senior notes due November 2019 581,402 581,402 8.625% senior notes due April 2020 718,596 718,596 6.75% Berry senior notes due November 2020 261,100 261,100 12.00% senior secured second lien notes due December 2020 (4) 1,000,000 1,000,000 Interest payable on senior secured second lien notes due December 2020 (4) 608,333 608,333 7.75% senior notes due February 2021 779,474 779,474 6.50% senior notes due September 2021 381,423 381,423 6.375% Berry senior notes due September 2022 572,700 572,700 Net unamortized discounts and premiums (8,318 ) (8,694 ) Net unamortized deferred financing fees (35,477 ) (37,374 ) Total debt, net 9,888,142 9,007,369 Less current portion, net (5) (4,593,332 ) (3,714,693 ) Long-term debt, net $ 5,294,810 $ 5,292,676 (1) Variable interest rates of 3.18% and 2.66% at March 31, 2016 , and December 31, 2015, respectively. (2) Variable interest rates of 5.25% and 3.17% at March 31, 2016 , and December 31, 2015, respectively. (3) Variable interest rates of 3.18% and 3.17% at March 31, 2016 , and December 31, 2015, respectively. (4) The issuance of the Second Lien Notes was accounted for as a troubled debt restructuring, which requires that interest payments on the Second Lien Notes reduce the carrying value of the debt with no interest expense recognized. (5) Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at March 31, 2016 , and December 31, 2015. The current portion as of both March 31, 2016 , and December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	March 31, 2016 December 31, 2015 Carrying Value Fair Value Carrying Value Fair Value (in thousands) Senior secured second lien notes $ 1,000,000 $ 140,000 $ 1,000,000 $ 501,250 Senior notes, net 3,814,810 501,073 3,812,676 662,179

Derivatives (Tables)

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following table presents derivative positions for the periods indicated as of March 31, 2016 : April 1 - December 31, 2016 2017 2018 Natural gas positions: Fixed price swaps (NYMEX Henry Hub): Hedged volume (MMMBtu) 91,548 120,122 36,500 Average price ($/MMBtu) $ 4.20 $ 4.26 $ 5.00 Put options (NYMEX Henry Hub): Hedged volume (MMMBtu) 57,306 66,886 — Average price ($/MMBtu) $ 5.00 $ 4.88 $ — Oil positions: Fixed price swaps (NYMEX WTI): (1) Hedged volume (MBbls) 8,614 4,755 — Average price ($/Bbl) $ 90.56 $ 89.02 $ — Put options (NYMEX WTI): Hedged volume (MBbls) 2,457 384 — Average price ($/Bbl) $ 90.00 $ 90.00 $ — Natural gas basis differential positions: (2) Panhandle basis swaps: (3) Hedged volume (MMMBtu) 45,049 59,138 16,425 Hedged differential ($/MMBtu) $ (0.32 ) $ (0.33 ) $ (0.33 ) April 1 - December 31, 2016 2017 2018 NWPL Rockies basis swaps: (3) Hedged volume (MMMBtu) 50,143 38,880 10,804 Hedged differential ($/MMBtu) $ (0.24 ) $ (0.19 ) $ (0.19 ) MichCon basis swaps: (3) Hedged volume (MMMBtu) 5,830 7,437 2,044 Hedged differential ($/MMBtu) $ 0.05 $ 0.05 $ 0.05 Houston Ship Channel basis swaps: (3) Hedged volume (MMMBtu) 26,128 36,730 986 Hedged differential ($/MMBtu) $ (0.02 ) $ (0.02 ) $ (0.08 ) Permian basis swaps: (3) Hedged volume (MMMBtu) 2,274 2,629 1,314 Hedged differential ($/MMBtu) $ (0.20 ) $ (0.20 ) $ (0.20 ) SoCal basis swaps: (4) Hedged volume (MMMBtu) 24,750 — — Hedged differential ($/MMBtu) $ (0.03 ) $ — $ — Oil timing differential positions: Trade month roll swaps (NYMEX WTI): (5) Hedged volume (MBbls) 1,992 2,654 — Hedged differential ($/Bbl) $ 0.25 $ 0.25 $ — (1) Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for the year ending December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, at counterparty election on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other year. (2) Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price. (3) For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis. (4) For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis. (5) The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).
Fair Value of Derivatives Outstanding on a Gross Basis by Location on the Balance Sheet	The following summarizes the fair value of derivatives outstanding on a gross basis: March 31, 2016 December 31, 2015 (in thousands) Assets: Commodity derivatives $ 1,569,054 $ 1,812,375 Liabilities: Commodity derivatives $ 22,651 $ 28,842
Derivative Instruments, Gain (Loss)	A summary of gains and losses on derivatives included on the condensed consolidated statements of operations is presented below: Three Months Ended 2016 2015 (in thousands) Gains on oil and natural gas derivatives $ 109,961 $ 424,781 Lease operating expenses (1) (3,368 ) (926 ) Total gains on oil and natural gas derivatives $ 106,593 $ 423,855 (1) Consists of gains and (losses) on derivatives entered into in March 2015 to hedge exposure to differentials in consuming areas.

Fair Value Measurements on a 27

Fair Value Measurements on a Recurring Basis (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements, Recurring Basis	The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis: March 31, 2016 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 1,569,054 $ (20,987 ) $ 1,548,067 Liabilities: Commodity derivatives $ 22,651 $ (20,987 ) $ 1,664 December 31, 2015 Level 2 Netting (1) Total (in thousands) Assets: Commodity derivatives $ 1,812,375 $ (25,744 ) $ 1,786,631 Liabilities: Commodity derivatives $ 28,842 $ (25,744 ) $ 3,098 (1) Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations Reconciliation	The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations at December 31, 2015 $ 523,541 Liabilities added from drilling 307 Current year accretion expense 7,641 Settlements (2,756 ) Asset retirement obligations at March 31, 2016 $ 528,733

Earnings Per Unit (Tables)

Earnings Per Unit (Tables)	3 Months Ended
	Mar. 31, 2016
Earnings Per Share [Abstract]
Reconciliation of numerators and denominators of the basic and diluted per unit computations for net income (loss)	The following table provides a reconciliation of the numerators and denominators of the basic and diluted per unit computations for net loss: Three Months Ended March 31, 2016 2015 (in thousands, except per unit data) Net loss $ (1,347,746 ) $ (339,160 ) Allocated to participating securities — (1,781 ) $ (1,347,746 ) $ (340,941 ) Basic net loss per unit $ (3.83 ) $ (1.03 ) Diluted net loss per unit $ (3.83 ) $ (1.03 ) Basic weighted average units outstanding 352,234 330,642 Dilutive effect of unit equivalents — — Diluted weighted average units outstanding 352,234 330,642

Supplemental Disclosures to t30

Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows (Tables)	3 Months Ended
	Mar. 31, 2016
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows [Abstract]
Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows [Table Text Block]	Supplemental disclosures to the condensed consolidated statements of cash flows are presented below: Three Months Ended 2016 2015 (in thousands) Cash payments for interest, net of amounts capitalized $ 30,135 $ 98,541 Cash payments for income taxes $ 1,228 $ 57 Noncash investing activities: Accrued capital expenditures $ 31,348 $ 161,247

