Document

10-Q 1 line930201610q.htm FORM 10-Q Q3 2016 Document

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended September 30, 2016



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _______________ to _______________

Commission File Number: 000-51719

LINN ENERGY, LLC

(Exact name of registrant as specified in its charter)



Delaware (State or other jurisdiction of incorporation or organization)	65-1177591 (I.R.S. Employer Identification No.)
600 Travis Houston, Texas (Address of principal executive offices)	77002 (Zip Code)
(281) 840-4000 (Registrant’s telephone number, including area code)

600 Travis, Suite 5100 Houston, Texas 77002 (Former address of principal executive offices)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨ Smaller reporting company x

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No x

As of October 31, 2016, there were 355,032,380 units outstanding.

TABLE OF CONTENTS



		Page

	Glossary of Terms	ii

	Part I – Financial Information
Item 1.	Financial Statements
	Condensed Consolidated Balance Sheets as of September 30, 2016, and December 31, 2015	1
	Condensed Consolidated Statements of Operations for the three months and nine months ended September 30, 2016, and September 30, 2015	2
	Condensed Consolidated Statement of Unitholders’ Deficit for the nine months ended September 30, 2016	3
	Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2016, and September 30, 2015	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	37
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	66
Item 4.	Controls and Procedures	67

	Part II – Other Information
Item 1.	Legal Proceedings	68
Item 1A.	Risk Factors	68
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	72
Item 3.	Defaults Upon Senior Securities	72
Item 4.	Mine Safety Disclosures	72
Item 5.	Other Information	73
Item 6.	Exhibits	74

	Signatures	76

Table of Contents

GLOSSARY OF TERMS

As commonly used in the oil and natural gas industry and as used in this Quarterly Report on Form 10-Q, the following terms have the following meanings:

Bbl. One stock tank barrel or 42 United States gallons liquid volume.

Bcf. One billion cubic feet.

Bcfe. One billion cubic feet equivalent, determined using the ratio of six Mcf of natural gas to one Bbl of oil, condensate or natural gas liquids.

Btu. One British thermal unit, which is the heat required to raise the temperature of a one-pound mass of water from 58.5 degrees to 59.5 degrees Fahrenheit.

MBbls. One thousand barrels of oil or other liquid hydrocarbons.

MBbls/d. MBbls per day.

Mcf. One thousand cubic feet.

Mcfe. One thousand cubic feet equivalent, determined using the ratio of six Mcf of natural gas to one Bbl of oil, condensate or natural gas liquids.

MMBbls. One million barrels of oil or other liquid hydrocarbons.

MMBtu. One million British thermal units.

MMcf. One million cubic feet.

MMcf/d. MMcf per day.

MMcfe. One million cubic feet equivalent, determined using the ratio of six Mcf of natural gas to one Bbl of oil, condensate or natural gas liquids.

MMcfe/d. MMcfe per day.

MMMBtu. One billion British thermal units.

NGL. Natural gas liquids, which are the hydrocarbon liquids contained within natural gas.

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PART I – FINANCIAL INFORMATION


Item 1.	Financial Statements

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)



	September 30, 2016			December 31, 2015
	(in thousands, except unit amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	800,507		$	2,168
Accounts receivable – trade, net	213,108			216,556
Derivative instruments	1,447			1,220,230
Other current assets	121,092			95,593
Total current assets	1,136,154			1,534,547

Noncurrent assets:
Oil and natural gas properties (successful efforts method)	18,193,256			18,121,155
Less accumulated depletion and amortization	(12,676,972		)	(11,097,492		)
	5,516,284			7,023,663

Other property and equipment	742,264			708,711
Less accumulated depreciation	(232,245		)	(195,661		)
	510,019			513,050

Derivative instruments	—			566,401
Restricted cash	205,204			257,363
Other noncurrent assets	35,287			33,234
	240,491			856,998
Total noncurrent assets	6,266,794			8,393,711
Total assets	$	7,402,948		$	9,928,258

LIABILITIES AND UNITHOLDERS’ DEFICIT
Current liabilities:
Accounts payable and accrued expenses	$	363,003		$	455,374
Derivative instruments	1,776			2,241
Current portion of long-term debt, net	2,828,848			3,714,693
Other accrued liabilities	46,299			119,593
Total current liabilities	3,239,926			4,291,901

Derivative instruments	1,199			857
Long-term debt, net	—			5,292,676
Other noncurrent liabilities	571,123			611,725
Liabilities subject to compromise	5,173,059			—

Commitments and contingencies (Note 10)

Unitholders’ deficit:
355,142,363 units and 355,017,428 units issued and outstanding at September 30, 2016, and December 31, 2015, respectively	5,367,277			5,343,116
Accumulated deficit	(6,949,636		)	(5,612,017		)
	(1,582,359		)	(268,901		)
Total liabilities and unitholders’ deficit	$	7,402,948		$	9,928,258

The accompanying notes are an integral part of these condensed consolidated financial statements.

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(in thousands, except per unit amounts)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	360,143		$	427,245		$	959,715		$	1,374,233
Gains (losses) on oil and natural gas derivatives	274			549,029			(72,533		)	782,622
Marketing revenues	18,352			15,723			47,177			60,200
Other revenues	6,896			6,307			21,468			19,624
	385,665			998,304			955,827			2,236,679
Expenses:
Lease operating expenses	117,470			154,086			370,658			467,759
Transportation expenses	49,630			54,915			156,590			164,250
Marketing expenses	12,191			9,359			35,784			47,359
General and administrative expenses	50,202			60,113			196,377			237,731
Exploration costs	4			3,072			2,745			4,032
Depreciation, depletion and amortization	142,448			207,218			449,677			637,964
Impairment of long-lived assets	41,728			2,255,080			1,195,632			2,787,697
Taxes, other than income taxes	15,383			46,238			80,297			158,317
(Gains) losses on sale of assets and other, net	1,940			(166,980		)	5,959			(197,263		)
	430,996			2,623,101			2,493,719			4,307,846
Other income and (expenses):
Interest expense, net of amounts capitalized	(40,105		)	(138,383		)	(213,758		)	(427,584		)
Gain on extinguishment of debt	—			197,741			—			213,527
Other, net	(269		)	(1,701		)	(1,437		)	(10,060		)
	(40,374		)	57,657			(215,195		)	(224,117		)
Reorganization items, net	(116,276		)	—			418,608			—
Loss before income taxes	(201,981		)	(1,567,140		)	(1,334,479		)	(2,295,284		)
Income tax expense (benefit)	(3,616		)	2,177			3,140			(7,680		)
Net loss	$	(198,365	)	$	(1,569,317	)	$	(1,337,619	)	$	(2,287,604	)

Net loss per unit:
Basic	$	(0.56	)	$	(4.47	)	$	(3.79	)	$	(6.72	)
Diluted	$	(0.56	)	$	(4.47	)	$	(3.79	)	$	(6.72	)
Weighted average units outstanding:
Basic	352,792			350,695			352,606			340,831
Diluted	352,792			350,695			352,606			340,831

Distributions declared per unit	$	—		$	0.313		$	—		$	0.938

The accompanying notes are an integral part of these condensed consolidated financial statements.

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENT OF UNITHOLDERS’ DEFICIT

(Unaudited)



	Units	Unitholders’ Capital			Accumulated Deficit			Total Unitholders’ Deficit
	(in thousands)

December 31, 2015	355,017	$	5,343,116		$	(5,612,017	)	$	(268,901	)
Issuance of units	125	—			—			—
Unit-based compensation expenses		24,514			—			24,514
Other		(353		)	—			(353		)
Net loss		—			(1,337,619		)	(1,337,619		)
September 30, 2016	355,142	$	5,367,277		$	(6,949,636	)	$	(1,582,359	)

The accompanying notes are an integral part of these condensed consolidated financial statements.

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)



	Nine Months Ended September 30,
	2016			2015
	(in thousands)
Cash flow from operating activities:
Net loss	$	(1,337,619	)	$	(2,287,604	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	449,677			637,964
Impairment of long-lived assets	1,195,632			2,787,697
Unit-based compensation expenses	24,514			47,918
Gain on extinguishment of debt	—			(213,527		)
Amortization and write-off of deferred financing fees	12,514			23,798
(Gains) losses on sale of assets and other, net	4,660			(193,768		)
Deferred income taxes	902			(8,263		)
Reorganization items, net	(462,965		)	—
Derivatives activities:
Total (gains) losses	77,138			(785,520		)
Cash settlements	508,082			858,368
Cash settlements on canceled derivatives	358,536			—
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	(3,750		)	207,062
(Increase) decrease in other assets	(20,286		)	2,683
Increase (decrease) in accounts payable and accrued expenses	55,172			(36,626		)
Increase (decrease) in other liabilities	22,985			(5,413		)
Net cash provided by operating activities	885,192			1,034,769

Cash flow from investing activities:
Development of oil and natural gas properties	(142,396		)	(503,206		)
Purchases of other property and equipment	(36,936		)	(51,529		)
Decrease in restricted cash	53,418			—
Proceeds from sale of properties and equipment and other	(3,149		)	364,195
Net cash used in investing activities	(129,063		)	(190,540		)

Cash flow from financing activities:
Proceeds from sale of units	—			233,427
Proceeds from borrowings	978,500			1,405,000
Repayments of debt	(914,911		)	(1,701,909		)
Distributions to unitholders	—			(323,878		)
Financing fees and offering costs	(692		)	(8,774		)
Excess tax benefit from unit-based compensation	—			(9,467		)
Other	(20,687		)	(95,631		)
Net cash provided by (used in) financing activities	42,210			(501,232		)

Net increase in cash and cash equivalents	798,339			342,997
Cash and cash equivalents:
Beginning	2,168			1,809
Ending	$	800,507		$	344,806

The accompanying notes are an integral part of these condensed consolidated financial statements.

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 – 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.

Bankruptcy Accounting

As discussed further in Note 2, on May 11, 2016 (the “Petition Date”), the Company, certain of the Company’s direct and indirect subsidiaries, and LinnCo (collectively with the Company, the “LINN Debtors”) and Berry (collectively with the LINN Debtors, the “Debtors”), filed voluntary petitions (“Bankruptcy Petitions”) for relief 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”). During the pendency of the Chapter 11 proceedings, the Debtors will operate their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code.

The condensed consolidated financial statements have been prepared as if the Company is a going concern and reflect the application of Accounting Standards Codification 852 “Reorganizations” (“ASC 852”). ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 filing, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. Accordingly, certain expenses, gains and losses that are realized or incurred in the bankruptcy proceedings are recorded in “reorganization items, net” on the Company’s condensed consolidated statements of operations. In addition, prepetition unsecured and under-secured obligations that may be impacted by the bankruptcy reorganization process have been classified as “liabilities subject to compromise” on the Company’s condensed consolidated balance sheet at September 30, 2016. These liabilities are reported at the amounts expected to be allowed as claims by the Bankruptcy Court, although they may be settled for less.

The accompanying condensed consolidated financial statements do not purport to reflect or provide for the consequences of the Chapter 11 proceedings. In particular, the condensed consolidated financial statements do not purport to show: (i) the realizable

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

value of assets on a liquidation basis or their availability to satisfy liabilities; (ii) the amount of prepetition liabilities that may be allowed for claims or contingencies, or the status and priority thereof; (iii) the effect on unitholders’ deficit accounts of any changes that may be made to the Company’s capitalization; or (iv) the effect on operations of any changes that may be made to the Company’s business. While operating as debtor-in-possession under Chapter 11 of the Bankruptcy Code, the Company may sell or otherwise dispose of or liquidate assets or settle liabilities in amounts other than those reflected on its condensed consolidated financial statements, subject to the approval of the Bankruptcy Court or otherwise as permitted in the ordinary course of business. Further, a plan of reorganization could materially change the amounts and classifications on the Company’s historical condensed consolidated financial statements.

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

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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 consolidated 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.

Note 2 – Chapter 11 Proceedings, Ability to Continue as a Going Concern and Covenant Violations

Chapter 11 Proceedings

On the Petition Date, the Debtors filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code in the Bankruptcy Court. The Debtors’ Chapter 11 cases are being administered jointly under the caption In re Linn Energy, LLC., et al., Case No. 16‑60040.

The Debtors are operating their businesses as “debtors-in-possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code. The Bankruptcy Court has granted certain relief requested by the Debtors, allowing the Company to use its cash to fund the Chapter 11 proceedings, pursuant to an agreement with the first lien lenders, and giving the Company the authority to, among other things, continue to pay employee wages and benefits without interruption, to utilize its current cash management system and to make royalty payments. During the pendency of the Chapter 11 proceedings, all transactions outside the ordinary course of the Company’s business require prior approval of the Bankruptcy Court. For goods and services provided following the Petition Date, the Company intends to pay vendors in full under normal terms.

Bank RSA

Prior to the Petition Date, on May 10, 2016, the Debtors entered into a restructuring support agreement (“Bank RSA”) with certain holders (“Consenting Bank 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 Bank RSA sets forth, subject to certain conditions, the commitment of the Consenting Bank Creditors to support a comprehensive restructuring of the Debtors’ long-term debt. The restructuring transactions contemplated by the Bank RSA will be effectuated through one or more plans of reorganization (“Plan”) filed in the Chapter 11 proceedings.

The Bank RSA provides that the Consenting Bank Creditors will support the use of the LINN Debtors’ and Berry’s cash collateral under specified terms and conditions, including adequate protection terms. The Bank RSA obligates the Debtors and the Consenting Bank Creditors to, among other things, support and not interfere with consummation of the restructuring transactions contemplated by the Bank RSA and, as to the Consenting Bank Creditors, vote their claims in favor of the Plan. The Bank RSA may be terminated upon the occurrence of certain events, including the failure to meet specified milestones relating to, among other requirements, the filing, confirmation and consummation of the Plan, and in the event of certain breaches by the parties under the Bank RSA. The Bank RSA is subject to termination if the effective date of the Plan has not

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

occurred within 250 days of the Petition Date. There can be no assurance that the restructuring transactions contemplated by the Bank RSA will be consummated.

Restructuring Support Agreement

On October 7, 2016, the LINN Debtors entered into a restructuring support agreement (“Original LINN RSA”) with (i) certain holders of the Company’s 12.00% senior secured second lien notes due December 2020 (such notes, the “Second Lien Notes,” and such holders, the “Consenting Second Lien Noteholders”) and (ii) certain holders of the Company’s unsecured notes (such notes, the “Unsecured Notes,” and such holders of the Unsecured Notes, the “Consenting Unsecured Noteholders,” and together such Consenting Unsecured Noteholders with the Consenting Second Lien Noteholders, the “Consenting Noteholders”).

On October 21, 2016, the LINN Debtors entered into the First Amended and Restated Restructuring Support Agreement (“LINN RSA”) with (i) certain Consenting Second Lien Noteholders, (ii) certain Consenting Unsecured Noteholders and (iii) certain lenders (the “Consenting LINN Lenders,” and together with the Consenting Noteholders, the “Consenting LINN Creditors”) under the LINN Credit Facility. The LINN RSA amends and restates the Original LINN RSA and replaces the Bank RSA with respect to the terms of the restructuring of the LINN Debtors. The Bank RSA remains in full force and effect with respect to the restructuring of Berry and Linn Acquisition Company, LLC.

The LINN RSA sets forth, subject to certain conditions, the commitment of the LINN Debtors and the Consenting LINN Creditors to support a comprehensive restructuring of the LINN Debtors’ long-term debt (the “Restructuring”). The LINN RSA obligates the LINN Debtors and the Consenting LINN Creditors to, among other things, support and not interfere with consummation of the Restructuring and, as to the Consenting LINN Creditors, vote their claims in favor of the Plan. The LINN RSA 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, and in the event of certain breaches by the parties under the LINN RSA. The LINN RSA is subject to termination if the effective date of the Plan has not occurred by March 1, 2017. There can be no assurance that the Restructuring will be consummated.

Magnitude of Potential Claims

On July 11, 2016, the Debtors filed with the Bankruptcy Court schedules and statements setting forth, among other things, the assets and liabilities of the Debtors, subject to the assumptions filed in connection therewith. The schedules and statements may be subject to further amendment or modification after filing. Holders of prepetition claims are required to file proofs of claims by the applicable deadline for filing certain proofs of claims in the Debtors’ Chapter 11 cases, which was September 16, 2016, for general claims and is November 7, 2016, for governmental claims. Differences between amounts scheduled by the Debtors and claims by creditors will be investigated and resolved in connection with the claims resolution process.