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	3 Months Ended
	Mar. 31, 2016
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEETS March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) ASSETS Current assets: Cash and cash equivalents $ 917,814 $ 134,408 $ 7,334 $ — $ 1,059,556 Accounts receivable – trade, net — 145,297 40,755 — 186,052 Accounts receivable – affiliates 2,885,185 50,518 — (2,935,703 ) — Derivative instruments — 1,095,929 295 — 1,096,224 Other current assets 23,159 59,170 19,582 — 101,911 Total current assets 3,826,158 1,485,322 67,966 (2,935,703 ) 2,443,743 Noncurrent assets: Oil and natural gas properties (successful efforts method) — 13,129,776 5,019,579 — 18,149,355 Less accumulated depletion and amortization — (9,776,724 ) (2,682,011 ) 65,173 (12,393,562 ) — 3,353,052 2,337,568 65,173 5,755,793 Other property and equipment — 600,783 113,947 — 714,730 Less accumulated depreciation — (194,874 ) (14,617 ) — (209,491 ) — 405,909 99,330 — 505,239 Derivative instruments — 451,843 — — 451,843 Restricted cash — 7,208 250,612 — 257,820 Notes receivable – affiliates 162,700 — — (162,700 ) — Investments in consolidated subsidiaries 2,675,208 — — (2,675,208 ) — Other noncurrent assets — 8,223 16,836 — 25,059 2,837,908 467,274 267,448 (2,837,908 ) 734,722 Total noncurrent assets 2,837,908 4,226,235 2,704,346 (2,772,735 ) 6,995,754 Total assets $ 6,664,066 $ 5,711,557 $ 2,772,312 $ (5,708,438 ) $ 9,439,497 LIABILITIES AND UNITHOLDERS’ CAPITAL (DEFICIT) Current liabilities: Accounts payable and accrued expenses $ — $ 269,911 $ 98,163 $ — $ 368,074 Accounts payable – affiliates — 2,885,185 50,518 (2,935,703 ) — Derivative instruments — — 1,190 — 1,190 Current portion of long-term debt, net 3,720,157 — 873,175 — 4,593,332 Other accrued liabilities 107,536 32,985 29,996 — 170,517 Total current liabilities 3,827,693 3,188,081 1,053,042 (2,935,703 ) 5,133,113 Noncurrent liabilities: Derivative instruments — 474 — — 474 Long-term debt, net 4,449,883 — 844,927 — 5,294,810 Notes payable – affiliates — 162,700 — (162,700 ) — Other noncurrent liabilities — 402,515 213,003 — 615,518 Total noncurrent liabilities 4,449,883 565,689 1,057,930 (162,700 ) 5,910,802 Unitholders’ capital (deficit): Units issued and outstanding 5,346,253 4,831,568 2,798,713 (7,621,189 ) 5,355,345 Accumulated deficit (6,959,763 ) (2,873,781 ) (2,137,373 ) 5,011,154 (6,959,763 ) (1,613,510 ) 1,957,787 661,340 (2,610,035 ) (1,604,418 ) Total liabilities and unitholders’ capital (deficit) $ 6,664,066 $ 5,711,557 $ 2,772,312 $ (5,708,438 ) $ 9,439,497 CONDENSED CONSOLIDATING BALANCE SHEETS December 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) ASSETS Current assets: Cash and cash equivalents $ 1,073 $ 72 $ 1,023 $ — $ 2,168 Accounts receivable – trade, net — 170,503 46,053 — 216,556 Accounts receivable – affiliates 2,920,082 8,621 — (2,928,703 ) — Derivative instruments — 1,207,012 13,218 — 1,220,230 Other current assets 25,090 49,606 20,897 — 95,593 Total current assets 2,946,245 1,435,814 81,191 (2,928,703 ) 1,534,547 Noncurrent assets: Oil and natural gas properties (successful efforts method) — 13,110,094 5,011,061 — 18,121,155 Less accumulated depletion and amortization — (9,557,283 ) (1,596,165 ) 55,956 (11,097,492 ) — 3,552,811 3,414,896 55,956 7,023,663 Other property and equipment — 597,216 111,495 — 708,711 Less accumulated depreciation — (183,139 ) (12,522 ) — (195,661 ) — 414,077 98,973 — 513,050 Derivative instruments — 566,401 — — 566,401 Restricted cash — 7,004 250,359 — 257,363 Notes receivable – affiliates 175,100 — — (175,100 ) — Investments in consolidated subsidiaries 3,940,444 — — (3,940,444 ) — Other noncurrent assets — 17,178 16,057 (1 ) 33,234 4,115,544 590,583 266,416 (4,115,545 ) 856,998 Total noncurrent assets 4,115,544 4,557,471 3,780,285 (4,059,589 ) 8,393,711 Total assets $ 7,061,789 $ 5,993,285 $ 3,861,476 $ (6,988,292 ) $ 9,928,258 LIABILITIES AND UNITHOLDERS’ CAPITAL (DEFICIT) Current liabilities: Accounts payable and accrued expenses $ 1,285 $ 336,962 $ 117,127 $ — $ 455,374 Accounts payable – affiliates — 2,920,082 8,621 (2,928,703 ) — Derivative instruments — — 2,241 — 2,241 Current portion of long-term debt, net 2,841,518 — 873,175 — 3,714,693 Other accrued liabilities 49,861 52,997 16,735 — 119,593 Total current liabilities 2,892,664 3,310,041 1,017,899 (2,928,703 ) 4,291,901 Noncurrent liabilities: Derivative instruments — 857 — — 857 Long-term debt, net 4,447,308 — 845,368 — 5,292,676 Notes payable – affiliates — 175,100 — (175,100 ) — Other noncurrent liabilities — 399,676 212,050 (1 ) 611,725 Total noncurrent liabilities 4,447,308 575,633 1,057,418 (175,101 ) 5,905,258 Unitholders’ capital (deficit): Units issued and outstanding 5,333,834 4,831,758 2,798,713 (7,621,189 ) 5,343,116 Accumulated deficit (5,612,017 ) (2,724,147 ) (1,012,554 ) 3,736,701 (5,612,017 ) (278,183 ) 2,107,611 1,786,159 (3,884,488 ) (268,901 ) Total liabilities and unitholders’ capital (deficit) $ 7,061,789 $ 5,993,285 $ 3,861,476 $ (6,988,292 ) $ 9,928,258
Condensed Consolidating Statements of Operations	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Revenues and other: Oil, natural gas and natural gas liquids sales $ — $ 199,849 $ 83,466 $ — $ 283,315 Gains on oil and natural gas derivatives — 109,453 508 — 109,961 Marketing revenues — 9,061 5,244 — 14,305 Other revenues — 5,138 2,048 — 7,186 — 323,501 91,266 — 414,767 Expenses: Lease operating expenses — 87,552 50,093 — 137,645 Transportation expenses — 41,994 12,929 — 54,923 Marketing expenses — 7,833 4,455 — 12,288 General and administrative expenses — 61,357 25,172 — 86,529 Exploration costs — 2,693 — — 2,693 Depreciation, depletion and amortization — 108,045 58,843 (2,830 ) 164,058 Impairment of long-lived assets — 129,703 1,030,588 (6,387 ) 1,153,904 Taxes, other than income taxes 2 19,752 14,313 — 34,067 (Gains) losses on sale of assets and other, net — 1,269 (192 ) — 1,077 2 460,198 1,196,201 (9,217 ) 1,647,184 Other income and (expenses): Interest expense, net of amounts capitalized (85,472 ) 205 (19,952 ) — (105,219 ) Interest expense – affiliates — (2,969 ) — 2,969 — Interest income – affiliates 2,969 — — (2,969 ) — Equity in losses from consolidated subsidiaries (1,265,236 ) — — 1,265,236 — Other, net (5 ) 73 66 — 134 (1,347,744 ) (2,691 ) (19,886 ) 1,265,236 (105,085 ) Loss before income taxes (1,347,746 ) (139,388 ) (1,124,821 ) 1,274,453 (1,337,502 ) Income tax expense (benefit) — 10,246 (2 ) — 10,244 Net loss $ (1,347,746 ) $ (149,634 ) $ (1,124,819 ) $ 1,274,453 $ (1,347,746 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended March 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Revenues and other: Oil, natural gas and natural gas liquids sales $ — $ 293,983 $ 156,586 $ — $ 450,569 Gains on oil and natural gas derivatives — 421,514 3,267 — 424,781 Marketing revenues — 26,212 7,532 — 33,744 Other revenues — 5,557 1,896 — 7,453 — 747,266 169,281 — 916,547 Expenses: Lease operating expenses — 105,832 67,189 — 173,021 Transportation expenses — 40,934 12,606 — 53,540 Marketing expenses — 23,196 5,645 — 28,841 General and administrative expenses — 57,781 21,187 — 78,968 Exploration costs — 396 — — 396 Depreciation, depletion and amortization — 140,699 72,979 1,336 215,014 Impairment of long-lived assets — 325,417 272,000 (64,800 ) 532,617 Taxes, other than income taxes 2 30,711 23,332 — 54,045 Gains on sale of assets and other, net — (7,814 ) (4,473 ) — (12,287 ) 2 717,152 470,465 (63,464 ) 1,124,155 Other income and (expenses): Interest expense, net of amounts capitalized (123,386 ) 1,706 (21,421 ) — (143,101 ) Interest expense – affiliates — (2,382 ) — 2,382 — Interest income – affiliates 2,382 — — (2,382 ) — Gain on extinguishment of debt 6,635 — — — 6,635 Equity in losses from consolidated subsidiaries (222,811 ) — — 222,811 — Other, net (1,978 ) (65 ) (170 ) — (2,213 ) (339,158 ) (741 ) (21,591 ) 222,811 (138,679 ) Income (loss) before income taxes (339,160 ) 29,373 (322,775 ) 286,275 (346,287 ) Income tax benefit — (7,077 ) (50 ) — (7,127 ) Net income (loss) $ (339,160 ) $ 36,450 $ (322,725 ) $ 286,275 $ (339,160 )
Condensed Consolidating Statements of Cash Flows	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS For the Three Months Ended March 31, 2016 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from operating activities: Net loss $ (1,347,746 ) $ (149,634 ) $ (1,124,819 ) $ 1,274,453 $ (1,347,746 ) Adjustments to reconcile net loss to net cash provided by operating activities: Depreciation, depletion and amortization — 108,045 58,843 (2,830 ) 164,058 Impairment of long-lived assets — 129,703 1,030,588 (6,387 ) 1,153,904 Unit-based compensation expenses — 12,425 — — 12,425 Amortization and write-off of deferred financing fees 4,676 — 182 — 4,858 (Gains) losses on sale of assets and other, net — 2,226 (310 ) — 1,916 Equity in losses from consolidated subsidiaries 1,265,236 — — (1,265,236 ) — Deferred income taxes — 9,422 (2 ) — 9,420 Derivatives activities: Total (gains) losses — (109,454 ) 2,861 — (106,593 ) Cash settlements — 334,712 9,011 — 343,723 Changes in assets and liabilities: Decrease in accounts receivable – trade, net — 25,815 5,298 — 31,113 (Increase) decrease in accounts receivable – affiliates 49,034 (41,897 ) — (7,137 ) — Increase in other assets — (8,225 ) (64 ) — (8,289 ) Decrease in accounts payable and accrued expenses (36 ) (594 ) (13,897 ) — (14,527 ) Increase (decrease) in accounts payable and accrued expenses – affiliates — (49,034 ) 41,897 7,137 — Increase (decrease) in other liabilities 56,876 (21,163 ) 11,053 — 46,766 Net cash provided by operating activities 28,040 242,347 20,641 — 291,028 Cash flow from investing activities: Development of oil and natural gas properties — (70,407 ) (11,019 ) — (81,426 ) Purchases of other property and equipment — (6,404 ) (3,327 ) — (9,731 ) Change in notes receivable with affiliate 12,400 — — (12,400 ) — Proceeds from sale of properties and equipment and other (918 ) 638 16 — (264 ) Net cash provided by (used in) investing activities 11,482 (76,173 ) (14,330 ) (12,400 ) (91,421 ) Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from financing activities: Proceeds from borrowings 978,500 — — — 978,500 Repayments of debt (100,000 ) — — — (100,000 ) Financing fees and offering costs (32 ) — — — (32 ) Change in notes payable with affiliate — (12,400 ) — 12,400 — Other (1,249 ) (19,438 ) — — (20,687 ) Net cash provided by (used in) financing activities 877,219 (31,838 ) — 12,400 857,781 Net increase in cash and cash equivalents 916,741 134,336 6,311 — 1,057,388 Cash and cash equivalents: Beginning 1,073 72 1,023 — 2,168 Ending $ 917,814 $ 134,408 $ 7,334 $ — $ 1,059,556 CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS For the Three Months Ended March 31, 2015 Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from operating activities: Net income (loss) $ (339,160 ) $ 36,450 $ (322,725 ) $ 286,275 $ (339,160 ) Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: Depreciation, depletion and amortization — 140,699 72,979 1,336 215,014 Impairment of long-lived assets — 325,417 272,000 (64,800 ) 532,617 Unit-based compensation expenses — 20,510 — — 20,510 Gain on extinguishment of debt (6,635 ) — — — (6,635 ) Amortization and write-off of deferred financing fees 6,453 — 259 — 6,712 Gains on sale of assets and other, net — (5,243 ) (1,857 ) — (7,100 ) Equity in losses from consolidated subsidiaries 222,811 — — (222,811 ) — Deferred income taxes — (7,108 ) (50 ) — (7,158 ) Derivatives activities: Total gains — (421,514 ) (2,341 ) — (423,855 ) Cash settlements — 254,569 27,513 — 282,082 Changes in assets and liabilities: Decrease in accounts receivable – trade, net 21,921 96,917 16,392 — 135,230 (Increase) decrease in accounts receivable – affiliates 17,082 (19,856 ) — 2,774 — Increase in other assets — (8,521 ) (3,878 ) — (12,399 ) Decrease in accounts payable and accrued expenses (290 ) (3,844 ) (25,734 ) — (29,868 ) Increase (decrease) in accounts payable and accrued expenses – affiliates — (17,082 ) 19,856 (2,774 ) — Increase (decrease) in other liabilities 42,695 (24,057 ) (9,925 ) — 8,713 Net cash provided by (used in) operating activities (35,123 ) 367,337 42,489 — 374,703 Cash flow from investing activities: Development of oil and natural gas properties — (263,209 ) (1,609 ) — (264,818 ) Purchases of other property and equipment — (11,309 ) (1,092 ) — (12,401 ) Investment in affiliates 43,778 — — (43,778 ) — Change in notes receivable with affiliate (16,400 ) — — 16,400 — Proceeds from sale of properties and equipment and other (1,121 ) 24,808 3,813 — 27,500 Net cash provided by (used in) investing activities 26,257 (249,710 ) 1,112 (27,378 ) (249,719 ) Linn Energy, LLC Guarantor Subsidiaries Non- Guarantor Subsidiary Eliminations Consolidated (in thousands) Cash flow from financing activities: Proceeds from sale of units 15,900 — — — 15,900 Proceeds from borrowings 395,000 — — — 395,000 Repayments of debt (280,287 ) — — — (280,287 ) Distributions to unitholders (104,815 ) — — — (104,815 ) Financing fees and offering costs (453 ) — — — (453 ) Change in notes payable with affiliate — 16,400 — (16,400 ) — Distribution to affiliate — — (43,778 ) 43,778 — Excess tax benefit from unit-based compensation (8,867 ) — — — (8,867 ) Other (3,786 ) (91,188 ) 15 — (94,959 ) Net cash provided by (used in) financing activities 12,692 (74,788 ) (43,763 ) 27,378 (78,481 ) Net increase (decrease) in cash and cash equivalents 3,826 42,839 (162 ) — 46,503 Cash and cash equivalents: Beginning 38 185 1,586 — 1,809 Ending $ 3,864 $ 43,024 $ 1,424 $ — $ 48,312

Basis of Presentation Details (

Basis of Presentation Details (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Deferred Tax Assets, Net, Current		$ 22,000
Deferred Tax Liabilities, Net, Noncurrent		11,000
Deferred Tax Assets, Net		11,000
Senior Notes [Member]
Debt Instrument [Line Items]
Deferred Finance Costs, Net	$ 35,477	$ 37,374

Chapter 11 Proceedings, Liqui33

Chapter 11 Proceedings, Liquidity and Ability to Continue as a Going Concern (Details) - USD ($) $ in Thousands	May. 10, 2016	Apr. 30, 2016	May. 31, 2016	Mar. 31, 2016	Mar. 31, 2015	May. 01, 2016	Apr. 15, 2016	Mar. 15, 2016
Debt Instrument [Line Items]
Repayments of Long-term Debt				$ 100,000	$ 280,287
Required issuance of additional debt				1,000,000
Senior Notes [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt				$ 70,000
Deferred interest payment								$ 60,000
Linn Energy, LLC [Member] | Senior Secured Notes [Member] | Senior Secured Second Lien Notes Due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				12.00%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due February 2021
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				7.75%
Deferred interest payment								30,000
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due September 2021
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				6.50%
Deferred interest payment								12,000
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due April 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				8.625%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				6.25%
Berry [Member] | Senior Notes [Member] | Senior Notes Due September 2022
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				6.375%
Deferred interest payment								$ 18,000
Berry [Member] | Senior Notes [Member] | Senior Notes Due November 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				6.75%
Subsequent Event [Member]
Debt Instrument [Line Items]
Increase (Decrease) in Restricted Cash		$ (45,000)
Subsequent Event [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Holders required for agreement	66.67%
Subsequent Event [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Interest Paid		60,000
Subsequent Event [Member] | Linn Energy, LLC [Member] | Line of Credit
Debt Instrument [Line Items]
Repayments of Long-term Debt	$ 350,000	$ 100,000	$ 1,200,000
Subsequent Event [Member] | Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due April 2020
Debt Instrument [Line Items]
Deferred interest payment							$ 31,000
Subsequent Event [Member] | Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019
Debt Instrument [Line Items]
Deferred interest payment						$ 18,000
Subsequent Event [Member] | Berry [Member] | Senior Notes [Member] | Senior Notes Due November 2020
Debt Instrument [Line Items]
Deferred interest payment						$ 9,000

Unitholders' Deficit Equity Off

Unitholders' Deficit Equity Offering (Details) - At-the-Market Offering Program [Member]	3 Months Ended
	Mar. 31, 2016USD ($)$ / sharesshares
Schedule of Equity Offerings [Line Items]
Equity Offering Program Remaining Balance	$ 455,000,000
Stock issued during period, sales price per unit | $ / shares	$ 11.97
Sale of units, net of offering costs	$ 16,000,000
Investment Banking, Advisory, Brokerage, and Underwriting Fees and Commissions	159,000
Professional Fees	$ 435,000
Sale of units (in units) | shares	1,328,192
Equity Offering Program Maximum Value	$ 500,000,000