Liabilities Subject to Compromise

The Company’s condensed consolidated balance sheet includes amounts classified as “liabilities subject to compromise,” which represent prepetition liabilities that have been allowed, or that the Company anticipates will be allowed, as claims in its Chapter 11 cases. The amounts represent the Company’s current estimate of known or potential obligations to be resolved in connection with the Chapter 11 proceedings. The differences between the liabilities the Company has estimated and the claims filed, or to be filed, will be investigated and resolved in connection with the claims resolution process. The Company will continue to evaluate these liabilities throughout the Chapter 11 process and adjust amounts as necessary. Such adjustments may be material.

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LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The following table summarizes the components of liabilities subject to compromise included on the condensed consolidated balance sheet:



	September 30, 2016
	(in thousands)

Accounts payable and accrued expenses	$	156,708
Accrued interest payable	159,422
Debt	4,856,929
Liabilities subject to compromise	$	5,173,059

Reorganization Items, Net

The Company has incurred and is expected to continue to incur significant costs associated with the reorganization. These costs, which are expensed as incurred, are expected to significantly affect the Company’s results of operations. Reorganization items represent costs and income directly associated with the Chapter 11 proceedings since the Petition Date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments are determined.

The following table summarizes the components of reorganization items included on the condensed consolidated statements of operations:



	Three Months Ended September 30, 2016			Nine Months Ended September 30, 2016
	(in thousands)

Legal and other professional advisory fees	$	(25,604	)	$	(46,114	)
Unamortized deferred financing fees, discounts and premiums	—			(41,122		)
Gain related to interest payable on the 12.00% senior secured second lien notes due December 2020 ⁽¹⁾	—			551,000
Terminated contracts	(92,957		)	(47,848		)
Other	2,285			2,692
Reorganization items, net	$	(116,276	)	$	418,608


⁽¹⁾	Represents a noncash gain on the write-off of postpetition contractual interest through maturity, recorded to reflect the carrying value of the liability subject to compromise at its estimated allowed claim amount.

Rejection of Executory Contracts

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 Bankruptcy Court and satisfaction of certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a prepetition 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 prepetition 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 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 any of the Debtors in this Quarterly Report on Form 10-Q, including where applicable a quantification of the Company’s obligations under any such executory contract or unexpired lease with the applicable Debtor, is qualified by any overriding

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(Unaudited)

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.

Effect of Filing on Creditors and Unitholders

Subject to certain exceptions, under the Bankruptcy Code, the filing of 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 Petition Date. Absent an order of the Bankruptcy Court, substantially all of the Debtors’ prepetition liabilities are subject to settlement under the Bankruptcy Code. Although the filing of 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. The Company did not record interest expense on its Second Lien Notes or senior notes for the three months ended September 30, 2016, or for the period from May 12, 2016, through September 30, 2016. For those periods, unrecorded contractual interest was approximately $100 million and $154 million, respectively.

Under the Bankruptcy Code, unless creditors agree otherwise, prepetition liabilities and postpetition liabilities must be satisfied in full before the holders of the Company’s existing common units representing limited liability company interests (“units”) are entitled to receive any settlement or retain any property under a plan of reorganization. The ultimate recovery to creditors and/or unitholders, if any, will not be determined until confirmation and implementation of a plan or plans of reorganization. No assurance can be given as to what values, if any, will be ascribed in the Chapter 11 proceedings to each of these constituencies or what types or amounts of settlements, if any, they will receive. A plan of reorganization could result in holders of the Debtors’ liabilities and/or units receiving no settlement on account of their interests and cancellation of their holdings.

Process for Plan of Reorganization

In order to successfully exit bankruptcy, the Debtors will need to propose, and obtain confirmation by the Bankruptcy Court of, a Plan that satisfies the requirements of the Bankruptcy Code. A Plan would, among other things, resolve the Debtors’ prepetition obligations, set forth the revised capital structure of the newly reorganized entity and provide for corporate governance subsequent to exit from bankruptcy.

In addition to being voted on by holders of impaired claims and equity interests, a Plan must satisfy certain requirements of the Bankruptcy Code and must be approved, or confirmed, by the Bankruptcy Court in order to become effective. A Plan would be accepted by holders of claims against and equity interests in the Debtors if (i) at least one-half in number and two-thirds in dollar amount of claims actually voting in each class of claims impaired by the Plan have voted to accept the Plan and (ii) at least two-thirds in amount of equity interests impaired by the Plan actually voting has voted to accept the Plan. A class of claims or equity interests that does not receive or retain any property under the Plan on account of such claims or interests is deemed to have voted to reject the Plan.

Under certain circumstances set forth in Section 1129(b) of the Bankruptcy Code, the Bankruptcy Court may confirm a Plan even if such Plan has not been accepted by all impaired classes of claims and equity interests. The precise requirements and evidentiary showing for confirming a Plan notwithstanding its rejection by one or more impaired classes of claims or equity interests depends upon a number of factors, including the status and seniority of the claims or equity interests in the rejecting class (i.e., unsecured or secured claims, subordinated or senior claims). Generally, with respect to units, a Plan may be “crammed down” even if the unitholders receive no recovery if the proponent of the Plan demonstrates that (1) no class junior to the units are receiving or retaining property under the Plan and (2) no class of claims or interests senior to the units are being paid more than in full.

On October 21, 2016, the Debtors filed a proposed Plan with the Bankruptcy Court.

Ability to Continue as a Going Concern

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(Unaudited)

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, were expected to adversely impact upcoming redeterminations and have a significant negative impact on the Company’s liquidity. The Company’s filing of the Bankruptcy Petitions constituted an event of default that accelerated the Company’s obligations under its Credit Facilities, its 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 undertook a number of actions, including minimizing capital expenditures and further reducing its recurring operating expenses. Despite taking these actions, the Company did 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 relief under Chapter 11 of the Bankruptcy Code.

Covenant Violations

The Company’s filing of the Bankruptcy Petitions constituted 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 the Company’s Second Lien Notes and senior notes, as well as 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 a 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 the Berry Credit Facility. The amendments provided for, among other things, an agreement that (i) certain 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 previously restricted cash of $45 million in order to fund ordinary course operations.

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.

Pursuant to the terms of the amendment to the LINN Credit Facility and as a result of the execution of the Bank RSA, in May 2016, the Company made a $350 million permanent repayment of a portion of the borrowings outstanding under the LINN Credit Facility.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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.

The settlement agreement required the parties to 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. The settlement agreement provided that in the event the parties were unable to reach agreement on the terms of a consensual restructuring on or before the commencement of such Chapter 11 proceedings (or such later date as mutually agreed to by the parties), the parties would 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 will terminate upon, among other events, entry by the Bankruptcy Court of a final, non-appealable order denying the Company’s motion seeking entry of the Settlement Order.

The Company failed to make an interest payment on its Second Lien Notes of approximately $68 million due June 15, 2016.

The filing of the Bankruptcy Petitions constituted 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 provided 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.

The Company failed to make interest payments due on its senior notes subsequent to April 14, 2016.

The filing of the Bankruptcy Petitions constituted 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.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Note 3 – Unitholders’ Deficit

Delisting from Stock Exchange

As a result of the Company’s failure to comply with the NASDAQ Global Select Market (“NASDAQ”) continued listing requirements, on May 24, 2016, the Company’s units began trading over the counter on the OTC Markets Group Inc.’s Pink marketplace under the trading symbol “LINEQ.”

At-the-Market Offering Program

The Company’s Board of Directors had authorized the sale of up to $500 million of units under an at-the-market offering program, with sales of units, if any, to be made under an equity distribution agreement. No sales were made under the equity distribution agreement during the nine months ended September 30, 2016. During the nine months ended September 30, 2015, the Company, under its equity distribution agreement, sold 3,621,983 units representing limited liability company interests at an average price of $12.37 per unit for net proceeds of approximately $44 million (net of approximately $448,000 in commissions). In connection with the issuance and sale of these units, the Company also incurred professional services expenses of approximately $459,000. 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).

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; however, as a result of the Chapter 11 proceedings, the Company cannot pay any distributions without the prior approval of the Bankruptcy Court. Distributions paid by the Company during 2015 are presented on the condensed consolidated statement of cash flows.

Note 4 – 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:



	September 30, 2016			December 31, 2015
	(in thousands)
Proved properties:
Leasehold acquisition	$	13,371,861		$	13,361,171
Development	3,043,225			2,976,643
Unproved properties	1,778,170			1,783,341
	18,193,256			18,121,155
Less accumulated depletion and amortization	(12,676,972		)	(11,097,492		)
	$	5,516,284		$	7,023,663

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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 September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
	(in thousands)

California region	$	—	$	330,311	$	984,288	$	537,511
Mid-Continent region	18,586		366,865		148,289		372,568
Rockies region	23,142		1,182,337		49,819		1,182,337
TexLa region	—		375,567		—		408,667
Hugoton Basin region	—		—		—		277,914
South Texas region	—		—		—		8,700
	$	41,728	$	2,255,080	$	1,182,396	$	2,787,697

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 and the Company’s estimates of proved reserves. 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 nine months ended September 30, 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 September 30, 2016, or the nine months ended September 30, 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.

Divestiture – 2015

On August 31, 2015, the Company, through certain of its wholly owned subsidiaries, completed the sale of its remaining position in Howard County in the Permian Basin. Cash proceeds received from the sale of these properties were approximately

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(Unaudited)

$276 million, net of costs to sell of approximately $1 million, and the Company recognized a net gain of approximately $174 million for the three months ended September 30, 2015. The gain is included in “(gains) losses on sale of assets and other, net” on the condensed consolidated statements of operations. The Company used the net proceeds from the sale to repay a portion of the outstanding indebtedness under the LINN Credit Facility.

Note 5 – Unit-Based Compensation

The Company granted no unit-based awards during the nine months ended September 30, 2016. A summary of unit-based compensation expenses included on the condensed consolidated statements of operations is presented below:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
	(in thousands)

General and administrative expenses	$	4,832	$	13,040	$	19,238	$	40,717
Lease operating expenses	1,129		1,167		5,276		7,201
Total unit-based compensation expenses	$	5,961	$	14,207	$	24,514	$	47,918
Income tax benefit	$	2,203	$	5,250	$	9,058	$	17,706

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 September 30, 2016.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Note 6 – Debt

The following summarizes the Company’s outstanding debt:



	September 30, 2016			December 31, 2015
	(in thousands, except percentages)

LINN credit facility ⁽¹⁾	$	1,654,745		$	2,215,000
Berry credit facility ⁽²⁾	891,259			873,175
Term loan ⁽²⁾	284,241			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 ⁽³⁾	1,000,000			1,000,000
Interest payable on senior secured second lien notes due December 2020 ⁽³⁾	—			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 ⁽⁴⁾	—			(8,694		)
Net unamortized deferred financing fees ⁽⁴⁾	(1,397		)	(37,374		)
Total debt, net	7,685,777			9,007,369
Less current portion, net ⁽⁵⁾	(2,828,848		)	(3,714,693		)
Less liabilities subject to compromise ⁽⁶⁾	(4,856,929		)	—
Long-term debt, net	$	—		$	5,292,676


⁽¹⁾	Variable interest rates of 5.25% and 2.66% at September 30, 2016, and December 31, 2015, respectively.


⁽²⁾	Variable interest rates of 5.25% and 3.17% at September 30, 2016, and December 31, 2015, respectively.

⁽³⁾

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. During the nine months ended September 30, 2016, $551 million was written off to reorganization items in connection with the filing of the Bankruptcy Petitions. The remaining amount of approximately $57 million was classified as liabilities subject to compromise at September 30, 2016.


⁽⁴⁾	Approximately $41 million in net discounts, premiums and deferred financing fees were written off to reorganization items in connection with the filing of the Bankruptcy Petitions.


⁽⁵⁾	Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at September 30, 2016, and December 31, 2015. The current portion as of December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.


⁽⁶⁾	The Company’s senior notes and Second Lien Notes were classified as liabilities subject to compromise at September 30, 2016.

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.

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)



	September 30, 2016				December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(in thousands)

Senior secured second lien notes	$	1,000,000	$	466,250	$	1,000,000	$	501,250
Senior notes, net	3,856,929		1,202,887		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 senior secured term loan, in aggregate subject to the then-effective borrowing base. The maturity date is April 2019, subject to a “springing maturity” based on the maturity of any outstanding LINN Energy junior lien debt. At September 30, 2016, the Company had approximately $1.7 billion in total borrowings outstanding (including outstanding letters of credit) under the revolving credit facility and approximately $284 million under the term loan, and there was no remaining availability.

See Note 2 for details of the amendment to the LINN Credit Facility entered into on April 12, 2016.

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. 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 monthly 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 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 monthly 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

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(Unaudited)

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”) provides for a senior secured revolving credit facility, subject to the then-effective borrowing base. The maturity date is April 2019. At September 30, 2016, the Company had approximately $898 million in total borrowings outstanding (including outstanding letters of credit) under the Berry Credit Facility and there was no remaining availability.

See Note 2 for details of the amendment to the Berry Credit Facility entered into on April 12, 2016.

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. 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 in Note 2, the lenders had agreed that the failure to maintain the EBITDAX to Interest Expense ratio would not result in 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 monthly 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 0.50% 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 constituted 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. The automatic stay under the Bankruptcy Code does not apply to letters of credit issued under the prepetition Credit Facilities and third parties may draw on their letters of credit if the terms of a particular letter of credit so provide. During the three months and nine months ended September 30, 2016, approximately $16 million and $20 million, respectively, in letters of credit draws were made from the Berry Credit Facility.

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.

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”). Under the Registration Rights Agreements, the Company agreed to use its reasonable efforts to file with the SEC and cause to become effective a registration statement relating to an offer to issue new notes having terms substantially identical to the Second Lien Notes in exchange for outstanding Second Lien Notes within 370 days following the issuance of the Second Lien Notes. 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

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(Unaudited)

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 following the issuance of the Second Lien Notes. 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 nine months ended September 30, 2016. During the nine months ended September 30, 2015, the Company repurchased on the open market approximately $783 million of its outstanding senior notes as follows:


•	6.50% senior notes due May 2019 – $41 million;


•	6.25% senior notes due November 2019 – $316 million;


•	8.625% senior notes due April 2020 – $177 million;


•	6.75% Berry senior notes due November 2020 – $39 million;


•	7.75% senior notes due February 2021 – $36 million;


•	6.50% senior notes due September 2021 – $148 million; and


•	6.375% Berry senior notes due September 2022 – $26 million.

In connection with the repurchases, the Company paid approximately $557 million in cash and recorded a gain on extinguishment of debt of approximately $214 million for the nine months ended September 30, 2015.

Notes Covenants

The Second Lien Indenture contains covenants that, among other things, may 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. Historically, to the extent that Berry generated cash in excess of its needs and determined to distribute such amounts to LINN Energy, the indentures governing Berry’s senior notes limited the amount it could distribute to LINN Energy to the amount available under a “restricted payments basket,” and Berry could 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. During the pendency of the bankruptcy proceedings, Berry will not distribute cash to LINN Energy using the restricted payments basket.

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(Unaudited)

The filing of the Bankruptcy Petitions constituted 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

The Company’s filing of the Bankruptcy Petitions described in Note 2 constituted 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 the Company’s Second Lien Notes and senior notes, as well as 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.

Note 7 – 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 period indicated as of September 30, 2016:



	October 1 - December 31, 2016		2017
Natural gas positions:
Fixed price swaps (NYMEX Henry Hub):
Hedged volume (MMMBtu)	33,580		83,950
Average price ($/MMBtu)	$	3.05	$	3.08
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls)	—		730
Average price ($/Bbl)	$	—	$	50.98

In accordance with a Bankruptcy Court order dated August 16, 2016, the Company was authorized to enter into postpetition hedging arrangements. In September 2016, the Company entered into commodity derivative contracts consisting of natural gas swaps for October 2016 through December 2017 and oil swaps for January 2017 through December 2017.

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Also, in May 2016 and July 2016, as a result of the Chapter 11 proceedings, Berry’s counterparties canceled (prior to the contract settlement dates) all of Berry’s then-outstanding derivative contracts for net proceeds of approximately $2 million. The net proceeds were used to make permanent repayments of a portion of the borrowings outstanding under the Berry Credit Facility.