Oil and Natural Gas Propertie35

Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Proved properties:
Leasehold acquisition	$ 13,372,330		$ 13,361,171
Development	3,003,402		2,976,643
Unproved properties	1,773,623		1,783,341
Oil and natural gas properties (successful efforts method)	18,149,355		18,121,155
Less accumulated depletion and amortization	(12,393,562)		(11,097,492)
Oil and natural gas properties, successful efforts method, net	5,755,793		$ 7,023,663
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	1,140,668	$ 532,617
Impairment Of Unproved Oil And Gas Properties		0
California region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	984,288	207,200
Impairment Of Unproved Oil And Gas Properties	13,000
Mid-Continent region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	129,703	5,703
Rockies region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	26,677	0
Hugoton Basin region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	0	277,914
TexLa region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	0	33,100
South Texas region
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of proved oil and gas properties	$ 0	$ 8,700

Unit-Based Compensation (Detail

Unit-Based Compensation (Details) - Performance Shares [Member]	3 Months Ended
	Mar. 31, 2016USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted to employees	567,320
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	0
Deferred Compensation Share-based Arrangements, Liability, Classified, Noncurrent | $	$ 0

Unit-Based Compensation (Compen

Unit-Based Compensation (Compensation Expenses) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	$ 12,425	$ 20,510
Income tax benefit	4,591	7,579
General and administrative expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	9,460	16,633
Lease operating expenses
Employee Service Share-based Compensation, Allocation of Recognized Period Costs
Unit-based compensation expense	$ 2,965	$ 3,877

Debt (Details)

Debt (Details)	May. 10, 2016USD ($)	Apr. 30, 2016USD ($)	Nov. 30, 2015USD ($)	May. 31, 2016USD ($)	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)	Apr. 30, 2012USD ($)
Debt Instrument [Line Items]
Gain on extinguishment of debt					$ 0	$ 6,635,000
Extinguishment of debt					79,000,000
Repayments of Long-term Debt					$ 100,000,000	280,287,000
Percent of future net income allowable to increase Berry's restricted payments basket					50.00%
Senior Notes Exchanged			$ 2,000,000,000
Cash payments for interest, net of amounts capitalized					$ 30,135,000	$ 98,541,000
Senior Notes [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt					$ 70,000,000
Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End					5.25%		3.17%
Line of Credit Facility, Current Borrowing Capacity					$ 900,000,000
Line of Credit Facility, Maximum Borrowing Capacity					900,000,000
Line of Credit Facility, Remaining Borrowing Capacity					$ 1,000,000
The percentage of properties that the company is required to maintain mortgages on (in hundredths)					90.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage					0.50%
Berry [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					1.75%
Berry [Member] | Line of Credit | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					2.75%
Berry [Member] | Line of Credit | Credit Facility | ABR | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					0.75%
Berry [Member] | Line of Credit | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					1.75%
Berry [Member] | Senior Notes [Member] | Senior Notes Due November 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.75%
Berry [Member] | Senior Notes [Member] | Senior Notes Due September 2022
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.375%
Linn Energy, LLC [Member] | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					1.75%
Linn Energy, LLC [Member] | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					2.75%
Linn Energy, LLC [Member] | Credit Facility | ABR | Minimum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					0.75%
Linn Energy, LLC [Member] | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					1.75%
Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End					3.18%		2.66%
Line of Credit Facility, Current Borrowing Capacity					$ 3,100,000,000			$ 4,000,000,000
Line of Credit Facility, Maximum Borrowing Capacity					3,600,000,000
Line of Credit Facility, Remaining Borrowing Capacity					0
Minimum liquidity					$ 500,000,000
Minimum liquidity as a percentage of borrowing base					15.00%
The percentage of properties that the company is required to maintain mortgages on (in hundredths)					90.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage					0.50%
Linn Energy, LLC [Member] | Senior Secured Notes [Member] | Senior Secured Second Lien Notes Due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount					$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage					12.00%
Cash payments for interest, net of amounts capitalized					$ 0
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due April 2020
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					8.625%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due February 2021
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					7.75%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due September 2021
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.25%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due May 2019
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					6.50%
Linn Energy, LLC [Member] | Loans Payable [Member]
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End					3.18%		3.17%
Term loan					$ 500,000,000
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility
Debt Instrument [Line Items]
The percentage of properties that the company is required to maintain mortgages on (in hundredths)					80.00%
Line Of Credit Facility Collateral Coverage Ratio | Pure					2.5
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility | London Interbank Offered Rate (LIBOR) [Member] | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					2.75%
Linn Energy, LLC [Member] | Loans Payable [Member] | Credit Facility | ABR | Maximum
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					1.75%
Linn Energy, LLC [Member] | Secured Debt [Member] | Senior Secured Second Lien Notes Due 2020 [Member]
Debt Instrument [Line Items]
Interest Payments on Troubled Debt, Current					$ 128,000,000		$ 128,000,000
Subsequent Event [Member]
Debt Instrument [Line Items]
Increase (Decrease) in Restricted Cash		$ (45,000,000)
Subsequent Event [Member] | Linn Energy, LLC [Member] | Line of Credit
Debt Instrument [Line Items]
Repayments of Long-term Debt	$ 350,000,000	$ 100,000,000		$ 1,200,000,000
March 31, 2017 and June 30, 2017 [Member] | Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2.25
March 31, 2017 and June 30, 2017 [Member] | Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2.25
Subsequent to June 30, 2017 [Member] | Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2.5
Subsequent to June 30, 2017 [Member] | Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2.5
December 31, 2015 through December 31, 2016 [Member] | Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2
December 31, 2015 through December 31, 2016 [Member] | Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Line Of Credit Facility Collateral Coverage Ratio					2

Debt Schedule of Long Term Debt

Debt Schedule of Long Term Debt (Details) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Senior notes, net		$ 3,814,810	$ 3,812,676
Senior secured second lien notes		1,000,000	1,000,000
Total debt, net		9,888,142	9,007,369
Less current portion, net	[1]	(4,593,332)	(3,714,693)
Long-term debt, net		5,294,810	5,292,676
Senior Notes [Member]
Debt Instrument [Line Items]
Net unamortized discounts and premiums		(8,318)	(8,694)
Net unamortized deferred financing fees		(35,477)	(37,374)
Linn Energy, LLC [Member] | Line of Credit
Debt Instrument [Line Items]
Credit facilities	[2]	$ 3,093,500	$ 2,215,000
Linn Energy, LLC [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End		3.18%	2.66%
Linn Energy, LLC [Member] | Loans Payable [Member]
Debt Instrument [Line Items]
Term Loan	[3]	$ 500,000	$ 500,000
Debt Instrument Interest Rate Period End		3.18%	3.17%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due May 2019
Debt Instrument [Line Items]
Senior notes, net		$ 562,234	$ 562,234
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due November 2019
Debt Instrument [Line Items]
Senior notes, net		$ 581,402	581,402
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Senior notes, net		$ 718,596	718,596
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due September 2021
Debt Instrument [Line Items]
Senior notes, net		$ 381,423	381,423
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Linn Energy, LLC [Member] | Senior Notes [Member] | Senior Notes Due 2021 [Member]
Debt Instrument [Line Items]
Senior notes, net		$ 779,474	779,474
Linn Energy, LLC [Member] | Senior Secured Notes [Member] | Senior Secured Second Lien Notes Due 2020 [Member]
Debt Instrument [Line Items]
Senior secured second lien notes	[4]	$ 1,000,000	1,000,000
Debt Instrument, Interest Rate, Stated Percentage		12.00%
Linn Energy, LLC [Member] | Secured Debt [Member] | Senior Secured Second Lien Notes Due 2020 [Member]
Debt Instrument [Line Items]
Interest payable on senior secured second lien notes due December 2020 (4)	[4]	$ 608,333	608,333
Interest Payments on Troubled Debt, Current		128,000	128,000
Berry [Member] | Line of Credit
Debt Instrument [Line Items]
Credit facilities	[5]	$ 873,175	$ 873,175
Berry [Member] | Line of Credit | Credit Facility
Debt Instrument [Line Items]
Debt Instrument Interest Rate Period End		5.25%	3.17%
Berry [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Senior notes, net		$ 261,100	$ 261,100
Berry [Member] | Senior Notes [Member] | Senior Notes Due September 2022
Debt Instrument [Line Items]
Senior notes, net		$ 572,700	$ 572,700
Debt Instrument, Interest Rate, Stated Percentage		6.375%
[1]	Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at March 31, 2016, and December 31, 2015. The current portion as of both March 31, 2016, and December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.
[2]	Variable interest rates of 3.18% and 2.66% at March 31, 2016, and December 31, 2015, respectively.
[3]	Variable interest rates of 3.18% and 3.17% at March 31, 2016, and December 31, 2015, respectively.
[4]	The issuance of the Second Lien Notes was accounted for as a troubled debt restructuring, which requires that interest payments on the Second Lien Notes reduce the carrying value of the debt with no interest expense recognized.
[5]	Variable interest rates of 5.25% and 3.17% at March 31, 2016, and December 31, 2015, respectively.