Excluding settlements on canceled derivatives, the Company had no settlements on commodity derivatives for the three months ended September 30, 2016. Settled derivatives on natural gas production for the nine months ended September 30, 2016, included volumes of 77,734 MMMBtu at an average contract price of $4.50 per MMBtu. Settled derivatives on oil production for the nine months ended September 30, 2016, included volumes of 4,331 MBbls at an average contract price of $90.44 per Bbl. Settled derivatives on natural gas production for the three months and nine months ended September 30, 2015, included volumes of 47,864 MMMBtu and 142,031 MMMBtu, respectively, at an average contract price of $5.12 per MMBtu. Settled derivatives on oil production for the three months and nine months ended September 30, 2015, included volumes of 5,060 MBbls and 13,855 MBbls, respectively, at average contract prices of $87.53 per Bbl and $89.86 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:



	September 30, 2016		December 31, 2015
	(in thousands)
Assets:
Commodity derivatives	$	6,451	$	1,812,375
Liabilities:
Commodity derivatives	$	7,979	$	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. 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. While the Company is in bankruptcy, the Bankruptcy Court’s hedging order governs the provision of collateral securing any commodity derivatives.

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 $6 million at September 30, 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.

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(Unaudited)

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 September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(in thousands)

Gains (losses) on oil and natural gas derivatives	$	274		$	549,029		$	(72,533	)	$	782,622
Lease operating expenses ⁽¹⁾	(200		)	(162		)	(4,605		)	2,898
Total gains (losses) on oil and natural gas derivatives	$	74		$	548,867		$	(77,138	)	$	785,520


⁽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 and nine months ended September 30, 2016, the Company received net cash settlements of approximately $93,000 and $867 million, respectively. In addition, during the nine months ended September 30, 2016, approximately $841 million in settlements (primarily in connection with the April 2016 and May 2016 commodity derivative cancellations) were paid directly by the counterparties to the lenders under the LINN Credit Facility as repayments of a portion of the borrowings outstanding. For the three months and nine months ended September 30, 2015, the Company received net cash settlements of approximately $292 million and $858 million, respectively.

Note 8 – 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:



	September 30, 2016
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	6,451	$	(5,004	)	$	1,447
Liabilities:
Commodity derivatives	$	7,979	$	(5,004	)	$	2,975

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	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.

Note 9 – 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; and (iv) a credit-adjusted risk-free interest 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.

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	449
Current year accretion expense	23,199
Settlements	(7,862		)
Revision of estimates	356
Asset retirement obligations at September 30, 2016	$	539,683

Note 10 – Commitments and Contingencies

For certain statewide class action royalty payment disputes, the Company filed notices advising that it had filed for bankruptcy protection and seeking a stay, which was granted. 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 nine months ended September 30, 2016, and September 30, 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.

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confirmed, will provide for the treatment of claims against the Company’s bankruptcy estates, including prepetition liabilities that have not otherwise been satisfied or addressed during the Chapter 11 proceedings. See Note 2 for additional information.

Note 11 – 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 September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(in thousands, except per unit data)

Net loss	$	(198,365	)	$	(1,569,317	)	$	(1,337,619	)	$	(2,287,604	)
Allocated to participating securities	—			—			—			(3,081		)
	$	(198,365	)	$	(1,569,317	)	$	(1,337,619	)	$	(2,290,685	)

Basic net loss per unit	$	(0.56	)	$	(4.47	)	$	(3.79	)	$	(6.72	)
Diluted net loss per unit	$	(0.56	)	$	(4.47	)	$	(3.79	)	$	(6.72	)

Basic weighted average units outstanding	352,792			350,695			352,606			340,831
Dilutive effect of unit equivalents	—			—			—			—
Diluted weighted average units outstanding	352,792			350,695			352,606			340,831

Basic units outstanding excludes the effect of weighted average anti-dilutive unit equivalents related to approximately 1 million unit options and warrants for both the three months and nine months ended September 30, 2016, and approximately 4 million and 5 million unit options and warrants for the three months and nine months ended September 30, 2015, respectively. All equivalent units were antidilutive for both the three months and nine months ended September 30, 2016, and September 30, 2015.

Note 12 – 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.

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(Unaudited)

Note 13 – Supplemental Disclosures to the Condensed Consolidated Statements of Cash Flows

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



	Nine Months Ended September 30,
	2016		2015
	(in thousands)

Cash payments for interest, net of amounts capitalized	$	163,828	$	386,118
Cash payments for income taxes	$	4,774	$	627
Cash payments for reorganization items, net	$	8,866	$	—

Noncash investing activities:
Accrued capital expenditures	$	26,792	$	98,404

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 September 30, 2016, and December 31, 2015, “restricted cash” on the condensed consolidated balance sheets includes approximately $197 million and $250 million, respectively, related to the $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 $8 million and $7 million at September 30, 2016, and December 31, 2015, respectively, of cash deposited by the Company into a separate account designated for asset retirement obligations in accordance with contractual agreements.

During the nine months ended September 30, 2016, approximately $841 million in commodity derivative settlements (primarily in connection with the April 2016 and May 2016 commodity derivative cancellations) were paid directly by the counterparties to the lenders under the LINN Credit Facility as repayments of a portion of the borrowings outstanding, and are reflected as noncash transactions by the Company. In addition, during the three months and nine months ended September 30, 2016, approximately $16 million and $20 million, respectively, in letters of credit draws were made from the Berry Credit Facility as requested by certain vendors owed prepetition amounts from the Company.

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 September 30, 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.

Note 14 – 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 September 30, 2016, LinnCo had no significant assets or operations other than those related to its interest in LINN Energy and owned approximately 71% 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. The initial offer expired on April 25, 2016, and on April 26, 2016, LinnCo commenced a subsequent offering period that expired on August 1, 2016. During the exchange period, 123,100,715 LINN Energy units were exchanged for an equal number of LinnCo shares. As a result of the exchanges of LINN Energy units for LinnCo shares, LinnCo’s

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ownership of LINN Energy’s outstanding units increased from approximately 37% at December 31, 2015, to approximately 71% at September 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 and nine months ended September 30, 2016, LinnCo incurred total general and administrative expenses, reorganization expenses and offering costs of approximately $1.0 million and $5.2 million, respectively, including approximately $603,000 and $1.8 million, respectively, related to services provided by LINN Energy. Of the expenses and costs incurred during the nine months ended September 30, 2016, approximately $5.1 million had been paid by LINN Energy on LinnCo’s behalf as of September 30, 2016.

For the three months and nine months ended September 30, 2015, LinnCo incurred total general and administrative expenses and certain offering costs of approximately $965,000 and $2.8 million, respectively, including approximately $491,000 and $1.5 million, respectively, related to services provided by LINN Energy. All of the expenses and costs incurred during the nine months ended September 30, 2015, had been paid by LINN Energy on LinnCo’s behalf as of September 30, 2015.

The Company did not pay any distributions to LinnCo during the three months or nine months ended September 30, 2016. During the three months and nine months ended September 30, 2015, the Company paid approximately $41 million and $121 million, respectively, in distributions to LinnCo attributable to LinnCo’s interest in LINN Energy.

Other

One of the Company’s directors is the President and Chief Executive Officer of Superior Energy Services, Inc. (“Superior”), which provides oilfield services to the Company. For the three months and nine months ended September 30, 2016, the Company incurred expenditures of approximately $1 million and $4 million, respectively, and for the three months and nine months ended September 30, 2015, the Company incurred expenditures of approximately $2 million and $7 million, respectively, related to services rendered by Superior and its subsidiaries.

Note 15 – 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.

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(Unaudited)

CONDENSED CONSOLIDATING BALANCE SHEETS

September 30, 2016



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	311,180		$	459,680		$	29,647		$	—		$	800,507
Accounts receivable – trade, net	—			165,650			47,458			—			213,108
Accounts receivable – affiliates	1,785,051			35,567			—			(1,820,618		)	—
Derivative instruments	—			1,447			—			—			1,447
Other current assets	18,677			82,864			19,551			—			121,092
Total current assets	2,114,908			745,208			96,656			(1,820,618		)	1,136,154

Noncurrent assets:
Oil and natural gas properties (successful efforts method)	—			13,171,180			5,022,076			—			18,193,256
Less accumulated depletion and amortization	—			(9,992,670		)	(2,755,015		)	70,713			(12,676,972		)
	—			3,178,510			2,267,061			70,713			5,516,284

Other property and equipment	—			621,947			120,317			—			742,264
Less accumulated depreciation	—			(213,586		)	(18,659		)	—			(232,245		)
	—			408,361			101,658			—			510,019

Restricted cash	—			7,580			197,624			—			205,204
Notes receivable – affiliates	137,400			—			—			(137,400		)	—
Investments in consolidated subsidiaries	2,263,182			—			—			(2,263,182		)	—
Other noncurrent assets	—			17,102			18,257			(72		)	35,287
	2,400,582			24,682			215,881			(2,400,654		)	240,491
Total noncurrent assets	2,400,582			3,611,553			2,584,600			(2,329,941		)	6,266,794
Total assets	$	4,515,490		$	4,356,761		$	2,681,256		$	(4,150,559	)	$	7,402,948

LIABILITIES AND UNITHOLDERS’ CAPITAL (DEFICIT)
Current liabilities:
Accounts payable and accrued expenses	$	—		$	293,729		$	69,274		$	—		$	363,003
Accounts payable – affiliates	—			1,785,051			35,567			(1,820,618		)	—
Derivative instruments	—			82			1,694			—			1,776
Current portion of long-term debt, net	1,937,589			—			891,259			—			2,828,848
Other accrued liabilities	374			43,426			2,499			—			46,299
Total current liabilities	1,937,963			2,122,288			1,000,293			(1,820,618		)	3,239,926

Derivative instruments	—			1,199			—			—			1,199
Notes payable – affiliates	—			137,400			—			(137,400		)	—
Other noncurrent liabilities	—			396,772			174,423			(72		)	571,123
Liabilities subject to compromise	4,168,822			67,439			936,798			—			5,173,059

Unitholders’ capital (deficit):
Units issued and outstanding	5,358,341			4,831,412			2,798,713			(7,621,189		)	5,367,277
Accumulated deficit	(6,949,636		)	(3,199,749		)	(2,228,971		)	5,428,720			(6,949,636		)
	(1,591,295		)	1,631,663			569,742			(2,192,469		)	(1,582,359		)
Total liabilities and unitholders’ capital (deficit)	$	4,515,490		$	4,356,761		$	2,681,256		$	(4,150,559	)	$	7,402,948

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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

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

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

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Three Months Ended September 30, 2016



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	257,902		$	102,241		$	—		$	360,143
Gains on oil and natural gas derivatives	—			166			108			—			274
Marketing revenues	—			9,249			9,103			—			18,352
Other revenues	—			5,123			1,773			—			6,896
	—			272,440			113,225			—			385,665
Expenses:
Lease operating expenses	—			71,422			46,048			—			117,470
Transportation expenses	—			40,986			8,644			—			49,630
Marketing expenses	—			6,933			5,258			—			12,191
General and administrative expenses	—			34,809			15,393			—			50,202
Exploration costs	—			4			—			—			4
Depreciation, depletion and amortization	—			105,304			39,951			(2,807		)	142,448
Impairment of long-lived assets	—			41,728			—			—			41,728
Taxes, other than income taxes	2			19,075			(3,694		)	—			15,383
(Gains) losses on sale of assets and other, net	—			2,310			(370		)	—			1,940
	2			322,571			111,230			(2,807		)	430,996
Other income and (expenses):
Interest expense, net of amounts capitalized	(27,595		)	(95		)	(12,415		)	—			(40,105		)
Interest expense – affiliates	—			(2,479		)	—			2,479			—
Interest income – affiliates	2,479			—			—			(2,479		)	—
Equity in losses from consolidated subsidiaries	(171,817		)	—			—			171,817			—
Other, net	(116		)	(84		)	(69		)	—			(269		)
	(197,049		)	(2,658		)	(12,484		)	171,817			(40,374		)
Reorganization items, net	(1,314		)	(27,047		)	(87,915		)	—			(116,276		)
Loss before income taxes	(198,365		)	(79,836		)	(98,404		)	174,624			(201,981		)
Income tax expense (benefit)	—			(3,650		)	34			—			(3,616		)
Net loss	$	(198,365	)	$	(76,186	)	$	(98,438	)	$	174,624		$	(198,365	)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Three Months Ended September 30, 2015



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	286,993		$	140,252		$	—		$	427,245
Gains on oil and natural gas derivatives	—			521,365			27,664			—			549,029
Marketing revenues	—			6,004			9,719			—			15,723
Other revenues	—			4,635			1,672			—			6,307
	—			818,997			179,307			—			998,304
Expenses:
Lease operating expenses	—			86,745			67,341			—			154,086
Transportation expenses	—			41,121			13,794			—			54,915
Marketing expenses	—			3,633			5,726			—			9,359
General and administrative expenses	—			38,549			21,564			—			60,113
Exploration costs	—			3,072			—			—			3,072
Depreciation, depletion and amortization	—			142,211			63,057			1,950			207,218
Impairment of long-lived assets	—			1,744,449			510,631			—			2,255,080
Taxes, other than income taxes	—			31,718			14,520			—			46,238
(Gains) losses on sale of assets and other, net	—			(169,613		)	2,633			—			(166,980		)
	—			1,921,885			699,266			1,950			2,623,101
Other income and (expenses):
Interest expense, net of amounts capitalized	(117,096		)	197			(21,484		)	—			(138,383		)
Interest expense – affiliates	—			(2,207		)	—			2,207			—
Interest income – affiliates	2,207			—			—			(2,207		)	—
Gain on extinguishment of debt	193,363			—			4,378			—			197,741
Equity in losses from consolidated subsidiaries	(1,646,256		)	—			—			1,646,256			—
Other, net	(1,535		)	(76		)	(90		)	—			(1,701		)
	(1,569,317		)	(2,086		)	(17,196		)	1,646,256			57,657
Loss before income taxes	(1,569,317		)	(1,104,974		)	(537,155		)	1,644,306			(1,567,140		)
Income tax expense	—			2,174			3			—			2,177
Net loss	$	(1,569,317	)	$	(1,107,148	)	$	(537,158	)	$	1,644,306		$	(1,569,317	)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Nine Months Ended September 30, 2016



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	674,177		$	285,538		$	—		$	959,715
Gains (losses) on oil and natural gas derivatives	—			(74,175		)	1,642			—			(72,533		)
Marketing revenues	—			26,861			20,316			—			47,177
Other revenues	—			15,834			5,634			—			21,468
	—			642,697			313,130			—			955,827
Expenses:
Lease operating expenses	—			232,101			138,557			—			370,658
Transportation expenses	—			124,072			32,518			—			156,590
Marketing expenses	—			21,493			14,291			—			35,784
General and administrative expenses	—			131,064			65,313			—			196,377
Exploration costs	—			2,745			—			—			2,745
Depreciation, depletion and amortization	—			318,067			139,980			(8,370		)	449,677
Impairment of long-lived assets	—			171,431			1,030,588			(6,387		)	1,195,632
Taxes, other than income taxes	4			59,679			20,614			—			80,297
(Gains) losses on sale of assets and other, net	—			6,096			(137		)	—			5,959
	4			1,066,748			1,441,724			(14,757		)	2,493,719
Other income and (expenses):
Interest expense, net of amounts capitalized	(165,185		)	146			(48,719		)	—			(213,758		)
Interest expense – affiliates	—			(8,417		)	—			8,417			—
Interest income – affiliates	8,417			—			—			(8,417		)	—
Equity in losses from consolidated subsidiaries	(1,677,262		)	—			—			1,677,262			—
Other, net	(1,358		)	—			(79		)	—			(1,437		)
	(1,835,388		)	(8,271		)	(48,798		)	1,677,262			(215,195		)
Reorganization items, net	497,773			(40,336		)	(38,829		)	—			418,608
Loss before income taxes	(1,337,619		)	(472,658		)	(1,216,221		)	1,692,019			(1,334,479		)
Income tax expense	—			2,944			196			—			3,140
Net loss	$	(1,337,619	)	$	(475,602	)	$	(1,216,417	)	$	1,692,019		$	(1,337,619	)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS

For the Nine Months Ended September 30, 2015



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	—		$	904,014		$	470,219		$	—		$	1,374,233
Gains on oil and natural gas derivatives	—			756,165			26,457			—			782,622
Marketing revenues	—			35,501			24,699			—			60,200
Other revenues	—			14,521			5,103			—			19,624
	—			1,710,201			526,478			—			2,236,679
Expenses:
Lease operating expenses	—			283,333			184,426			—			467,759
Transportation expenses	—			124,872			39,378			—			164,250
Marketing expenses	—			29,990			17,369			—			47,359
General and administrative expenses	—			157,878			79,853			—			237,731
Exploration costs	—			4,032			—			—			4,032
Depreciation, depletion and amortization	—			433,649			199,088			5,227			637,964
Impairment of long-lived assets	—			2,069,866			782,631			(64,800		)	2,787,697
Taxes, other than income taxes	2			98,267			60,048			—			158,317
Gains on sale of assets and other, net	—			(194,612		)	(2,651		)	—			(197,263		)
	2			3,007,275			1,360,142			(59,573		)	4,307,846
Other income and (expenses):
Interest expense, net of amounts capitalized	(364,037		)	2,048			(65,595		)	—			(427,584		)
Interest expense – affiliates	—			(7,824		)	—			7,824			—
Interest income – affiliates	7,824			—			—			(7,824		)	—
Gain on extinguishment of debt	202,318			—			11,209			—			213,527
Equity in losses from consolidated subsidiaries	(2,124,493		)	—			—			2,124,493			—
Other, net	(9,214		)	(123		)	(723		)	—			(10,060		)
	(2,287,602		)	(5,899		)	(55,109		)	2,124,493			(224,117		)
Loss before income taxes	(2,287,604		)	(1,302,973		)	(888,773		)	2,184,066			(2,295,284		)
Income tax benefit	—			(7,622		)	(58		)	—			(7,680		)
Net loss	$	(2,287,604	)	$	(1,295,351	)	$	(888,715	)	$	2,184,066		$	(2,287,604	)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Nine Months Ended September 30, 2016



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Cash flow from operating activities:
Net loss	$	(1,337,619	)	$	(475,602	)	$	(1,216,417	)	$	1,692,019		$	(1,337,619	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	—			318,067			139,980			(8,370		)	449,677
Impairment of long-lived assets	—			171,431			1,030,588			(6,387		)	1,195,632
Unit-based compensation expenses	—			24,514			—			—			24,514
Amortization and write-off of deferred financing fees	11,288			—			1,226			—			12,514
(Gains) losses on sale of assets and other, net	—			5,534			(874		)	—			4,660
Equity in losses from consolidated subsidiaries	1,677,262			—			—			(1,677,262		)	—
Deferred income taxes	—			831			71			—			902
Reorganization items	(497,446		)	11,615			22,866			—			(462,965		)
Derivatives activities:
Total losses	—			74,175			2,963			—			77,138
Cash settlements	—			500,075			8,007			—			508,082
Cash settlements on canceled derivatives	—			356,835			1,701			—			358,536
Changes in assets and liabilities:
Increase in accounts receivable – trade, net	—			(911		)	(2,839		)	—			(3,750		)
(Increase) decrease in accounts receivable – affiliates	323,348			(26,946		)	—			(296,402		)	—
Increase in other assets	—			(17,111		)	(3,175		)	—			(20,286		)
Increase (decrease) in accounts payable and accrued expenses	(36		)	64,288			(9,080		)	—			55,172
Increase (decrease) in accounts payable and accrued expenses – affiliates	—			(323,348		)	26,946			296,402			—
Increase (decrease) in other liabilities	37,374			(15,695		)	1,306			—			22,985
Net cash provided by operating activities	214,171			667,752			3,269			—			885,192
Cash flow from investing activities:
Development of oil and natural gas properties	—			(126,228		)	(16,168		)	—			(142,396		)
Purchases of other property and equipment	—			(26,570		)	(10,366		)	—			(36,936		)
Decrease in restricted cash	—			—			53,418			—			53,418
Change in notes receivable with affiliate	37,700			—			—			(37,700		)	—
Proceeds from sale of properties and equipment and other	(5,114		)	1,793			172			—			(3,149		)
Net cash provided by (used in) investing activities	32,586			(151,005		)	27,056			(37,700		)	(129,063		)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)



	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	(913,210		)	—			(1,701		)	—		(914,911		)
Financing fees and offering costs	(692		)	—			—			—		(692		)
Change in notes payable with affiliate	—			(37,700		)	—			37,700		—
Other	(1,248		)	(19,439		)	—			—		(20,687		)
Net cash provided by (used in) financing activities	63,350			(57,139		)	(1,701		)	37,700		42,210

Net increase in cash and cash equivalents	310,107			459,608			28,624			—		798,339
Cash and cash equivalents:
Beginning	1,073			72			1,023			—		2,168
Ending	$	311,180		$	459,680		$	29,647		$	—	$	800,507

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS

For the Nine Months Ended September 30, 2015



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Cash flow from operating activities:
Net loss	$	(2,287,604	)	$	(1,295,351	)	$	(888,715	)	$	2,184,066		$	(2,287,604	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	—			433,649			199,088			5,227			637,964
Impairment of long-lived assets	—			2,069,866			782,631			(64,800		)	2,787,697
Unit-based compensation expenses	—			47,918			—			—			47,918
Gain on extinguishment of debt	(202,318		)	—			(11,209		)	—			(213,527		)
Amortization and write-off of deferred financing fees	22,677			—			1,121			—			23,798
Gains on sale of assets and other, net	—			(192,247		)	(1,521		)	—			(193,768		)
Equity in losses from consolidated subsidiaries	2,124,493			—			—			(2,124,493		)	—
Deferred income taxes	—			(8,205		)	(58		)	—			(8,263		)
Derivatives activities:
Total gains	—			(756,165		)	(29,355		)	—			(785,520		)
Cash settlements	—			810,314			48,054			—			858,368
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net	—			163,353			43,709			—			207,062
Decrease in accounts receivable – affiliates	813,653			6,876			—			(820,529		)	—
Decrease in other assets	—			1,164			1,519			—			2,683
Decrease in accounts payable and accrued expenses	—			(28,331		)	(8,295		)	—			(36,626		)
Decrease in accounts payable and accrued expenses – affiliates	—			(813,653		)	(6,876		)	820,529			—
Increase (decrease) in other liabilities	27,462			(12,086		)	(20,789		)	—			(5,413		)
Net cash provided by operating activities	498,363			427,102			109,304			—			1,034,769
Cash flow from investing activities:
Development of oil and natural gas properties	—			(500,130		)	(3,076		)	—			(503,206		)
Purchases of other property and equipment	—			(38,769		)	(12,760		)	—			(51,529		)
Investment in affiliates	(91,455		)	—			—			91,455			—
Change in notes receivable with affiliate	(50,900		)	—			—			50,900			—
Settlement of advance to affiliate	—			—			129,217			(129,217		)	—
Proceeds from sale of properties and equipment and other	(2,826		)	344,535			22,486			—			364,195
Net cash provided by (used in) investing activities	(145,181		)	(194,364		)	135,867			13,138			(190,540		)

Table of Contents

LINN ENERGY, LLC (DEBTOR-IN-POSSESSION)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)



	Linn Energy, LLC			Guarantor Subsidiaries			Non- Guarantor Subsidiary			Eliminations			Consolidated
	(in thousands)
Cash flow from financing activities:
Proceeds from sale of units	233,427			—			—			—			233,427
Proceeds from borrowings	1,405,000			—			—			—			1,405,000
Repayments of debt	(1,646,491		)	—			(55,418		)	—			(1,701,909		)
Distributions to unitholders	(323,878		)	—			—			—			(323,878		)
Financing fees and offering costs	(8,771		)	—			(3		)	—			(8,774		)
Change in notes payable with affiliate	—			50,900			—			(50,900		)	—
Settlement of advance from affiliate	—			(129,217		)	—			129,217			—
Capital contributions – affiliates	—			—			91,455			(91,455		)	—
Excess tax benefit from unit-based compensation	(9,467		)	—			—			—			(9,467		)
Other	(3,008		)	(92,637		)	14			—			(95,631		)
Net cash provided by (used in) financing activities	(353,188		)	(170,954		)	36,048			(13,138		)	(501,232		)

Net increase (decrease) in cash and cash equivalents	(6		)	61,784			281,219			—			342,997
Cash and cash equivalents:
Beginning	38			185			1,586			—			1,809
Ending	$	32		$	61,969		$	282,805		$	—		$	344,806

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with the financial statements and related notes included in this Quarterly Report on Form 10-Q and in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. The following discussion contains forward-looking statements based on expectations, estimates and assumptions. Actual results may differ materially from those discussed in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, market prices for oil, natural gas and NGL, production volumes, estimates of proved reserves, capital expenditures, economic and competitive conditions, credit and capital market conditions, regulatory changes and other uncertainties, as well as those factors set forth in “Cautionary Statement Regarding Forward-Looking Statements” below and in Item 1A. “Risk Factors” in this Quarterly Report on Form 10-Q and in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015, and elsewhere in the Annual Report.

When referring to Linn Energy, LLC (“LINN Energy” or the “Company”), the intent is to refer to LINN Energy and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. 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 reference to a “Note” herein refers to the accompanying Notes to Condensed Consolidated Financial Statements contained in Item 1. “Financial Statements.”

Executive Overview

LINN Energy’s mission is to acquire, develop and maximize cash flow from a growing portfolio of long-life oil and natural gas assets. LINN Energy is an independent oil and natural gas company that began operations in March 2003 and completed its initial public offering in January 2006. The Company’s properties are located in eight operating regions in the United States (“U.S.”):


•	Rockies, which includes properties located in Wyoming (Green River, Washakie and Powder River basins), Utah (Uinta Basin), North Dakota (Williston Basin) and Colorado (Piceance Basin);


•	Hugoton Basin, which includes properties located in Kansas, the Oklahoma Panhandle and the Shallow Texas Panhandle;


•	California, which includes properties located in the San Joaquin Valley and Los Angeles basins;


•	Mid-Continent, which includes Oklahoma properties located in the Anadarko and Arkoma basins, as well as waterfloods in the Central Oklahoma Platform;


•	TexLa, which includes properties located in east Texas and north Louisiana;


•	Permian Basin, which includes properties located in west Texas and southeast New Mexico;


•	Michigan/Illinois, which includes properties located in the Antrim Shale formation in north Michigan and oil properties in south Illinois; and


•	South Texas.

Results for the three months ended September 30, 2016, included the following:


•	oil, natural gas and NGL sales of approximately $360 million compared to $427 million for the three months ended September 30, 2015;


•	average daily production of approximately 1,075 MMcfe/d compared to 1,198 MMcfe/d for the three months ended September 30, 2015;


•	net loss of approximately $198 million compared to $1.6 billion for the three months ended September 30, 2015;


•	capital expenditures of approximately $49 million compared to $113 million for the three months ended September 30, 2015; and


•	46 wells drilled (all successful) compared to 41 wells drilled (38 successful) for the three months ended September 30, 2015.

Results for the nine months ended September 30, 2016, included the following:


•	oil, natural gas and NGL sales of approximately $960 million compared to $1.4 billion for the nine months ended September 30, 2015;

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued


•	average daily production of approximately 1,089 MMcfe/d compared to 1,206 MMcfe/d for the nine months ended September 30, 2015;


•	net loss of approximately $1.3 billion compared to $2.3 billion for the nine months ended September 30, 2015;


•	net cash provided by operating activities of approximately $885 million compared to $1.0 billion for the nine months ended September 30, 2015;


•	capital expenditures of approximately $115 million compared to $424 million for the nine months ended September 30, 2015; and


•	158 wells drilled (157 successful) compared to 311 wells drilled (308 successful) for the nine months ended September 30, 2015.

Chapter 11 Proceedings

On May 11, 2016 (the “Petition Date”), the Company, certain of the Company’s direct and indirect subsidiaries, and LinnCo (collectively with the Company, the “LINN Debtors”) and Berry (collectively with the LINN Debtors, the “Debtors”), filed voluntary petitions (“Bankruptcy Petitions”) for relief 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’ Chapter 11 cases are being administered jointly under the caption In re Linn Energy, LLC., et al., Case No. 16‑60040.

Bank RSA

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

occurred within 250 days of the Petition Date. There can be no assurance that the restructuring transactions contemplated by the Bank RSA will be consummated.

Restructuring Support Agreement

The LINN RSA sets forth, subject to certain conditions, the commitment of the LINN Debtors and the Consenting LINN Creditors to support a comprehensive restructuring of the LINN Debtors’ long-term debt (the “Restructuring”). On October 21, 2016, the Debtors filed a proposed Plan with the Bankruptcy Court. See “Process for Plan of Reorganization” below for certain principal terms of the proposed Plan.

The LINN RSA obligates the LINN Debtors and the Consenting LINN Creditors to, among other things, support and not interfere with consummation of the Restructuring and, as to the Consenting LINN Creditors, vote their claims in favor of the Plan. The LINN RSA 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, and in the event of certain breaches by the parties under the LINN RSA. The LINN RSA is subject to termination if the effective date of the Plan has not occurred by March 1, 2017. There can be no assurance that the Restructuring will be consummated.

Backstop Commitment Agreement

In connection with the proposed Plan, on October 25, 2016, the Company entered into a backstop commitment agreement (“Backstop Commitment Agreement”) with the parties thereto (collectively, the “Backstop Parties”), pursuant to which the Backstop Parties, which are also Consenting Noteholders under the LINN RSA, have agreed to backstop a $530 million new money investment in the LINN Debtors pursuant to the rights offerings to be conducted in accordance with the Plan.

In accordance with the Plan, the Backstop Commitment Agreement and the rights offerings procedures filed in the Chapter 11 cases, the LINN Debtors will offer eligible creditors, including the Backstop Parties, the right to purchase new common stock or limited liability company interests in the reorganized Company (“New Common Stock”) upon emergence from the Chapter 11 cases for an aggregate purchase price of $530 million. The rights offerings will consist of the following offerings:

•

Holders of Unsecured Notes as of the record date set therefor shall be granted rights entitling each such holder to subscribe to the rights offering in an amount up to its pro rata share of New Common Stock (the “Unsecured Rights Offering,” and such New Common Stock offered for purchase thereunder, the “Unsecured Rights Offering Shares”), which Unsecured Rights Offering Shares, collectively, will reflect an aggregate purchase price of $319,004,408 at the per share price set forth in the Backstop Commitment Agreement.

•

Holders of Second Lien Notes as of the record date set therefor shall be granted rights entitling each such holder to subscribe to the rights offering in an amount up to its pro rata share of New Common Stock (the “Secured Rights Offering,” and such New Common Stock offered for purchase thereunder, the “Secured Rights Offering Shares”), which Secured Rights Offering Shares, collectively, will reflect an aggregate purchase price of $210,995,592 at the per share price set forth in the Backstop Commitment Agreement.

Under the Backstop Commitment Agreement, certain Backstop Parties have agreed to purchase their pro rata share of the Unsecured Rights Offering Shares and the Secured Rights Offering Shares, as applicable, that are not duly subscribed to

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

pursuant to the Unsecured Rights Offering or the Secured Rights Offering, as applicable, at the discounted per share price set forth in the Backstop Commitment by parties other than Backstop Parties (the “Backstop Commitment”).

Subject to Bankruptcy Court approval, the LINN Debtors will pay the Backstop Parties on the Plan effective date a commitment premium equal to 4.0% of the $530 million committed amount (the “Backstop Commitment Premium”), of which 3.0% will be paid in cash and 1.0% will be paid in the form of New Common Stock at the discounted per share price set forth in the Backstop Commitment Agreement. The Backstop Commitment Premium shall be fully earned and nonrefundable as of the date of the Bankruptcy Court order approving the LINN Debtors’ entry into the Backstop Commitment Agreement. All amounts payable to the Backstop Parties in their capacities as such for the Backstop Commitment Premium shall be paid pro rata based on the amount of their respective Backstop Commitments on the effective date (as compared to the aggregate Backstop Commitment of all Backstop Parties).

The rights to purchase New Common Stock in the rights offerings, any shares issued upon exercise thereof, and all shares issued to the Backstop Parties in respect of their Backstop Commitments pursuant to the Backstop Commitment Premium, will be issued in reliance upon the exemption from the registration requirements of the securities laws pursuant to Section 1145 of the Bankruptcy Code. All shares issued to the Backstop Parties pursuant to the Backstop Commitment Agreement in respect of their Backstop Commitment will be issued in reliance upon the exemption from registration under the Securities Act of 1933, as amended (the “Securities Act”), provided by Section 4(a)(2) thereof and/or Regulation D thereunder. As a condition to the closing of the transactions contemplated by the Backstop Commitment Agreement, the Company will enter into a registration rights agreement with the certain Backstop Parties entitling such Backstop Parties to request that the Company register their securities for sale under the Securities Act at various times.

The Backstop Parties’ commitments to backstop the rights offerings, and the other transactions contemplated by the Backstop Commitment Agreement, are conditioned upon the satisfaction of all conditions to the effectiveness of the Plan and other applicable conditions precedent set forth in the Backstop Commitment Agreement. The issuances of New Common Stock pursuant to the rights offerings and the Backstop Commitment Agreement are conditioned upon, among other things, confirmation of the Plan by the Bankruptcy Court, and the Plan’s effectiveness upon the Company’s emergence from its Chapter 11 cases.