Debt Debt Fair Value Disclosure

Debt Debt Fair Value Disclosure (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Carrying Value
Senior secured second lien notes	$ 1,000,000	$ 1,000,000
Senior notes, net	3,814,810	3,812,676
Fair Value
Senior secured second lien notes	140,000	501,250
Senior notes, net	$ 501,073	$ 662,179

Derivatives (Commodity Derivati

Derivatives (Commodity Derivatives) (Details)	Mar. 31, 2016$ / MMBTU$ / bblMBblsMMMBTU
2015 | Natural Gas Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	91,548
Average Price (in usd per energy unit) | $ / MMBTU	4.20
2015 | Natural Gas Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	57,306
Average Price (in usd per energy unit) | $ / MMBTU	5
2015 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	8,614	[1]
Average Price (in usd per energy unit) | $ / bbl	90.56	[1]
2015 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	2,457
Average Price (in usd per energy unit) | $ / bbl	90
2015 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	45,049	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.32)	[2],[3]
2015 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	50,143	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.24)	[2],[3]
2015 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	5,830	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	0.05	[2],[3]
2015 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	26,128	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.02)	[2],[3]
2015 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	2,274	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.20)	[2],[3]
2015 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	24,750	[3],[4]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.03)	[3],[4]
2015 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	1,992	[5]
Hedged Differential (in usd per energy unit) | $ / bbl	0.25	[5]
2016 | Natural Gas Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	120,122
Average Price (in usd per energy unit) | $ / MMBTU	4.26
2016 | Natural Gas Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	66,886
Average Price (in usd per energy unit) | $ / MMBTU	4.88
2016 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	4,755	[1]
Average Price (in usd per energy unit) | $ / bbl	89.02	[1]
2016 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	384
Average Price (in usd per energy unit) | $ / bbl	90
2016 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	59,138	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.33)	[2],[3]
2016 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	38,880	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.19)	[2],[3]
2016 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	7,437	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	0.05	[2],[3]
2016 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	36,730	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.02)	[2],[3]
2016 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	2,629	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.20)	[2],[3]
2016 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[3],[4]
Hedged Differential (in usd per energy unit) | $ / MMBTU	0	[3],[4]
2016 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	2,654	[5]
Hedged Differential (in usd per energy unit) | $ / bbl	0.25	[5]
2017 | Natural Gas Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	36,500
Average Price (in usd per energy unit) | $ / MMBTU	5
2017 | Natural Gas Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit)	0
Average Price (in usd per energy unit) | $ / MMBTU	0
2017 | Oil Derivative Instruments | Fixed price swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	0	[1]
Average Price (in usd per energy unit) | $ / bbl	0	[1]
2017 | Oil Derivative Instruments | Puts
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	0
Average Price (in usd per energy unit) | $ / bbl	0
2017 | Oil Derivative Instruments | Extendible Fixed Price Swaps
Derivative [Line Items]
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls) | MBbls	5,384
2017 | Natural Gas Basis Differential Positions | Panhandle Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	16,425	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.33)	[2],[3]
2017 | Natural Gas Basis Differential Positions | NWPL - Rockies basis swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	10,804	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.19)	[2],[3]
2017 | Natural Gas Basis Differential Positions | MichCon Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	2,044	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	0.05	[2],[3]
2017 | Natural Gas Basis Differential Positions | Houston Ship Channel Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	986	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.08)	[2],[3]
2017 | Natural Gas Basis Differential Positions | Permian Basis Swaps
Derivative [Line Items]
Hedged Volume (in energy unit)	1,314	[2],[3]
Hedged Differential (in usd per energy unit) | $ / MMBTU	(0.20)	[2],[3]
2017 | Natural Gas Basis Differential Positions | SoCal basis swaps [Member]
Derivative [Line Items]
Hedged Volume (in energy unit)	0	[3],[4]
Hedged Differential (in usd per energy unit) | $ / MMBTU	0	[3],[4]
2017 | Oil Timing Differential Positions | Trade month roll swaps
Derivative [Line Items]
Hedged Volume (in energy unit) | MBbls	0	[5]
Hedged Differential (in usd per energy unit) | $ / bbl	0	[5]
2018 | Oil Derivative Instruments | Extendible Fixed Price Swaps
Derivative [Line Items]
Average Price (in usd per energy unit) | $ / bbl	100
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls) | MBbls	5,384
2019 | Oil Derivative Instruments | Extendible Fixed Price Swaps
Derivative [Line Items]
Average Price (in usd per energy unit) | $ / bbl	90
Amount of outstanding extendible fixed price oil swaps of daily production (in MBbls) | MBbls	5,384
Berry [Member] | Natural Gas Basis Differential Positions
Derivative [Line Items]
Hedged Volume (in energy unit)	26,108
[1]	Includes certain outstanding fixed price oil swaps of approximately 5,384 MBbls which may be extended annually at a price of $100.00 per Bbl for the year ending December 31, 2018, and $90.00 per Bbl for the year ending December 31, 2019, at counterparty election on a designated date in each respective preceding year. The extension for each year is exercisable without respect to the other year.
[2]	For positions which hedge exposure to differentials in producing areas, the Company receives the NYMEX Henry Hub natural gas price plus the respective spread and pays the specified index price. Cash settlements are made on a net basis.
[3]	Settle on the respective pricing index to hedge basis differential to the NYMEX Henry Hub natural gas price.
[4]	For positions which hedge exposure to differentials in consuming areas, the Company pays the NYMEX Henry Hub natural gas price plus the respective spread and receives the specified index price. Cash settlements are made on a net basis.
[5]	The Company hedges the timing risk associated with the sales price of oil in the Mid-Continent, Hugoton Basin and Permian Basin regions. In these regions, the Company generally sells oil for the delivery month at a sales price based on the average NYMEX WTI price during that month, plus an adjustment calculated as a spread between the weighted average prices of the delivery month, the next month and the following month during the period when the delivery month is prompt (the “trade month roll”).

Derivatives (Balance Sheet Pres

Derivatives (Balance Sheet Presentation) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 1,600,000
Assets:
Commodity derivatives	1,569,054	$ 1,812,375
Liabilities:
Commodity derivatives	$ 22,651	$ 28,842

Derivatives (Gains (Losses) On

Derivatives (Gains (Losses) On Derivatives) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)$ / MMBTU$ / bblMBblsMMMBTU	Mar. 31, 2015USD ($)$ / MMBTU$ / bblMBblsMMMBTU
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Volume Of Natural Gas Production On Settled Derivatives | MMMBTU	49,257	46,823
Average Contract Price On Natural Gas Settled Derivatives Per Unit | $ / MMBTU	4.51	5.12
Volume Of Oil On Settled Derivatives | MBbls	3,664	3,975
Average Contract Price On Oil Settled Derivatives Per Unit | $ / bbl	90.44	94.29
Cash settlements | $	$ 343,723	$ 282,082

Derivatives (Income Statement P

Derivatives (Income Statement Presentation) (Details) - USD ($) $ in Thousands		May. 10, 2016	Apr. 30, 2016	May. 31, 2016	Mar. 31, 2016	Mar. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Repayments of Long-term Debt					$ 100,000	$ 280,287
Gains (losses) on oil and natural gas derivatives					106,593	423,855
Gains on oil and natural gas derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on oil and natural gas derivatives					109,961	424,781
Lease operating expenses
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on oil and natural gas derivatives	[1]				$ (3,368)	$ (926)
Line of Credit | Subsequent Event [Member] | Linn Energy, LLC [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Repayments of Long-term Debt		$ 350,000	$ 100,000	$ 1,200,000
[1]	Consists of gains and (losses) on derivatives entered into in March 2015 to hedge exposure to differentials in consuming areas.

Fair Value Measurements on a 45

Fair Value Measurements on a Recurring Basis (Details) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Assets:
Commodity derivatives		$ 1,569,054	$ 1,812,375
Commodity derivatives	[1]	(20,987)	(25,744)
Commodity derivatives		1,548,067	1,786,631
Liabilities:
Commodity derivatives		22,651	28,842
Commodity derivatives	[1]	(20,987)	(25,744)
Commodity derivatives		$ 1,664	$ 3,098
[1]	Represents counterparty netting under agreements governing such derivatives.