Magnitude of Potential Claims

Rejection of Executory Contracts

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Effect of Filing on Creditors and Unitholders

Process for Plan of Reorganization

On October 21, 2016, the Debtors filed a proposed Plan with the Bankruptcy Court. Certain principal terms of the proposed Plan, as filed on October 21, 2016, with respect to the LINN Debtors include:


•	One or more new legal entities, in a to-be-determined form, will be formed to directly or indirectly hold all of the assets of the LINN Debtors. Following the Restructuring, the LINN Debtors will be standalone companies, separate from Berry.


•	The holders of claims under the LINN Credit Facility will receive their pro rata share of $1.7 billion reserve-based revolving and term loan credit facilities, as described further below (the “New LINN Exit Facility”), and a cash paydown in an amount that has yet to be determined.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

•

The Second Lien Notes will be allowed in the aggregate as a $2.0 billion unsecured claim (plus accrued and unpaid interest and reasonable and documented fees and expenses), and the holders of the Second Lien Notes will receive their pro rata share of (i) a to-be-determined percentage of New Common Stock; (ii) certain rights to purchase shares of New Common Stock in the rights offering, as described above; and (iii) $30 million in cash to the extent such holders vote their Second Lien Notes claims to accept the Plan.


•	The holders of the Company’s Unsecured Notes will receive their pro rata share of (i) a to-be-determined percentage of New Common Stock; and (ii) certain rights to purchase shares of New Common Stock in the rights offering.

•

The holders of unsecured claims against the Company other than the Unsecured Notes will receive their pro rata share of (i) a to-be-determined percentage of New Common Stock; and (ii) certain rights to purchase shares of New Common Stock, at the same price per share as in the rights offerings, to be issued separate from the rights offerings. Such holders of unsecured claims less than a to-be-determined amount are expected to have the right to elect to receive, in lieu of New Common Stock and rights to purchase shares of New Common Stock, cash in an amount equal to a to-be-determined percentage of such holder’s allowed unsecured claim.


•	Cash recoveries will be funded with the proceeds of $530 million from the rights offerings of New Common Stock, which will be fully committed to be backstopped by certain of the Consenting Noteholders, as described above.


•	The board of directors shall consist of seven directors, who shall include: (i) the chief executive officer of the Company, (ii) one director selected by the Company and (iii) five directors selected by a selection committee.


•	All existing equity interests of the Company will be extinguished without recovery.

The Plan contemplates a New LINN Exit Facility consisting of (i) a term loan in the amount of $300 million (the “New LINN Term Loan”) and (ii) a revolving loan in the initial amount of $1.4 billion (the “New LINN Revolving Loan”). The New LINN Term Loan will mature on the earlier of June 30, 2021, or the day prior to the fourth anniversary of the date of emergence from bankruptcy (the “Closing Date”), with interest payable at LIBOR plus 7.50% and amortized principal payments payable quarterly, beginning March 31, 2017. The New LINN Revolving Loan will be composed of two tranches as follows: (a) a conforming tranche with an initial amount of $1.4 billion subject to the borrowing base (the “Conforming Tranche”), and (b) a non-conforming tranche with an initial amount of $0 (the “Non-Conforming Tranche”). The Conforming Tranche will mature on the earlier of (i) June 30, 2021, or (ii) the day prior to the fourth anniversary of the Closing Date, with an interest rate of LIBOR plus 3.50%. The Non-Conforming Tranche will mature on the earlier of (i) December 31, 2020, or (ii) the day prior to the date that is three years and six months after the Closing Date, with an interest rate of LIBOR plus 5.50%. The New LINN Exit Facility will contain a variety of other terms and conditions including annual year-end borrowing base redeterminations beginning April 1, 2018, conditions precedent to funding, financial and other covenants, and certain representations and warranties.

The Plan also provides for the establishment of a customary employee incentive plan at the reorganized Company under which a pool of equity having a value equal to (i) 8% of the equity value of the reorganized LINN Debtors as of the Plan effective date (the “Company Group Emergence Value”) as follows: (A) 2.5% of the Company Group Emergence Value in the form of restricted stock units to be issued at emergence; (B) 1.5% of the Company Group Emergence Value in the form of profits interests that will vest based on time and performance; and (C) the remaining 4% of the Company Group Emergence Value in a form of equity-based awards as determined by the board of directors of the reorganized Company; and (ii) an additional 2.0% of the Company Group Emergence Value, which will be issued at emergence in the form of profits interests that vest once the equity value of the reorganized LINN Debtors (as equitably adjusted for subsequent contributions and distributions) is equal to 1.5 times the Company Group Emergence Value.

Certain principal terms of the proposed Plan, as filed on October 21, 2016, with respect to Berry include:

•

The holders of claims under the Berry Credit Facility will receive a full recovery consisting of one or more of the following: (i) a to-be-determined exit financing facility; (ii) a to-be-determined cash paydown; (iii) a to-be-determined percentage of new common stock or limited liability company interests (“New Berry Common Stock”) in the reorganized Berry or its successor in interest (“New Berry”) up to the value of the collateral securing the Berry Credit Facility claims; and (iv) proceeds of any asset sales solely to the extent such assets are the collateral securing the Berry Credit Facility claims.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued


•	The holders of Berry unsecured notes (the “Berry Unsecured Notes”) will receive one or more of the following: (i) New Berry Common Stock; (ii) rights to purchase New Berry Common Stock or other security in New Berry; and (iii) proceeds of any asset sales, after accounting for proceeds required to satisfy the Berry Credit Facility claims.


•	The holders of unsecured claims against Berry other than the Berry Unsecured Notes will receive one or more of the following: (i) New Berry Common Stock; (ii) rights to purchase New Berry Common Stock or other security in New Berry; and (iii) proceeds of any asset sales, after accounting for proceeds required to satisfy the Berry Credit Facility claims.


•	Berry will settle all intercompany claims against the LINN Debtors pursuant to a settlement to be approved as part of the Plan, which settlement provides that Berry will have a $25 million general unsecured claim against the Company.


•	The governance terms of New Berry, as well as the terms of any employee incentive plan, are to be determined. New Berry will be a standalone company, separate from the Company and the LINN Debtors.


•	All existing equity interests of Berry and Linn Acquisition Company, LLC will be extinguished without recovery.

There can be no assurance at this time that the Debtors will be able to successfully confirm and consummate the Plan.

For the duration of the Company’s Chapter 11 proceedings, the Company’s operations and ability to develop and execute its business plan are subject to the risks and uncertainties associated with the Chapter 11 process as described in Item 1A. “Risk Factors.” As a result of these risks and uncertainties, the number of the Company’s units and unitholders, assets, liabilities, officers and/or directors could be significantly different following the outcome of the Chapter 11 proceedings, and the description of the Company’s operations, properties and capital plans included in this quarterly report may not accurately reflect its operations, properties and capital plans following the Chapter 11 process.

Ability to Continue as a Going Concern

Continued low commodity prices have resulted in significantly lower levels of cash flow from operating activities 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, 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, were expected to adversely impact upcoming redeterminations and have a significant negative impact on the Company’s liquidity. The Company’s filing of the Bankruptcy Petitions constituted an event of default that accelerated the Company’s obligations under its Credit Facilities, its Second Lien Notes and its senior notes.

Covenant Violations

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

defaults, are present, including the failure to make interest payments on the Company’s Second Lien Notes and senior notes, as well as 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

Second Lien Notes

The settlement agreement will terminate upon, among other events, entry by the Bankruptcy Court of a final, non-appealable order denying the Company’s motion seeking entry of the Settlement Order.

The Company failed to make an interest payment on its Second Lien Notes of approximately $68 million due June 15, 2016.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Senior Notes

The Company failed to make interest payments due on its senior notes subsequent to April 14, 2016.

Commodity Derivatives

In October 2016, the Company entered into commodity derivative contracts consisting of oil swaps for November 2016 through December 2017 and natural gas swaps for January 2017 through December 2018. Including these new hedges, as of October 31, 2016, the Company had oil swaps of 610 MBbls at an average price of $50.91 per Bbl for the remainder of 2016 and 2,373 MBbls at an average price of $51.74 per Bbl for 2017, and natural gas swaps of 22,265 MMMBtus at an average price of $3.05 per MMBtu for the remainder of 2016, 113,150 MMMBtus at an average price of $3.14 per MMBtu for 2017 and 14,600 MMMBtus at an average price of $3.01 per MMBtu for 2018.

In September 2016, the Company entered into commodity derivative contracts consisting of natural gas swaps for October 2016 through December 2017 and oil swaps for January 2017 through December 2017.

In April 2016 and May 2016, in connection with the Company’s restructuring efforts, LINN Energy canceled (prior to the contract settlement dates) all of its then-outstanding derivative contracts for net proceeds of approximately $1.2 billion. The net proceeds were used to make permanent repayments of a portion of the borrowings outstanding under the LINN Credit Facility. Also, in May 2016 and July 2016, as a result of the Chapter 11 proceedings, Berry’s counterparties canceled (prior to the contract settlement dates) all of Berry’s then-outstanding derivative contracts for net proceeds of approximately $2 million. The net proceeds were used to make permanent repayments of a portion of the borrowings outstanding under the Berry Credit Facility.

Offer to Exchange LINN Energy Units for LinnCo Shares

2016 Oil and Natural Gas Capital Budget

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

and subject to ongoing adjustments. The Company expects to fund its capital expenditures primarily from net cash provided by operating activities; however, there is uncertainty regarding the Company’s liquidity as discussed above. In addition, at this level of capital spending, the Company expects its total reserves to decline.

Financing Activities

See above for a description of the amendments to the Credit Facilities entered into in April 2016. During the nine months ended September 30, 2016, the Company borrowed approximately $979 million under the LINN Credit Facility and made repayments of approximately $1.8 billion of a portion of the borrowings outstanding under the Credit Facilities and term loan. The repayments include approximately $841 million in commodity derivative settlements paid by the counterparties to the lenders under the LINN Credit Facility. As of September 30, 2016, total borrowings outstanding (including outstanding letters of credit) under the LINN Credit Facility and the Berry Credit Facility were approximately $1.9 billion and $898 million, respectively, with no remaining availability for either.

Delisting from Stock Exchange

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Results of Operations

Three Months Ended September 30, 2016, Compared to Three Months Ended September 30, 2015



	Three Months Ended September 30,
	2016			2015			Variance
	(in thousands)
Revenues and other:
Natural gas sales	$	141,193		$	156,641		$	(15,448	)
Oil sales	179,796			241,467			(61,671		)
NGL sales	39,154			29,137			10,017
Total oil, natural gas and NGL sales	360,143			427,245			(67,102		)
Gains on oil and natural gas derivatives	274			549,029			(548,755		)
Marketing and other revenues	25,248			22,030			3,218
	385,665			998,304			(612,639		)
Expenses:
Lease operating expenses	117,470			154,086			(36,616		)
Transportation expenses	49,630			54,915			(5,285		)
Marketing expenses	12,191			9,359			2,832
General and administrative expenses ⁽¹⁾	50,202			60,113			(9,911		)
Exploration costs	4			3,072			(3,068		)
Depreciation, depletion and amortization	142,448			207,218			(64,770		)
Impairment of long-lived assets	41,728			2,255,080			(2,213,352		)
Taxes, other than income taxes	15,383			46,238			(30,855		)
(Gains) losses on sale of assets and other, net	1,940			(166,980		)	168,920
	430,996			2,623,101			(2,192,105		)
Other income and (expenses)	(40,374		)	57,657			(98,031		)
Reorganization items, net	(116,276		)	—			(116,276		)
Loss before income taxes	(201,981		)	(1,567,140		)	1,365,159
Income tax expense (benefit)	(3,616		)	2,177			(5,793		)
Net loss	$	(198,365	)	$	(1,569,317	)	$	1,370,952


⁽¹⁾	General and administrative expenses for the three months ended September 30, 2016, and September 30, 2015, include approximately $5 million and $13 million, respectively, of noncash unit-based compensation expenses.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued



	Three Months Ended September 30,
	2016		2015		Variance
Average daily production:
Natural gas (MMcf/d)	597		644		(7	)%
Oil (MBbls/d)	49.6		63.1		(21	)%
NGL (MBbls/d)	30.0		29.2		3	%
Total (MMcfe/d)	1,075		1,198		(10	)%

Weighted average prices: ⁽¹⁾
Natural gas (Mcf)	$	2.57	$	2.64	(3	)%
Oil (Bbl)	$	39.37	$	41.58	(5	)%
NGL (Bbl)	$	14.17	$	10.84	31	%

Average NYMEX prices:
Natural gas (MMBtu)	$	2.81	$	2.77	1	%
Oil (Bbl)	$	44.94	$	46.43	(3	)%

Costs per Mcfe of production:
Lease operating expenses	$	1.19	$	1.40	(15	)%
Transportation expenses	$	0.50	$	0.50	—
General and administrative expenses ⁽²⁾	$	0.51	$	0.55	(7	)%
Depreciation, depletion and amortization	$	1.44	$	1.88	(23	)%
Taxes, other than income taxes	$	0.16	$	0.42	(62	)%


⁽¹⁾	Does not include the effect of gains (losses) on derivatives.


⁽²⁾	General and administrative expenses for the three months ended September 30, 2016, and September 30, 2015, include approximately $5 million and $13 million, respectively, of noncash unit-based compensation expenses.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Revenues and Other

Oil, Natural Gas and NGL Sales

Oil, natural gas and NGL sales decreased by approximately $67 million or 16% to approximately $360 million for the three months ended September 30, 2016, from approximately $427 million for the three months ended September 30, 2015, due to lower oil and natural gas prices and lower production volumes, partially offset by higher NGL prices. Lower oil and natural gas prices resulted in a decrease in revenues of approximately $10 million and $4 million, respectively. Higher NGL prices resulted in an increase in revenues of approximately $9 million.

Average daily production volumes decreased to approximately 1,075 MMcfe/d for the three months ended September 30, 2016, from 1,198 MMcfe/d for the three months ended September 30, 2015. Lower oil and natural gas production volumes resulted in a decrease in revenues of approximately $52 million and $11 million, respectively. Higher NGL production volumes resulted in an increase in revenues of approximately $1 million.

The following table sets forth average daily production by region:



	Three Months Ended September 30,
	2016	2015	Variance
Average daily production (MMcfe/d):
Rockies	396	429	(33	)	(8	)%
Hugoton Basin	236	254	(18	)	(7	)%
California	148	183	(35	)	(19	)%
Mid-Continent	102	105	(3	)	(2	)%
TexLa	80	87	(7	)	(8	)%
Permian Basin	54	77	(23	)	(30	)%
Michigan/Illinois	30	31	(1	)	(2	)%
South Texas	29	32	(3	)	(9	)%
	1,075	1,198	(123	)	(10	)%

The decreases in average daily production volumes primarily reflect lower production volumes as a result of reduced development capital spending throughout the Company’s various operating regions, as well as marginal well shut-ins, driven by continued low commodity prices. The decrease in average daily production volumes in California also reflects operational challenges in the Company’s Diatomite development program, where the Company is pursuing various remedies to address wells performance and has temporarily curtailed capital spending in this program. The decrease in average daily production volumes in the Permian Basin region also reflects lower production volumes as a result of the Howard County assets sale on August 31, 2015.

Gains on Oil and Natural Gas Derivatives

Gains on oil and natural gas derivatives were approximately $274,000 and $549 million for the three months ended September 30, 2016, and September 30, 2015, respectively, representing a decrease of approximately $549 million. Gains on oil and natural gas derivatives were primarily due to changes in fair value of the derivative contracts. The fair value on unsettled derivative contracts changes as future commodity price expectations change compared to the contract prices on the derivatives. If the expected future commodity prices increase compared to the contract prices on the derivatives, losses are recognized; and if the expected future commodity prices decrease compared to the contract prices on the derivatives, gains are recognized.

See above under “Executive Overview” for details about the Company’s commodity derivatives cancellations in 2016.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

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. See Item 3. “Quantitative and Qualitative Disclosures About Market Risk” and Note 7 and Note 8 for additional details about the Company’s commodity derivatives. For information about the Company’s credit risk related to derivative contracts, see “Counterparty Credit Risk” under “Liquidity and Capital Resources” below.

Marketing and Other Revenues

Marketing revenues represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing and other revenues increased by approximately $3 million or 15% to approximately $25 million for the three months ended September 30, 2016, from approximately $22 million for the three months ended September 30, 2015. The increase was primarily due to higher revenues generated by the Jayhawk natural gas processing plant in Kansas and higher helium sales revenue in the Hugoton Basin, partially offset by lower electricity sales revenues generated by the Company’s California cogeneration facilities.

Expenses

Lease Operating Expenses

Lease operating expenses include expenses such as labor, field office, vehicle, supervision, maintenance, tools and supplies, and workover expenses. Lease operating expenses decreased by approximately $37 million or 24% to approximately $117 million for the three months ended September 30, 2016, from approximately $154 million for the three months ended September 30, 2015. The decrease was primarily due to cost savings initiatives and lower workover activities, as well as a decrease in steam costs caused by a decrease in steam injection volumes. Lease operating expenses per Mcfe also decreased to $1.19 per Mcfe for the three months ended September 30, 2016, from $1.40 per Mcfe for the three months ended September 30, 2015.

Transportation Expenses

Transportation expenses decreased by approximately $5 million or 10% to approximately $50 million for the three months ended September 30, 2016, from approximately $55 million for the three months ended September 30, 2015. The decrease was primarily due to reduced costs as a result of certain contracts terminated in the Chapter 11 proceedings and lower production volumes, partially offset by higher costs from nonoperated properties in the Rockies region. Transportation expenses per Mcfe remained consistent at $0.50 per Mcfe for both the three months ended September 30, 2016, and September 30, 2015.

Marketing Expenses

Marketing expenses represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing expenses increased by approximately $3 million or 30% to approximately $12 million for the three months ended September 30, 2016, from approximately $9 million for the three months ended September 30, 2015. The increase was primarily due to higher expenses associated with the Jayhawk natural gas processing plant in Kansas.

General and Administrative Expenses

General and administrative expenses are costs not directly associated with field operations and reflect the costs of employees including executive officers, related benefits, office leases and professional fees. General and administrative expenses decreased by approximately $10 million or 16% to approximately $50 million for the three months ended September 30, 2016, from approximately $60 million for the three months ended September 30, 2015. The decrease was primarily due to lower salaries and benefits related expenses, lower professional services expenses and lower acquisition expenses. General and administrative expenses per Mcfe also decreased to $0.51 per Mcfe for the three months ended September 30, 2016, from $0.55 per Mcfe for the three months ended September 30, 2015.

Professional services expenses of approximately $26 million for the three months ended September 30, 2016, related to the Chapter 11 proceedings that were incurred since the Petition Date, have been recorded in “reorganization items, net” on the condensed consolidated statement of operations.

Exploration Costs

Exploration costs decreased by approximately $3 million to approximately $4,000 for the three months ended September 30, 2016, from approximately $3 million for the three months ended September 30, 2015. The decrease was primarily due to lower seismic data expenses and lower leasehold impairment expenses on unproved properties.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization decreased by approximately $65 million or 31% to approximately $142 million for the three months ended September 30, 2016, from approximately $207 million for the three months ended September 30, 2015. The decrease was primarily due to lower rates as a result of the impairments recorded in the prior year and the first quarter of 2016, as well as lower total production volumes. Depreciation, depletion and amortization per Mcfe also decreased to $1.44 per Mcfe for the three months ended September 30, 2016, from $1.88 per Mcfe for the three months ended September 30, 2015.

Impairment of Long-Lived Assets

The Company recorded the following noncash impairment charges (before and after tax) associated with proved oil and natural gas properties:



	Three Months Ended September 30,
	2016		2015
	(in thousands)

Rockies region	$	23,142	$	1,182,337
Mid-Continent region	18,586		366,865
TexLa region	—		375,567
California region	—		330,311
	$	41,728	$	2,255,080

The impairment charges for both the three months ended September 30, 2016 and September 30, 2015, were due to a decline in commodity prices.

(Gains) Losses on Sale of Assets and Other, Net

During the three months ended September 30, 2015, the Company recorded a net gain of approximately $174 million, including costs to sell of approximately $1 million, on the sale of its remaining position in Howard County in the Permian Basin (the “Howard County Assets Sale”).

Taxes, Other Than Income Taxes



	Three Months Ended September 30,
	2016			2015		Variance
	(in thousands)

Severance taxes	$	14,544		$	14,621	$	(77	)
Ad valorem taxes	(2,479		)	26,027		(28,506		)
California carbon allowances	3,261			5,548		(2,287		)
Other	57			42		15
	$	15,383		$	46,238	$	(30,855	)

Taxes, other than income taxes decreased by approximately $31 million or 67% for the three months ended September 30, 2016, compared to the three months ended September 30, 2015. Severance taxes, which are a function of revenues generated from production, decreased primarily due to lower oil and natural gas prices and lower production volumes, partially offset by reduced incentives on certain wells in the Rockies region for the three months ended September 30, 2016, compared to the same period in 2015. Ad valorem taxes, which are based on the value of reserves and production equipment and vary by location, decreased primarily due to lower estimated valuations on certain of the Company’s properties. California carbon allowances decreased primarily due to lower anticipated emissions compliance obligations as a result of reduced capital spending levels and a decrease in steam injection volumes.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Other Income and (Expenses)



	Three Months Ended September 30,
	2016			2015			Variance
	(in thousands)

Interest expense, net of amounts capitalized	$	(40,105	)	$	(138,383	)	$	98,278
Gain on extinguishment of debt	—			197,741			(197,741		)
Other, net	(269		)	(1,701		)	1,432
	$	(40,374	)	$	57,657		$	(98,031	)

Other income and (expenses) decreased by approximately $98 million for the three months ended September 30, 2016, compared to the three months ended September 30, 2015. Interest expense decreased primarily due to the Company’s discontinuation of interest expense recognition on the senior notes as a result of the Chapter 11 proceedings, lower outstanding debt during the period principally as a result of the senior notes repurchased and exchanged during 2015, and lower amortization of discounts and financing fees. For the three months ended September 30, 2016, contractual interest, which was not recorded, on the senior notes was approximately $70 million. For the three months ended September 30, 2015, the Company recorded a gain on extinguishment of debt of approximately $198 million as a result of the repurchases of a portion of its senior notes. Other expenses decreased primarily due to lower write-offs of deferred financing fees related to the Credit Facilities and lower bank fees. See “Debt” under “Liquidity and Capital Resources” below for additional details.

The $1.0 billion in aggregate principal amount of Second Lien Notes issued in November 2015 were 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. For the three months ended September 30, 2016, unrecorded contractual interest on the Second Lien Notes was approximately $30 million.

Reorganization Items, Net

The following table summarizes the components of reorganization items included on the condensed consolidated statement of operations:



	Three Months Ended September 30, 2016
	(in thousands)

Legal and other professional advisory fees	$	(25,604	)
Terminated contracts	(92,957		)
Other	2,285
Reorganization items, net	$	(116,276	)

Income Tax Expense (Benefit)

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

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. The Company recognized an income tax benefit of approximately $4 million for the three months ended September 30, 2016, compared to income tax expense of approximately $2 million for the three months ended September 30, 2015. The income tax benefit is primarily due to lower income from the Company’s taxable subsidiaries during the three months ended September 30, 2016, compared to the same period in 2015.

Net Loss

Net loss decreased by approximately $1.4 billion or 87% to approximately $198 million for the three months ended September 30, 2016, from approximately $1.6 billion for the three months ended September 30, 2015. The decrease was primarily due to lower impairment charges, partially offset by lower gains on oil and natural gas derivatives and lower production revenues. See discussion above for explanations of variances.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Results of Operations

Nine Months Ended September 30, 2016, Compared to Nine Months Ended September 30, 2015



	Nine Months Ended September 30,
	2016			2015			Variance
	(in thousands)
Revenues and other:
Natural gas sales	$	346,970		$	478,645		$	(131,675	)
Oil sales	507,159			787,158			(279,999		)
NGL sales	105,586			108,430			(2,844		)
Total oil, natural gas and NGL sales	959,715			1,374,233			(414,518		)
Gains (losses) on oil and natural gas derivatives	(72,533		)	782,622			(855,155		)
Marketing and other revenues	68,645			79,824			(11,179		)
	955,827			2,236,679			(1,280,852		)
Expenses:
Lease operating expenses	370,658			467,759			(97,101		)
Transportation expenses	156,590			164,250			(7,660		)
Marketing expenses	35,784			47,359			(11,575		)
General and administrative expenses ⁽¹⁾	196,377			237,731			(41,354		)
Exploration costs	2,745			4,032			(1,287		)
Depreciation, depletion and amortization	449,677			637,964			(188,287		)
Impairment of long-lived assets	1,195,632			2,787,697			(1,592,065		)
Taxes, other than income taxes	80,297			158,317			(78,020		)
(Gains) losses on sale of assets and other, net	5,959			(197,263		)	203,222
	2,493,719			4,307,846			(1,814,127		)
Other income and (expenses)	(215,195		)	(224,117		)	8,922
Reorganization items, net	418,608			—			418,608
Loss before income taxes	(1,334,479		)	(2,295,284		)	960,805
Income tax expense (benefit)	3,140			(7,680		)	10,820
Net loss	$	(1,337,619	)	$	(2,287,604	)	$	949,985


⁽¹⁾	General and administrative expenses for the nine months ended September 30, 2016, and September 30, 2015, include approximately $19 million and $41 million, respectively, of noncash unit-based compensation expenses.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued



	Nine Months Ended September 30,
	2016		2015		Variance
Average daily production:
Natural gas (MMcf/d)	600		654		(8	)%
Oil (MBbls/d)	51.9		63.6		(18	)%
NGL (MBbls/d)	29.6		28.5		4	%
Total (MMcfe/d)	1,089		1,206		(10	)%

Weighted average prices: ⁽¹⁾
Natural gas (Mcf)	$	2.11	$	2.68	(21	)%
Oil (Bbl)	$	35.66	$	45.36	(21	)%
NGL (Bbl)	$	13.03	$	13.94	(7	)%

Average NYMEX prices:
Natural gas (MMBtu)	$	2.29	$	2.80	(18	)%
Oil (Bbl)	$	41.33	$	51.00	(19	)%

Costs per Mcfe of production:
Lease operating expenses	$	1.24	$	1.42	(13	)%
Transportation expenses	$	0.52	$	0.50	4	%
General and administrative expenses ⁽²⁾	$	0.66	$	0.72	(8	)%
Depreciation, depletion and amortization	$	1.51	$	1.94	(22	)%
Taxes, other than income taxes	$	0.27	$	0.48	(44	)%


⁽¹⁾	Does not include the effect of gains (losses) on derivatives.


⁽²⁾	General and administrative expenses for the nine months ended September 30, 2016, and September 30, 2015, include approximately $19 million and $41 million, respectively, of noncash unit-based compensation expenses.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Revenues and Other

Oil, Natural Gas and NGL Sales

Oil, natural gas and NGL sales decreased by approximately $415 million or 30% to approximately $960 million for the nine months ended September 30, 2016, from approximately $1.4 billion for the nine months ended September 30, 2015, due to lower oil, natural gas and NGL prices and lower production volumes. Lower oil, natural gas and NGL prices resulted in a decrease in revenues of approximately $138 million, $94 million and $8 million, respectively.

Average daily production volumes decreased to approximately 1,089 MMcfe/d for the nine months ended September 30, 2016, from 1,206 MMcfe/d for the nine months ended September 30, 2015. Lower oil and natural gas production volumes resulted in a decrease in revenues of approximately $142 million and $38 million, respectively. Higher NGL production volumes resulted in an increase in revenues of approximately $5 million.

The following table sets forth average daily production by region:



	Nine Months Ended September 30,
	2016	2015	Variance
Average daily production (MMcfe/d):
Rockies	394	433	(39	)	(9	)%
Hugoton Basin	239	252	(13	)	(5	)%
California	158	187	(29	)	(15	)%
Mid-Continent	100	102	(2	)	(2	)%
TexLa	80	82	(2	)	(2	)%
Permian Basin	58	85	(27	)	(32	)%
Michigan/Illinois	31	31	—		(2	)%
South Texas	29	34	(5	)	(15	)%
	1,089	1,206	(117	)	(10	)%

Gains (Losses) on Oil and Natural Gas Derivatives

Losses on oil and natural gas derivatives were approximately $73 million for the nine months ended September 30, 2016, compared to gains of approximately $783 million for the nine months ended September 30, 2015, representing a variance of approximately $856 million. Losses on oil and natural gas derivatives were primarily due to changes in fair value of the derivative contracts, and the comparison from period to period was impacted by the declining maturity schedule of the Company’s hedges. The fair value on unsettled derivative contracts changes as future commodity price expectations change compared to the contract prices on the derivatives. If the expected future commodity prices increase compared to the contract prices on the derivatives, losses are recognized; and if the expected future commodity prices decrease compared to the contract prices on the derivatives, gains are recognized.

See above under “Executive Overview” for details about the Company’s commodity derivatives cancellations in 2016.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Marketing and Other Revenues

Marketing revenues represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing and other revenues decreased by approximately $11 million or 14% to approximately $69 million for the nine months ended September 30, 2016, from approximately $80 million for the nine months ended September 30, 2015. The decrease was primarily due to lower revenues generated by the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms, and lower electricity sales revenues generated by the Company’s California cogeneration facilities, partially offset by higher helium sales revenue in the Hugoton Basin.

Expenses

Lease Operating Expenses

Lease operating expenses include expenses such as labor, field office, vehicle, supervision, maintenance, tools and supplies, and workover expenses. Lease operating expenses decreased by approximately $97 million or 21% to approximately $371 million for the nine months ended September 30, 2016, from approximately $468 million for the nine months ended September 30, 2015. The decrease was primarily due to cost savings initiatives and lower workover activities, as well as a decrease in steam costs caused by lower prices for natural gas used in steam generation and a decrease in steam injection volumes. Lease operating expenses per Mcfe also decreased to $1.24 per Mcfe for the nine months ended September 30, 2016, from $1.42 per Mcfe for the nine months ended September 30, 2015.

Transportation Expenses

Transportation expenses decreased by approximately $7 million or 5% to approximately $157 million for the nine months ended September 30, 2016, from approximately $164 million for the nine months ended September 30, 2015. The decrease was primarily due to reduced costs as a result of certain contracts terminated in the Chapter 11 proceedings and lower production volumes, partially offset by higher costs from nonoperated properties in the Rockies region. Transportation expenses per Mcfe increased to $0.52 per Mcfe for the nine months ended September 30, 2016, from $0.50 per Mcfe for the nine months ended September 30, 2015.

Marketing Expenses

Marketing expenses represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing expenses decreased by approximately $11 million or 24% to approximately $36 million for the nine months ended September 30, 2016, from approximately $47 million for the nine months ended September 30, 2015. The decrease was primarily due to lower expenses associated with the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms, and lower electricity generation expenses incurred by the Company’s California cogeneration facilities.

General and Administrative Expenses

General and administrative expenses are costs not directly associated with field operations and reflect the costs of employees including executive officers, related benefits, office leases and professional fees. General and administrative expenses decreased by approximately $42 million or 17% to approximately $196 million for the nine months ended September 30, 2016, from approximately $238 million for the nine months ended September 30, 2015. The decrease was primarily due to lower salaries and benefits related expenses, lower acquisition expenses, lower professional services expenses and lower various other administrative expenses. General and administrative expenses for the nine months ended September 30, 2015, was impacted by advisory fees related to alliance agreements entered into with certain private capital investors. General and administrative expenses per Mcfe also decreased to $0.66 per Mcfe for the nine months ended September 30, 2016, from $0.72 per Mcfe for the nine months ended September 30, 2015.

Professional services expenses of approximately $46 million for the nine months ended September 30, 2016, related to the Chapter 11 proceedings that were incurred since the Petition Date, have been recorded in “reorganization items, net” on the condensed consolidated statement of operations.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Exploration Costs

Exploration costs decreased by approximately $1 million or 32% to approximately $3 million for the nine months ended September 30, 2016, from approximately $4 million for the nine months ended September 30, 2015. The decrease was primarily due to lower leasehold impairment expenses on unproved properties.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization decreased by approximately $188 million or 30% to approximately $450 million for the nine months ended September 30, 2016, from approximately $638 million for the nine months ended September 30, 2015. The decrease was primarily due to lower rates as a result of the impairments recorded in the prior year and the first quarter of 2016, as well as lower total production volumes. Depreciation, depletion and amortization per Mcfe also decreased to $1.51 per Mcfe for the nine months ended September 30, 2016, from $1.94 per Mcfe for the nine months ended September 30, 2015.