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
Asset Retirement Obligation Disclosure [Abstract]
Future inflation factor used in the calculation of the asset retirement obligations	2.00%
Credit adjusted risk-free interest rate for the calculation of the asset retirement obligations	5.90%
Asset retirement obligations rollforward
Asset retirement obligations at December 31, 2015	$ 523,541
Liabilities added from drilling	307
Current year accretion expense	7,641
Settlements	(2,756)
Asset retirement obligations at March 31, 2016	$ 528,733

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Payments for Legal Settlements	$ 0	$ 0

Earnings Per Unit (Details)

Earnings Per Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Earnings Per Share [Abstract]
Net loss	$ (1,347,746)	$ (339,160)
Allocated to participating securities	0	(1,781)
Net loss available to common unitholders, basic	$ (1,347,746)	$ (340,941)
Earnings per share reconciliation
Basic loss per unit (in usd per unit)	$ (3.83)	$ (1.03)
Diluted loss per unit (in usd per unit)	$ (3.83)	$ (1.03)
Weighted average units outstanding
Basic weighted average units outstanding	352,234	330,642
Dilutive effect of unit equivalents	0	0
Diluted weighted average units outstanding	352,234	330,642
Unit options and warrants
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average anti-dilutive unit equivalents excluded from computation of earnings per unit (in units)	1,000	5,000

Supplemental Disclosures to t49

Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows (Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Restricted cash	$ 257,820		$ 257,363
Net Outstanding Checks	0		21,000
Cash payments for interest, net of amounts capitalized	30,135	$ 98,541
Cash payments for income taxes	1,228	57
Noncash investing activities:
Accrued capital expenditures	31,348	$ 161,247
Restricted Cash for ARO [Member]
Debt Instrument [Line Items]
Restricted cash	7,000		$ 7,000
Restricted Cash for Debt Agreement [Member]
Debt Instrument [Line Items]
Restricted cash	$ 250,000

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Apr. 30, 2016	Mar. 31, 2016	Mar. 31, 2015
Related Party Transaction [Line Items]
General and administrative expenses		$ 86,529	$ 78,968
Distributions to unitholders		$ 0	104,815
LinnCo [Member]
Related Party Transaction [Line Items]
Ownership percentage		36.00%
General and administrative expenses		$ 1,700	1,400
General and administrative expenses paid on behalf of LinnCo		918	1,100
Related party transaction, amounts of transaction		603	491
Director [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction		2,000	$ 3,000
Dividend Paid [Member] | LinnCo [Member]
Related Party Transaction [Line Items]
Distributions to unitholders		$ 40,000
Subsequent Event [Member] | LinnCo [Member]
Related Party Transaction [Line Items]
Ownership percentage	66.00%
LinnCo [Member] | Subsequent Event [Member]
Related Party Transaction [Line Items]
Units of LINN Energy Acquired	104,719,468

Subsidiary Guarantors Details (

Subsidiary Guarantors Details (Details)	3 Months Ended
	Mar. 31, 2016
Condensed Consolidating Financial Information [Abstract]
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	100.00%

Subsidiary Guarantors Condensed

Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents		$ 1,059,556	$ 2,168	$ 48,312	$ 1,809
Accounts receivable – trade, net		186,052	216,556
Accounts receivable – affiliates		0	0
Derivative instruments		1,096,224	1,220,230
Other current assets		101,911	95,593
Total current assets		2,443,743	1,534,547
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		18,149,355	18,121,155
Less accumulated depletion and amortization		(12,393,562)	(11,097,492)
Oil and natural gas properties, successful efforts method, net		5,755,793	7,023,663
Other property and equipment		714,730	708,711
Less accumulated depreciation		(209,491)	(195,661)
Other property and equipment, net		505,239	513,050
Derivative instruments		451,843	566,401
Restricted cash		257,820	257,363
Notes receivable – affiliates		0	0
Investments in consolidated subsidiaries		0	0
Other noncurrent assets		25,059	33,234
Noncurrent assets, excluding property, total		734,722	856,998
Total noncurrent assets		6,995,754	8,393,711
Total assets		9,439,497	9,928,258
Current liabilities:
Accounts payable and accrued expenses		368,074	455,374
Accounts payable – affiliates		0	0
Derivative instruments		1,190	2,241
Current portion of long-term debt, net	[1]	4,593,332	3,714,693
Other accrued liabilities		170,517	119,593
Total current liabilities		5,133,113	4,291,901
Noncurrent liabilities:
Derivative instruments		474	857
Long-term debt, net		5,294,810	5,292,676
Notes payable – affiliates		0	0
Other noncurrent liabilities		615,518	611,725
Total noncurrent liabilities		5,910,802	5,905,258
Unitholders’ deficit:
Units issued and outstanding		5,355,345	5,343,116
Accumulated deficit		(6,959,763)	(5,612,017)
Total unitholders' deficit		(1,604,418)	(268,901)
Total liabilities and unitholders’ deficit		9,439,497	9,928,258
Reportable Legal Entities [Member] | Linn Energy, LLC
Current assets:
Cash and cash equivalents		917,814	1,073	3,864	38
Accounts receivable – trade, net		0	0
Accounts receivable – affiliates		2,885,185	2,920,082
Derivative instruments		0	0
Other current assets		23,159	25,090
Total current assets		3,826,158	2,946,245
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		0	0
Less accumulated depletion and amortization		0	0
Oil and natural gas properties, successful efforts method, net		0	0
Other property and equipment		0	0
Less accumulated depreciation		0	0
Other property and equipment, net		0	0
Derivative instruments		0	0
Restricted cash		0	0
Notes receivable – affiliates		162,700	175,100
Investments in consolidated subsidiaries		2,675,208	3,940,444
Other noncurrent assets		0	0
Noncurrent assets, excluding property, total		2,837,908	4,115,544
Total noncurrent assets		2,837,908	4,115,544
Total assets		6,664,066	7,061,789
Current liabilities:
Accounts payable and accrued expenses		0	1,285
Accounts payable – affiliates		0	0
Derivative instruments		0	0
Current portion of long-term debt, net		3,720,157	2,841,518
Other accrued liabilities		107,536	49,861
Total current liabilities		3,827,693	2,892,664
Noncurrent liabilities:
Derivative instruments		0	0
Long-term debt, net		4,449,883	4,447,308
Notes payable – affiliates		0	0
Other noncurrent liabilities		0	0
Total noncurrent liabilities		4,449,883	4,447,308
Unitholders’ deficit:
Units issued and outstanding		5,346,253	5,333,834
Accumulated deficit		(6,959,763)	(5,612,017)
Total unitholders' deficit		(1,613,510)	(278,183)
Total liabilities and unitholders’ deficit		6,664,066	7,061,789
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Current assets:
Cash and cash equivalents		134,408	72	43,024	185
Accounts receivable – trade, net		145,297	170,503
Accounts receivable – affiliates		50,518	8,621
Derivative instruments		1,095,929	1,207,012
Other current assets		59,170	49,606
Total current assets		1,485,322	1,435,814
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		13,129,776	13,110,094
Less accumulated depletion and amortization		(9,776,724)	(9,557,283)
Oil and natural gas properties, successful efforts method, net		3,353,052	3,552,811
Other property and equipment		600,783	597,216
Less accumulated depreciation		(194,874)	(183,139)
Other property and equipment, net		405,909	414,077
Derivative instruments		451,843	566,401
Restricted cash		7,208	7,004
Notes receivable – affiliates		0	0
Investments in consolidated subsidiaries		0	0
Other noncurrent assets		8,223	17,178
Noncurrent assets, excluding property, total		467,274	590,583
Total noncurrent assets		4,226,235	4,557,471
Total assets		5,711,557	5,993,285
Current liabilities:
Accounts payable and accrued expenses		269,911	336,962
Accounts payable – affiliates		2,885,185	2,920,082
Derivative instruments		0	0
Current portion of long-term debt, net		0	0
Other accrued liabilities		32,985	52,997
Total current liabilities		3,188,081	3,310,041
Noncurrent liabilities:
Derivative instruments		474	857
Long-term debt, net		0	0
Notes payable – affiliates		162,700	175,100
Other noncurrent liabilities		402,515	399,676
Total noncurrent liabilities		565,689	575,633
Unitholders’ deficit:
Units issued and outstanding		4,831,568	4,831,758
Accumulated deficit		(2,873,781)	(2,724,147)
Total unitholders' deficit		1,957,787	2,107,611
Total liabilities and unitholders’ deficit		5,711,557	5,993,285
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Current assets:
Cash and cash equivalents		7,334	1,023	1,424	1,586
Accounts receivable – trade, net		40,755	46,053
Accounts receivable – affiliates		0	0
Derivative instruments		295	13,218
Other current assets		19,582	20,897
Total current assets		67,966	81,191
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		5,019,579	5,011,061
Less accumulated depletion and amortization		(2,682,011)	(1,596,165)
Oil and natural gas properties, successful efforts method, net		2,337,568	3,414,896
Other property and equipment		113,947	111,495
Less accumulated depreciation		(14,617)	(12,522)
Other property and equipment, net		99,330	98,973
Derivative instruments		0	0
Restricted cash		250,612	250,359
Notes receivable – affiliates		0	0
Investments in consolidated subsidiaries		0	0
Other noncurrent assets		16,836	16,057
Noncurrent assets, excluding property, total		267,448	266,416
Total noncurrent assets		2,704,346	3,780,285
Total assets		2,772,312	3,861,476
Current liabilities:
Accounts payable and accrued expenses		98,163	117,127
Accounts payable – affiliates		50,518	8,621
Derivative instruments		1,190	2,241
Current portion of long-term debt, net		873,175	873,175
Other accrued liabilities		29,996	16,735
Total current liabilities		1,053,042	1,017,899
Noncurrent liabilities:
Derivative instruments		0	0
Long-term debt, net		844,927	845,368
Notes payable – affiliates		0	0
Other noncurrent liabilities		213,003	212,050
Total noncurrent liabilities		1,057,930	1,057,418
Unitholders’ deficit:
Units issued and outstanding		2,798,713	2,798,713
Accumulated deficit		(2,137,373)	(1,012,554)
Total unitholders' deficit		661,340	1,786,159
Total liabilities and unitholders’ deficit		2,772,312	3,861,476
Eliminations
Current assets:
Cash and cash equivalents		0	0	$ 0	$ 0
Accounts receivable – trade, net		0	0
Accounts receivable – affiliates		(2,935,703)	(2,928,703)
Derivative instruments		0	0
Other current assets		0	0
Total current assets		(2,935,703)	(2,928,703)
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		0	0
Less accumulated depletion and amortization		65,173	55,956
Oil and natural gas properties, successful efforts method, net		65,173	55,956
Other property and equipment		0	0
Less accumulated depreciation		0	0
Other property and equipment, net		0	0
Derivative instruments		0	0
Restricted cash		0	0
Notes receivable – affiliates		(162,700)	(175,100)
Investments in consolidated subsidiaries		(2,675,208)	(3,940,444)
Other noncurrent assets		0	(1)
Noncurrent assets, excluding property, total		(2,837,908)	(4,115,545)
Total noncurrent assets		(2,772,735)	(4,059,589)
Total assets		(5,708,438)	(6,988,292)
Current liabilities:
Accounts payable and accrued expenses		0	0
Accounts payable – affiliates		(2,935,703)	(2,928,703)
Derivative instruments		0	0
Current portion of long-term debt, net		0	0
Other accrued liabilities		0	0
Total current liabilities		(2,935,703)	(2,928,703)
Noncurrent liabilities:
Derivative instruments		0	0
Long-term debt, net		0	0
Notes payable – affiliates		(162,700)	(175,100)
Other noncurrent liabilities		0	(1)
Total noncurrent liabilities		(162,700)	(175,101)
Unitholders’ deficit:
Units issued and outstanding		(7,621,189)	(7,621,189)
Accumulated deficit		5,011,154	3,736,701
Total unitholders' deficit		(2,610,035)	(3,884,488)
Total liabilities and unitholders’ deficit		$ (5,708,438)	$ (6,988,292)
[1]	Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at March 31, 2016, and December 31, 2015. The current portion as of both March 31, 2016, and December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.