Impairment of Long-Lived Assets

The Company recorded the following noncash impairment charges (before and after tax) associated with proved and unproved oil and natural gas properties:



	Nine Months Ended September 30,
	2016		2015
	(in thousands)

California region	$	984,288	$	537,511
Mid-Continent region	148,289		372,568
Rockies region	49,819		1,182,337
Hugoton Basin	—		277,914
TexLa region	—		408,667
South Texas region	—		8,700
Proved oil and natural gas properties	1,182,396		2,787,697
California region unproved oil and natural gas properties	13,236		—
Impairment of long-lived assets	$	1,195,632	$	2,787,697

(Gains) Losses on Sale of Assets and Other, Net

During the nine months ended September 30, 2015, the Company recorded a net gain of approximately $174 million, including costs to sell of approximately $1 million, on the Howard County Assets Sale.

Taxes, Other Than Income Taxes



	Nine Months Ended September 30,
	2016		2015			Variance
	(in thousands)

Severance taxes	$	32,872	$	49,187		$	(16,315	)
Ad valorem taxes	36,140		91,923			(55,783		)
California carbon allowances	10,138		17,247			(7,109		)
Other	1,147		(40		)	1,187
	$	80,297	$	158,317		$	(78,020	)

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Taxes, other than income taxes decreased by approximately $78 million or 49% for the nine months ended September 30, 2016, compared to the nine months ended September 30, 2015. Severance taxes, which are a function of revenues generated from production, decreased primarily due to lower oil, natural gas and NGL prices and lower production volumes. Ad valorem taxes, which are based on the value of reserves and production equipment and vary by location, decreased primarily due to lower estimated valuations on certain of the Company’s properties. California carbon allowances decreased primarily due to lower anticipated emissions compliance obligations as a result of reduced capital spending levels and a decrease in steam injection volumes.

Other Income and (Expenses)



	Nine Months Ended September 30,
	2016			2015			Variance
	(in thousands)

Interest expense, net of amounts capitalized	$	(213,758	)	$	(427,584	)	$	213,826
Gain on extinguishment of debt	—			213,527			(213,527		)
Other, net	(1,437		)	(10,060		)	8,623
	$	(215,195	)	$	(224,117	)	$	8,922

Other income and (expenses) decreased by approximately $9 million for the nine months ended September 30, 2016, compared to the nine months ended September 30, 2015. Interest expense decreased primarily due to the Company’s discontinuation of interest expense recognition on the senior notes for the period from May 12, 2016 through September 30, 2016, as a result of the Chapter 11 proceedings, lower outstanding debt during the period principally as a result of the senior notes repurchased and exchanged during 2015, and lower amortization of discounts and financing fees. For the period from May 12, 2016, through September 30, 2016, contractual interest, which was not recorded, on the senior notes was approximately $108 million. For the nine months ended September 30, 2015, the Company recorded a gain on extinguishment of debt of approximately $214 million as a result of the repurchases of a portion of its senior notes. Other expenses decreased primarily due to lower write-offs of deferred financing fees related to the Credit Facilities and lower bank fees. See “Debt” under “Liquidity and Capital Resources” below for additional details.

The $1.0 billion in aggregate principal amount of Second Lien Notes issued in November 2015 were 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. For the period from May 12, 2016, through September 30, 2016, unrecorded contractual interest on the Second Lien Notes was approximately $46 million.

Reorganization Items, Net

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

The following table summarizes the components of reorganization items included on the condensed consolidated statement of operations:



	Nine Months Ended September 30, 2016
	(in thousands)

Legal and other professional advisory fees	$	(46,114	)
Unamortized deferred financing fees, discounts and premiums	(41,122		)
Gain related to interest payable on the 12.00% senior secured second lien notes due December 2020 ⁽¹⁾	551,000
Terminated contracts	(47,848		)
Other	2,692
Reorganization items, net	$	418,608


⁽¹⁾	Represents a noncash gain on the write-off of postpetition contractual interest through maturity, recorded to reflect the carrying value of the liability subject to compromise at its estimated allowed claim amount.

Income Tax Expense (Benefit)

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. The Company recognized income tax expense of approximately $3 million for the nine months ended September 30, 2016, compared to an income tax benefit of approximately $8 million for the nine months ended September 30, 2015. The increased income tax expense is primarily due to additional expense recognized related to unit-based compensation in 2016 for which there was no windfall benefit offset as in 2015.

Net Loss

Net loss decreased by approximately $950 million or 42% to approximately $1.3 billion for the nine months ended September 30, 2016, from approximately $2.3 billion for the nine months ended September 30, 2015. The decrease was primarily due to lower impairment charges, the gain related to the Second Lien Notes and lower expenses, including interest, partially offset by losses compared to gains on oil and natural gas derivatives for the comparative period as well as lower production revenues. See discussion above for explanations of variances.

Liquidity and Capital Resources

The significant risks and uncertainties related to the Company’s liquidity and Chapter 11 proceedings described under “Executive Overview” raise substantial doubt about the Company’s ability to continue as a going concern.

The Company’s filing of the Bankruptcy Petitions constituted 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 the Company’s Second Lien Notes and senior notes, as well as 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 above under “Executive Overview – Chapter 11 Proceedings” for a description of these and other developments.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

service obligations, meet other financial obligations and comply with its debt covenants. As a result, the Debtors filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code.

Although the Company believes its cash flow from operations and cash on hand will be adequate to meet the operating costs of its existing business, there are no assurances that the Company’s cash flow from operations and cash on hand will be sufficient to continue to fund its operations or to allow the Company to continue as a going concern until a Plan is confirmed by the Bankruptcy Court or other alternative restructuring transaction is approved by the Bankruptcy Court and consummated. The Company’s long-term liquidity requirements, the adequacy of its capital resources and its ability to continue as a going concern are difficult to predict at this time and ultimately cannot be determined until a Plan has been confirmed, if at all, by the Bankruptcy Court. See Item 1A. “Risk Factors” in this Quarterly Report on Form 10‑Q and in the Annual Report on Form 10‑K for the year ended December 31, 2015, for risks relating to liquidity and Chapter 11 proceedings.

The Company has utilized funds from debt and equity offerings, borrowings under its Credit Facilities and net cash provided by operating activities for capital resources and liquidity. To date, the primary use of capital has been for acquisitions and the development of oil and natural gas properties. For the nine months ended September 30, 2016, the Company’s total capital expenditures were approximately $115 million.

See below for details regarding capital expenditures for the periods presented:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2016		2015		2016		2015
	(in thousands)

Oil and natural gas	$	28,211	$	91,439	$	73,777	$	373,842
Plant and pipeline	19,519		8,887		34,547		13,889
Other	784		12,526		6,471		36,701
Capital expenditures	$	48,514	$	112,852	$	114,795	$	424,432

For 2016, the Company estimates its total capital expenditures, excluding acquisitions, will be approximately $235 million, including approximately $160 million related to its oil and natural gas capital program and approximately $60 million related to its plant and pipeline capital. This estimate is under continuous review and subject to ongoing adjustments. The Company expects to fund its capital expenditures primarily from net cash provided by operating activities; however, there is uncertainty regarding the Company’s liquidity as discussed above.

Statements of Cash Flows

The following is a comparative cash flow summary:



	Nine Months Ended September 30,
	2016			2015			Variance
	(in thousands)
Net cash:
Provided by operating activities	$	885,192		$	1,034,769		$	(149,577	)
Used in investing activities	(129,063		)	(190,540		)	61,477
Provided by (used in) financing activities	42,210			(501,232		)	543,442
Net increase in cash and cash equivalents	$	798,339		$	342,997		$	455,342

Operating Activities

Cash provided by operating activities for the nine months ended September 30, 2016, was approximately $885 million, compared to approximately $1.0 billion for the nine months ended September 30, 2015. The decrease was primarily due to lower production related revenues principally due to lower commodity prices and lower production volumes, partially offset by lower expenses.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Investing Activities

The following provides a comparative summary of cash flow from investing activities:



	Nine Months Ended September 30,
	2016			2015
	(in thousands)
Cash flow from investing activities:
Capital expenditures	$	(179,332	)	$	(554,735	)
Decrease in restricted cash	53,418			—
Proceeds from sale of properties and equipment and other	(3,149		)	364,195
	$	(129,063	)	$	(190,540	)

The primary use of cash in investing activities is for the development of the Company’s oil and natural gas properties. Capital expenditures decreased primarily due to lower spending on development activities throughout the Company’s various operating regions as a result of continued low commodity prices. The Company made no acquisitions of properties during the nine months ended September 30, 2016, or September 30, 2015. In addition, during the second quarter of 2016, restricted cash was reduced by approximately $53 million as a result of the amendment to the Berry Credit Facility and the Bank RSA. See Note 2 for additional details. Proceeds from sale of properties and equipment and other for the nine months ended September 30, 2015, include approximately $276 million in net cash proceeds received from the Howard County Assets Sale in August 2015.

Financing Activities

Cash provided by financing activities for the nine months ended September 30, 2016, was approximately $42 million, compared to cash used in financing activities of approximately $501 million for the nine months ended September 30, 2015. During the nine months ended September 30, 2016, the Company borrowed approximately $979 million under the LINN Credit Facility, including approximately $919 million in February 2016 which represented the remaining undrawn amount that was available. In addition, during the nine months ended September 30, 2016, the Company repaid approximately $913 million under the LINN Credit Facility and term loan, and approximately $2 million under the Berry Credit Facility, primarily using the net cash proceeds from canceled derivative contracts (see Note 7).

The following provides a comparative summary of proceeds from borrowings and repayments of debt:



	Nine Months Ended September 30,
	2016			2015
	(in thousands)
Proceeds from borrowings:
LINN Credit Facility	$	978,500		$	1,405,000
	$	978,500		$	1,405,000
Repayments of debt:
LINN Credit Facility	$	(814,299	)	$	(1,145,000	)
Berry Credit Facility	(1,701		)	—
Term loan	(98,911		)	—
Senior notes	—			(556,909		)
	$	(914,911	)	$	(1,701,909	)

See Note 13 for details about borrowings and repayments of debt that were reflected as noncash transactions by the Company.

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

Debt

The following summarizes the Company’s outstanding debt:



	September 30, 2016			December 31, 2015
	(in thousands, except percentages)

LINN credit facility	$	1,654,745		$	2,215,000
Berry credit facility	891,259			873,175
Term loan	284,241			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 ⁽¹⁾	1,000,000			1,000,000
Interest payable on senior secured second lien notes due December 2020 ⁽¹⁾	—			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 ⁽²⁾	—			(8,694		)
Net unamortized deferred financing fees ⁽²⁾	(1,397		)	(37,374		)
Total debt, net	7,685,777			9,007,369
Less current portion, net ⁽³⁾	(2,828,848		)	(3,714,693		)
Less liabilities subject to compromise ⁽⁴⁾	(4,856,929		)	—
Long-term debt, net	$	—		$	5,292,676

⁽¹⁾


⁽²⁾	Approximately $41 million in net discounts, premiums and deferred financing fees were written off to reorganization items in connection with the filing of the Bankruptcy Petitions.


⁽³⁾	Due to existing and anticipated covenant violations, the Company’s Credit Facilities and term loan were classified as current at September 30, 2016, and December 31, 2015. The current portion as of December 31, 2015, also includes approximately $128 million of interest payable on the Second Lien Notes due within one year.


⁽⁴⁾	The Company’s senior notes and Second Lien Notes were classified as liabilities subject to compromise at September 30, 2016.

As of September 30, 2016, there was no remaining available borrowing capacity under the Credit Facilities. For additional information related to the Company’s outstanding debt, see Note 6. The Company plans to file Berry’s stand-alone financial statements with the Securities and Exchange Commission at a later date.

Counterparty Credit Risk

The Company accounts for its commodity derivatives at fair value. The Company’s counterparties are current participants or affiliates of participants in its Credit Facilities. 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. While the Company is in bankruptcy, the Bankruptcy Court’s hedging order governs the provision of collateral securing any commodity derivatives. 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

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued

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.

Distributions

Off-Balance Sheet Arrangements

The Company does not currently have any off-balance sheet arrangements.

Contingencies

See Part II. Item 1. “Legal Proceedings” for information regarding legal proceedings that the Company is party to and any contingencies related to these legal proceedings.

Commitments and Contractual Obligations

The Company has contractual obligations for long-term debt, operating leases and other long-term liabilities that were summarized in the table of contractual obligations in the 2015 Annual Report on Form 10-K. During the nine months ended September 30, 2016, the Company made approximately $758 million in net repayments of a portion of the borrowings outstanding under the Credit Facilities. The Company’s filing of the Bankruptcy Petitions constituted an event of default that accelerated the Company’s obligations under the Credit Facilities, the Second Lien Notes and the senior notes. See Note 6 for additional information about the Company’s debt instruments.

Critical Accounting Policies and Estimates

The discussion and analysis of the Company’s financial condition and results of operations is based on the condensed consolidated financial statements, which have been prepared in accordance with U.S. generally accepted accounting principles. The preparation of these financial statements requires management of the Company to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities. 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 that are believed to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. Actual results may differ from these estimates and assumptions used in the preparation of the financial statements.

Recently Issued Accounting Standards

For a discussion of recently issued accounting standards, see Note 1.

Cautionary Statement Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond the Company’s control. These statements may include discussions about the Company’s:


•	business strategy;


•	acquisition strategy;


•	financial strategy;

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Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations - Continued


•	risks associated with the Chapter 11 process, including the Company’s inability to develop, confirm and consummate a plan under Chapter 11 or an alternative restructuring transaction;


•	inability to maintain relationships with suppliers, customers, employees and other third parties as a result of the Chapter 11 filing;


•	failure to satisfy the Company’s short- or long-term liquidity needs, including its inability to generate sufficient cash flow from operations or to obtain adequate financing to fund its capital expenditures and meet working capital needs and its ability to continue as a going concern;


•	large or multiple customer defaults on contractual obligations, including defaults resulting from actual or potential insolvencies;


•	effects of legal proceedings;


•	ability to resume payment of distributions in the future or maintain or grow them after such resumption;


•	drilling locations;


•	oil, natural gas and NGL reserves;


•	realized oil, natural gas and NGL prices;


•	production volumes;


•	capital expenditures;


•	economic and competitive advantages;


•	credit and capital market conditions;


•	regulatory changes;


•	lease operating expenses, general and administrative expenses and development costs;


•	future operating results, including results of acquired properties; and


•	plans, objectives, expectations and intentions.

All of these types of statements, other than statements of historical fact included in this Quarterly Report on Form 10-Q, are forward-looking statements. These forward-looking statements may be found in Item 2. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” the negative of such terms or other comparable terminology.

The forward-looking statements contained in this Quarterly Report on Form 10-Q are largely based on Company expectations, which reflect estimates and assumptions made by Company management. These estimates and assumptions reflect management’s best judgment based on currently known market conditions and other factors. Although the Company believes such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties beyond its control. In addition, management’s assumptions may prove to be inaccurate. The Company cautions that the forward-looking statements contained in this Quarterly Report on Form 10-Q are not guarantees of future performance, and it cannot assure any reader that such statements will be realized or the events will occur. Actual results may differ materially from those anticipated or implied in forward-looking statements due to factors set forth in Item 1A. “Risk Factors” in this Quarterly Report on Form 10-Q and in the Annual Report on Form 10-K for the year ended December 31, 2015, and elsewhere in the Annual Report. The forward-looking statements speak only as of the date made and, other than as required by law, the Company undertakes no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

The forward-looking statements related to the Plan involve known and unknown risks, uncertainties, assumptions and other factors that may cause the Company’s actual results, performance or achievements to be materially different from any results, performance or achievements expressed or implied by other forward-looking statements contained in this Quarterly Report on Form 10-Q, including but not limited to potential adverse effects related to the following: delisting of the Company’s units on NASDAQ; reorganization and related effects on the Company’s outstanding debt and outstanding units; potential effects of the industry downturn on the Company’s business, financial condition and results of operations; potential limitations on the Company’s ability to maintain contracts and other critical business relationships; requirements for adequate liquidity to fund the Company’s operations in the future, including obtaining sufficient financing on acceptable terms; and other matters related to the reorganization and the Company’s indebtedness, including any defaults related thereto.

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Item 3.	Quantitative and Qualitative Disclosures About Market Risk

The Company’s primary market risks are attributable to fluctuations in commodity prices and interest rates. These risks can affect the Company’s business, financial condition, operating results and cash flows. See below for quantitative and qualitative information about these risks.

The following should be read in conjunction with the financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q and in the Company’s 2015 Annual Report on Form 10-K. The reference to a “Note” herein refers to the accompanying Notes to Condensed Consolidated Financial Statements contained in Item 1. “Financial Statements.”