Subsidiary Guarantors Condens53

Subsidiary Guarantors Condensed Consolidating Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenues and other:
Oil, natural gas and natural gas liquids sales	$ 283,315	$ 450,569
Gains on oil and natural gas derivatives	109,961	424,781
Marketing revenues	14,305	33,744
Other revenues	7,186	7,453
Total revenues	414,767	916,547
Expenses:
Lease operating expenses	137,645	173,021
Transportation expenses	54,923	53,540
Marketing expenses	12,288	28,841
General and administrative expenses	86,529	78,968
Exploration costs	2,693	396
Depreciation, depletion and amortization	164,058	215,014
Impairment of long-lived assets	1,153,904	532,617
Taxes, other than income taxes	34,067	54,045
(Gains) losses on sale of assets and other, net	1,077	(12,287)
Total expenses	1,647,184	1,124,155
Other income and (expenses):
Interest expense, net of amounts capitalized	(105,219)	(143,101)
Interest expense – affiliates	0	0
Interest income – affiliates	0	0
Equity in losses from consolidated subsidiaries	0	0
Gain on extinguishment of debt	0	6,635
Other, net	134	(2,213)
Total other income and (expenses)	(105,085)	(138,679)
Loss before income taxes	(1,337,502)	(346,287)
Income tax expense (benefit)	10,244	(7,127)
Net loss	(1,347,746)	(339,160)
Reportable Legal Entities [Member] | Linn Energy, LLC
Revenues and other:
Oil, natural gas and natural gas liquids sales	0	0
Gains on oil and natural gas derivatives	0	0
Marketing revenues	0	0
Other revenues	0	0
Total revenues	0	0
Expenses:
Lease operating expenses	0	0
Transportation expenses	0	0
Marketing expenses	0	0
General and administrative expenses	0	0
Exploration costs	0	0
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0	0
Taxes, other than income taxes	2	2
(Gains) losses on sale of assets and other, net	0	0
Total expenses	2	2
Other income and (expenses):
Interest expense, net of amounts capitalized	(85,472)	(123,386)
Interest expense – affiliates	0	0
Interest income – affiliates	2,969	2,382
Equity in losses from consolidated subsidiaries	(1,265,236)	(222,811)
Gain on extinguishment of debt		6,635
Other, net	(5)	(1,978)
Total other income and (expenses)	(1,347,744)	(339,158)
Loss before income taxes	(1,347,746)	(339,160)
Income tax expense (benefit)	0	0
Net loss	(1,347,746)	(339,160)
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Revenues and other:
Oil, natural gas and natural gas liquids sales	199,849	293,983
Gains on oil and natural gas derivatives	109,453	421,514
Marketing revenues	9,061	26,212
Other revenues	5,138	5,557
Total revenues	323,501	747,266
Expenses:
Lease operating expenses	87,552	105,832
Transportation expenses	41,994	40,934
Marketing expenses	7,833	23,196
General and administrative expenses	61,357	57,781
Exploration costs	2,693	396
Depreciation, depletion and amortization	108,045	140,699
Impairment of long-lived assets	129,703	325,417
Taxes, other than income taxes	19,752	30,711
(Gains) losses on sale of assets and other, net	1,269	(7,814)
Total expenses	460,198	717,152
Other income and (expenses):
Interest expense, net of amounts capitalized	205	1,706
Interest expense – affiliates	(2,969)	(2,382)
Interest income – affiliates	0	0
Equity in losses from consolidated subsidiaries	0	0
Gain on extinguishment of debt		0
Other, net	73	(65)
Total other income and (expenses)	(2,691)	(741)
Loss before income taxes	(139,388)	29,373
Income tax expense (benefit)	10,246	(7,077)
Net loss	(149,634)	36,450
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Revenues and other:
Oil, natural gas and natural gas liquids sales	83,466	156,586
Gains on oil and natural gas derivatives	508	3,267
Marketing revenues	5,244	7,532
Other revenues	2,048	1,896
Total revenues	91,266	169,281
Expenses:
Lease operating expenses	50,093	67,189
Transportation expenses	12,929	12,606
Marketing expenses	4,455	5,645
General and administrative expenses	25,172	21,187
Exploration costs	0	0
Depreciation, depletion and amortization	58,843	72,979
Impairment of long-lived assets	1,030,588	272,000
Taxes, other than income taxes	14,313	23,332
(Gains) losses on sale of assets and other, net	(192)	(4,473)
Total expenses	1,196,201	470,465
Other income and (expenses):
Interest expense, net of amounts capitalized	(19,952)	(21,421)
Interest expense – affiliates	0	0
Interest income – affiliates	0	0
Equity in losses from consolidated subsidiaries	0	0
Gain on extinguishment of debt		0
Other, net	66	(170)
Total other income and (expenses)	(19,886)	(21,591)
Loss before income taxes	(1,124,821)	(322,775)
Income tax expense (benefit)	(2)	(50)
Net loss	(1,124,819)	(322,725)
Eliminations
Revenues and other:
Oil, natural gas and natural gas liquids sales	0	0
Gains on oil and natural gas derivatives	0	0
Marketing revenues	0	0
Other revenues	0	0
Total revenues	0	0
Expenses:
Lease operating expenses	0	0
Transportation expenses	0	0
Marketing expenses	0	0
General and administrative expenses	0	0
Exploration costs	0	0
Depreciation, depletion and amortization	(2,830)	1,336
Impairment of long-lived assets	(6,387)	(64,800)
Taxes, other than income taxes	0	0
(Gains) losses on sale of assets and other, net	0	0
Total expenses	(9,217)	(63,464)
Other income and (expenses):
Interest expense, net of amounts capitalized	0	0
Interest expense – affiliates	2,969	2,382
Interest income – affiliates	(2,969)	(2,382)
Equity in losses from consolidated subsidiaries	1,265,236	222,811
Gain on extinguishment of debt		0
Other, net	0	0
Total other income and (expenses)	1,265,236	222,811
Loss before income taxes	1,274,453	286,275
Income tax expense (benefit)	0	0
Net loss	$ 1,274,453	$ 286,275

Subsidiary Guarantors Condens54

Subsidiary Guarantors Condensed Consolidating Statements of Cash Flow (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flow from operating activities:
Net loss	$ (1,347,746)	$ (339,160)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	164,058	215,014
Impairment of long-lived assets	1,153,904	532,617
Unit-based compensation expenses	12,425	20,510
Gain on extinguishment of debt	0	(6,635)
Amortization and write-off of deferred financing fees	4,858	6,712
(Gains) losses on sale of assets and other, net	1,916	(7,100)
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	9,420	(7,158)
Derivatives activities:
Total gains	(106,593)	(423,855)
Cash settlements	343,723	282,082
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	31,113	135,230
(Increase) decrease in accounts receivable – affiliates	0	0
Increase in other assets	(8,289)	(12,399)
Decrease in accounts payable and accrued expenses	(14,527)	(29,868)
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	46,766	8,713
Net cash provided by operating activities	291,028	374,703
Cash flow from investing activities:
Development of oil and natural gas properties	(81,426)	(264,818)
Purchases of other property and equipment	(9,731)	(12,401)
Investment in affiliates		0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	(264)	27,500
Net cash used in investing activities	(91,421)	(249,719)
Cash flow from financing activities:
Proceeds from sale of units	0	15,900
Proceeds from borrowings	978,500	395,000
Repayments of debt	(100,000)	(280,287)
Distributions to unitholders	0	(104,815)
Financing fees and offering costs	(32)	(453)
Change in notes payable with affiliate	0	0
Distribution to affiliate		0
Excess tax benefit from unit-based compensation	0	(8,867)
Other	(20,687)	(94,959)
Net cash provided by (used in) financing activities	857,781	(78,481)
Net increase in cash and cash equivalents	1,057,388	46,503
Cash and cash equivalents:
Beginning	2,168	1,809
Ending	1,059,556	48,312
Reportable Legal Entities [Member] | Linn Energy, LLC
Cash flow from operating activities:
Net loss	(1,347,746)	(339,160)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	0	0
Impairment of long-lived assets	0	0
Unit-based compensation expenses	0	0
Gain on extinguishment of debt		(6,635)
Amortization and write-off of deferred financing fees	4,676	6,453
(Gains) losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	(1,265,236)	(222,811)
Deferred income taxes	0	0
Derivatives activities:
Total gains	0	0
Cash settlements	0	0
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	0	21,921
(Increase) decrease in accounts receivable – affiliates	(49,034)	(17,082)
Increase in other assets	0	0
Decrease in accounts payable and accrued expenses	(36)	(290)
Increase (decrease) in accounts payable and accrued expenses – affiliates	0	0
Increase in other liabilities	56,876	42,695
Net cash provided by operating activities	28,040	(35,123)
Cash flow from investing activities:
Development of oil and natural gas properties	0	0
Purchases of other property and equipment	0	0
Investment in affiliates		43,778
Change in notes receivable with affiliate	(12,400)	16,400
Proceeds from sale of properties and equipment and other	(918)	(1,121)
Net cash used in investing activities	11,482	26,257
Cash flow from financing activities:
Proceeds from sale of units		15,900
Proceeds from borrowings	978,500	395,000
Repayments of debt	(100,000)	(280,287)
Distributions to unitholders		(104,815)
Financing fees and offering costs	(32)	(453)
Change in notes payable with affiliate	0	0
Distribution to affiliate		0
Excess tax benefit from unit-based compensation		(8,867)
Other	(1,249)	(3,786)
Net cash provided by (used in) financing activities	877,219	12,692
Net increase in cash and cash equivalents	916,741	3,826
Cash and cash equivalents:
Beginning	1,073	38
Ending	917,814	3,864
Reportable Legal Entities [Member] | Guarantor Subsidiaries
Cash flow from operating activities:
Net loss	(149,634)	36,450
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	108,045	140,699
Impairment of long-lived assets	129,703	325,417
Unit-based compensation expenses	12,425	20,510
Gain on extinguishment of debt		0
Amortization and write-off of deferred financing fees	0	0
(Gains) losses on sale of assets and other, net	2,226	(5,243)
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	9,422	(7,108)
Derivatives activities:
Total gains	(109,454)	(421,514)
Cash settlements	334,712	254,569
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	25,815	96,917
(Increase) decrease in accounts receivable – affiliates	41,897	19,856
Increase in other assets	(8,225)	(8,521)
Decrease in accounts payable and accrued expenses	(594)	(3,844)
Increase (decrease) in accounts payable and accrued expenses – affiliates	(49,034)	(17,082)
Increase in other liabilities	(21,163)	(24,057)
Net cash provided by operating activities	242,347	367,337
Cash flow from investing activities:
Development of oil and natural gas properties	(70,407)	(263,209)
Purchases of other property and equipment	(6,404)	(11,309)
Investment in affiliates		0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	638	24,808
Net cash used in investing activities	(76,173)	(249,710)
Cash flow from financing activities:
Proceeds from sale of units		0
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders		0
Financing fees and offering costs	0	0
Change in notes payable with affiliate	(12,400)	16,400
Distribution to affiliate		0
Excess tax benefit from unit-based compensation		0
Other	(19,438)	(91,188)
Net cash provided by (used in) financing activities	(31,838)	(74,788)
Net increase in cash and cash equivalents	134,336	42,839
Cash and cash equivalents:
Beginning	72	185
Ending	134,408	43,024
Reportable Legal Entities [Member] | Non- Guarantor Subsidiary
Cash flow from operating activities:
Net loss	(1,124,819)	(322,725)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	58,843	72,979
Impairment of long-lived assets	1,030,588	272,000
Unit-based compensation expenses	0	0
Gain on extinguishment of debt		0
Amortization and write-off of deferred financing fees	182	259
(Gains) losses on sale of assets and other, net	(310)	(1,857)
Equity in losses from consolidated subsidiaries	0	0
Deferred income taxes	(2)	(50)
Derivatives activities:
Total gains	2,861	(2,341)
Cash settlements	9,011	27,513
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	5,298	16,392
(Increase) decrease in accounts receivable – affiliates	0	0
Increase in other assets	(64)	(3,878)
Decrease in accounts payable and accrued expenses	(13,897)	(25,734)
Increase (decrease) in accounts payable and accrued expenses – affiliates	41,897	19,856
Increase in other liabilities	11,053	(9,925)
Net cash provided by operating activities	20,641	42,489
Cash flow from investing activities:
Development of oil and natural gas properties	(11,019)	(1,609)
Purchases of other property and equipment	(3,327)	(1,092)
Investment in affiliates		0
Change in notes receivable with affiliate	0	0
Proceeds from sale of properties and equipment and other	16	3,813
Net cash used in investing activities	(14,330)	1,112
Cash flow from financing activities:
Proceeds from sale of units		0
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders		0
Financing fees and offering costs	0	0
Change in notes payable with affiliate	0	0
Distribution to affiliate		(43,778)
Excess tax benefit from unit-based compensation		0
Other	0	15
Net cash provided by (used in) financing activities	0	(43,763)
Net increase in cash and cash equivalents	6,311	(162)
Cash and cash equivalents:
Beginning	1,023	1,586
Ending	7,334	1,424
Eliminations
Cash flow from operating activities:
Net loss	1,274,453	286,275
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	(2,830)	1,336
Impairment of long-lived assets	(6,387)	(64,800)
Unit-based compensation expenses	0	0
Gain on extinguishment of debt		0
Amortization and write-off of deferred financing fees	0	0
(Gains) losses on sale of assets and other, net	0	0
Equity in losses from consolidated subsidiaries	1,265,236	222,811
Deferred income taxes	0	0
Derivatives activities:
Total gains	0	0
Cash settlements	0	0
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	0	0
(Increase) decrease in accounts receivable – affiliates	7,137	(2,774)
Increase in other assets	0	0
Decrease in accounts payable and accrued expenses	0	0
Increase (decrease) in accounts payable and accrued expenses – affiliates	7,137	(2,774)
Increase in other liabilities	0	0
Net cash provided by operating activities	0	0
Cash flow from investing activities:
Development of oil and natural gas properties	0	0
Purchases of other property and equipment	0	0
Investment in affiliates		(43,778)
Change in notes receivable with affiliate	12,400	(16,400)
Proceeds from sale of properties and equipment and other	0	0
Net cash used in investing activities	(12,400)	(27,378)
Cash flow from financing activities:
Proceeds from sale of units		0
Proceeds from borrowings	0	0
Repayments of debt	0	0
Distributions to unitholders		0
Financing fees and offering costs	0	0
Change in notes payable with affiliate	12,400	(16,400)
Distribution to affiliate		43,778
Excess tax benefit from unit-based compensation		0
Other	0	0
Net cash provided by (used in) financing activities	12,400	27,378
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents:
Beginning	0	0
Ending	$ 0	$ 0