Commodity Price Risk

The Company’s most significant market risk relates to prices of oil, natural gas and NGL. The Company expects commodity prices to remain volatile and unpredictable. As commodity prices decline or rise significantly, revenues and cash flows are likewise affected. In addition, future declines in commodity prices may result in noncash write-downs of the Company’s carrying amounts of its assets.

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 appropriate level of production to be hedged is an ongoing consideration based on a variety of factors, including among other things, current and future expected commodity market prices and the Company’s overall risk profile, including leverage and size and scale considerations. The Company does not enter into derivative contracts for trading purposes.

In September 2016, the Company entered into commodity derivative contracts consisting of natural gas swaps for October 2016 through December 2017 and oil swaps for January 2017 through December 2017.

At September 30, 2016, the fair value of fixed price swaps was a net liability of approximately $992,000. A 10% increase in the index oil and natural gas prices above the September 30, 2016, prices would result in a net liability of approximately $37 million, which represents a decrease in the fair value of approximately $36 million; conversely, a 10% decrease in the index oil and natural gas prices below the September 30, 2016, prices would result in a net asset of approximately $35 million, which represents an increase in the fair value of approximately $36 million.

At December 31, 2015, the fair value of fixed price swaps and put option contracts was a net asset of approximately $1.7 billion. A 10% increase in the index oil and natural gas prices above the December 31, 2015, prices would result in a net asset of approximately $1.5 billion, which represents a decrease in the fair value of approximately $190 million; conversely, a 10% decrease in the index oil and natural gas prices below the December 31, 2015, prices would result in a net asset of approximately $1.9 billion, which represents an increase in the fair value of approximately $190 million.

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.

The prices of oil, natural gas and NGL have been extremely volatile, and the Company expects this volatility to continue. Prices for these commodities may fluctuate widely in response to relatively minor changes in the supply of and demand for such commodities, market uncertainty and a variety of additional factors that are beyond its control. Actual gains or losses recognized related to the Company’s derivative contracts depend exclusively on the price of the commodities on the specified settlement dates provided by the derivative contracts.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk - Continued

Interest Rate Risk

At September 30, 2016, the Company had debt outstanding under its credit facilities and term loan of approximately $2.8 billion which incurred interest at floating rates (see Note 6). A 1% increase in the respective market rates would result in an estimated $28 million increase in annual interest expense.

At December 31, 2015, the Company had debt outstanding under its credit facilities and term loan of approximately $3.6 billion which incurred interest at floating rates. A 1% increase in the respective market rates would result in an estimated $36 million increase in annual interest expense.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in the Company’s reports under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including the Company’s Chief Executive Officer and Chief Financial Officer, and the Company’s Audit Committee of the Board of Directors, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management is required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

The Company carried out an evaluation under the supervision and with the participation of its management, including its Chief Executive Officer and Chief Financial Officer, of the effectiveness of its disclosure controls and procedures as of the end of the period covered by this report. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2016.

Changes in the Company’s Internal Control Over Financial Reporting

The Company’s management is also responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act. The Company’s internal controls were designed to provide reasonable assurance as to the reliability of its financial reporting and the preparation and presentation of the condensed consolidated financial statements for external purposes in accordance with accounting principles generally accepted in the United States.

Because of its inherent limitations, internal control over financial reporting may not detect or prevent misstatements. Projections of any evaluation of the effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

There were no changes in the Company’s internal control over financial reporting during the third quarter of 2016 that materially affected, or were reasonably likely to materially affect, the Company’s internal control over financial reporting.

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Part II – Other Information


Item 1.	Legal Proceedings

The commencement of the Chapter 11 proceedings automatically stayed certain actions against the Company, including actions to collect prepetition liabilities or to exercise control over the property of the Company’s bankruptcy estates. 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 LINN RSA and Bank RSA. The Plan in the Chapter 11 proceedings, if confirmed, will provide for the treatment of claims against the Company’s bankruptcy estates, including prepetition liabilities that have not otherwise been satisfied or addressed during the Chapter 11 proceedings. See above under Item 2. “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Chapter 11 Proceedings” for information about the Company’s entry into the LINN RSA and Bank RSA.


Item 1A.	Risk Factors

Our business has many risks. Factors that could materially adversely affect our business, financial condition, operating results or liquidity and the trading price of our units are described in Item 1A. “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2015. Except as set forth below, as of the date of this report, these risk factors have not changed materially. This information should be considered carefully, together with other information in this report and other reports and materials we file with the United States Securities and Exchange Commission.

Any plan of reorganization that we may implement will be based in large part upon assumptions and analyses developed by us. If these assumptions and analyses prove to be incorrect, our plan may be unsuccessful in its execution.

On October 21, 2016, we filed a proposed Plan with the Bankruptcy Court. Any plan of reorganization that we may implement could affect both our capital structure and the ownership, structure and operation of our business and will reflect assumptions and analyses based on our management’s experience and perception of historical trends, current conditions and expected future developments, as well as other factors that we consider appropriate under the circumstances. Whether actual future results and developments will be consistent with management’s expectations and assumptions depends on a number of factors, including but not limited to (i) our ability to change substantially our capital structure; (ii) our ability to obtain adequate liquidity and financing sources; (iii) our ability to maintain customers’ confidence in our viability as a continuing entity and to attract and retain sufficient business from them; (iv) our ability to retain key employees; and (v) the overall strength and stability of general economic conditions of the financial and oil and natural gas industries, both in the U.S. and in global markets. The failure of any of these factors could materially adversely affect the successful reorganization of our business.

In addition, any plan of reorganization will rely upon financial projections, including with respect to revenues, EBITDA, capital expenditures, debt service and cash flow. Financial forecasts are necessarily speculative, and it is likely that one or more of the assumptions and estimates that are the basis of these financial forecasts will not be accurate. In our case, the forecasts will be even more speculative than normal, because they may involve fundamental changes in the nature of our capital structure. Accordingly, we expect that our actual financial condition and results of operations will differ, perhaps materially, from what we have anticipated. Consequently, there can be no assurance that the results or developments contemplated by any plan of reorganization we may implement will occur or, even if they do occur, that they will have the anticipated effects on us and our subsidiaries or our business or operations. The failure of any such results or developments to materialize as anticipated could materially adversely affect the successful execution of any plan of reorganization.

We have substantial liquidity needs and may not be able to obtain sufficient liquidity to confirm a plan of reorganization and exit bankruptcy.

Although we have lowered our capital budget and reduced the scale of our operations significantly, our business remains capital intensive. In addition to the cash requirements necessary to fund ongoing operations, we have incurred significant professional fees and other costs in connection with our Chapter 11 proceedings and expect that we will continue to incur significant

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Item 1A. Risk Factors - Continued

professional fees and costs throughout the Chapter 11 proceedings. There are no assurances that our current liquidity is sufficient to allow us to satisfy our obligations related to the Chapter 11 proceedings, allow us to proceed with the confirmation of a Chapter 11 plan of reorganization and allow us to emerge from bankruptcy. We can provide no assurance that we will be able to secure additional interim financing or exit financing sufficient to meet our liquidity needs.

In connection with a plan of reorganization, we may, for federal and state income tax purposes, trigger an actual or deemed sale of all or a portion of our properties which may result in unfavorable tax consequences.

In connection with a plan of reorganization, we may, for federal and state income tax purposes, trigger an actual or deemed sale of all or a portion of our properties and use the proceeds to satisfy debt. Our unitholders may be allocated substantial taxable income or loss with respect to such a sale, and our unitholders’ share of our taxable income and gain (or specific items thereof) from such sale may be substantially greater than, or our tax losses and deductions (or specific items thereof) from such sale may be substantially less than, our unitholders’ interest in our economic profits because of allocations under section 704(c) of the Internal Revenue Code.

We are subject to the risks and uncertainties associated with Chapter 11 proceedings.

For the duration of our Chapter 11 proceedings, our operations and our ability to develop and execute our business plan, as well as our continuation as a going concern, are subject to the risks and uncertainties associated with bankruptcy. These risks include the following:


•	our ability to develop, confirm and consummate a Plan or alternative restructuring transaction;


•	our ability to obtain court approval with respect to motions filed in Chapter 11 proceedings from time to time;


•	our ability to maintain our relationships with our suppliers, service providers, customers, employees and other third parties;


•	our ability to maintain contracts that are critical to our operations;


•	our ability to execute our business plan;


•	the ability of third parties to seek and obtain court approval to terminate contracts and other agreements with us;


•	the ability of third parties to seek and obtain court approval to terminate or shorten the exclusivity period for us to propose and confirm a Plan, to appoint a Chapter 11 trustee, or to convert the Chapter 11 proceedings to a Chapter 7 proceeding; and


•	the actions and decisions of our creditors and other third parties who have interests in our Chapter 11 proceedings that may be inconsistent with our plans.

These risks and uncertainties could affect our business and operations in various ways. For example, negative events associated with our Chapter 11 proceedings could adversely affect our relationships with our suppliers, service providers, customers, employees, and other third parties, which in turn could adversely affect our operations and financial condition. Also, we need the prior approval of the Bankruptcy Court for transactions outside the ordinary course of business, which may limit our ability to respond timely to certain events or take advantage of certain opportunities. Because of the risks and uncertainties associated with our Chapter 11 proceedings, we cannot accurately predict or quantify the ultimate impact of events that will occur during our Chapter 11 proceedings that may be inconsistent with our plans.

Operating under Bankruptcy Court protection for a long period of time may harm our business.

Our future results are dependent upon the successful confirmation and implementation of a plan of reorganization. A long period of operations under Bankruptcy Court protection could have a material adverse effect on our business, financial condition, results of operations and liquidity. So long as the Chapter 11 proceedings continue, our senior management will be required to spend a significant amount of time and effort dealing with the reorganization instead of focusing exclusively on our business operations. A prolonged period of operating under Bankruptcy Court protection also may make it more difficult to retain management and other key personnel necessary for the success and growth of our business. In addition, the longer the Chapter 11 proceedings continue, the more likely it is that our customers and suppliers will lose confidence in our ability to reorganize our business successfully and will seek to establish alternative commercial relationships.

Furthermore, so long as the Chapter 11 proceedings continue, we will be required to incur substantial costs for professional fees and other expenses associated with the administration of the Chapter 11 proceedings. The Chapter 11 proceedings may also

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Item 1A. Risk Factors - Continued

require us to seek debtor-in-possession financing to fund operations. If we are unable to obtain such financing on favorable terms or at all, our chances of successfully reorganizing our business may be seriously jeopardized, the likelihood that we instead will be required to liquidate our assets may be enhanced, and, as a result, any securities in us could become further devalued or become worthless.

Furthermore, we cannot predict the ultimate amount of all settlement terms for the liabilities that will be subject to a plan of reorganization. Even once a plan of reorganization is approved and implemented, our operating results may be adversely affected by the possible reluctance of prospective lenders and other counterparties to do business with a company that recently emerged from Chapter 11 proceedings.

The LINN RSA and Bank RSA provide that our common units representing limited liability company interests (“units”) will be canceled in our Chapter 11 proceedings.

We have a significant amount of indebtedness that is senior to our existing units in our capital structure. The LINN RSA and Bank RSA provide that our existing equity will be canceled in our Chapter 11 proceedings and will be entitled to a limited recovery, if any. Any trading in our units during the pendency of the Chapter 11 proceedings is highly speculative and poses substantial risks to purchasers of our units.

We may not be able to obtain confirmation of a Chapter 11 plan of reorganization.

To emerge successfully from Bankruptcy Court protection as a viable entity, we must meet certain statutory requirements with respect to adequacy of disclosure with respect to the Plan, solicit and obtain the requisite acceptances of such a plan and fulfill other statutory conditions for confirmation of such a plan, which have not occurred to date. The confirmation process is subject to numerous, unanticipated potential delays, including a delay in the Bankruptcy Court’s commencement of the confirmation hearing regarding our Plan.

Prior to the Chapter 11 filing, we entered into the Bank RSA with certain of our creditors, and on October 21, 2016, we entered into the LINN RSA, which is intended to replace the Bank RSA with respect to the terms of the Restructuring of the LINN Debtors. The restructuring transactions contemplated by the LINN RSA and Bank RSA will be effectuated through a Plan. However, we may not receive the requisite acceptances of constituencies in the Chapter 11 proceedings to confirm our Plan. Even if the requisite acceptances of a Plan are received, the Bankruptcy Court may not confirm such a plan. The precise requirements and evidentiary showing for confirming a plan, notwithstanding its rejection by one or more impaired classes of claims or equity interests, depends upon a number of factors including, without limitation, the status and seniority of the claims or equity interests in the rejecting class (i.e., unsecured claims or secured claims, subordinated or senior claims).

If a Chapter 11 plan of reorganization is not confirmed by the Bankruptcy Court, it is unclear whether we would be able to reorganize our business and what, if anything, holders of claims against us would ultimately receive with respect to their claims.

The LINN RSA and Bank RSA are subject to significant conditions and milestones that may be difficult for us to satisfy.

There are certain material conditions we must satisfy under the LINN RSA and Bank RSA, including the timely satisfaction of milestones in the anticipated Chapter 11 proceedings, such as confirmation of a Plan and effectiveness of a Plan. Our ability to timely complete such milestones is subject to risks and uncertainties that may be beyond our control.

If either the LINN RSA or Bank RSA is terminated, or if both agreements are terminated, our ability to confirm and consummate the Plan could be materially and adversely affected.

The LINN RSA and Bank RSA contain a number of termination events, upon the occurrence of which certain parties to the LINN RSA and Bank RSA, as applicable, may terminate the agreement. If the LINN RSA and Bank RSA are terminated, each of the parties thereto, as applicable, will be released from their obligations in accordance with the terms of the applicable agreement. Such termination may result in the loss of support for the Plan by the parties to the LINN RSA or Bank RSA, as applicable, which could adversely affect our ability to confirm and consummate the Plan. If the Plan is not consummated, there can be no assurance that any new Plan would be as favorable to holders of claims as the current Plan.

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Item 1A. Risk Factors - Continued

Our long-term liquidity requirements and the adequacy of our capital resources are difficult to predict at this time.

We face uncertainty regarding the adequacy of our liquidity and capital resources and have extremely limited, if any, access to additional financing. In addition to the cash requirements necessary to fund ongoing operations, we have incurred significant professional fees and other costs in connection with our Chapter 11 proceedings and expect that we will continue to incur significant professional fees and costs throughout our Chapter 11 proceedings. We cannot assure you that cash on hand and cash flow from operations will be sufficient to continue to fund our operations and allow us to satisfy our obligations related to the Chapter 11 proceedings until we are able to emerge from our Chapter 11 proceedings.

Our liquidity, including our ability to meet our ongoing operational obligations, is dependent upon, among other things: (i) our ability to comply with the terms and conditions of any cash collateral order that may be entered by the Bankruptcy Court in connection with the Chapter 11 proceedings, (ii) our ability to maintain adequate cash on hand, (iii) our ability to generate cash flow from operations, (iv) our ability to develop, confirm and consummate a Chapter 11 plan or other alternative restructuring transaction, and (v) the cost, duration and outcome of the Chapter 11 proceedings.

As a result of the Chapter 11 proceedings, our financial results may be volatile and may not reflect historical trends.

During the Chapter 11 proceedings, we expect our financial results to continue to be volatile as restructuring activities and expenses, contract terminations and rejections, and claims assessments significantly impact our consolidated financial statements. As a result, our historical financial performance is likely not indicative of our financial performance after the date of the bankruptcy filing. In addition, if we emerge from Chapter 11, the amounts reported in subsequent consolidated financial statements may materially change relative to historical consolidated financial statements, including as a result of revisions to our operating plans pursuant to a plan of reorganization. We also may be required to adopt fresh start accounting, in which case our assets and liabilities will be recorded at fair value as of the fresh start reporting date, which may differ materially from the recorded values of assets and liabilities on our consolidated balance sheets. Our financial results after the application of fresh start accounting also may be different from historical trends.

We may be subject to claims that will not be discharged in the Chapter 11 proceedings, which could have a material adverse effect on our financial condition and results of operations.

The Bankruptcy Code provides that the confirmation of a plan of reorganization discharges a debtor from substantially all debts arising prior to confirmation. With few exceptions, all claims that arose prior to May 12, 2016, or before confirmation of the plan of reorganization (i) would be subject to compromise and/or treatment under the plan of reorganization and/or (ii) would be discharged in accordance with the terms of the Plan. Any claims not ultimately discharged through the Plan could be asserted against the reorganized entities and may have an adverse effect on our financial condition and results of operations on a post-reorganization basis.

We may experience increased levels of employee attrition as a result of the Chapter 11 proceedings.

As a result of the Chapter 11 proceedings, we may experience increased levels of employee attrition, and our employees likely will face considerable distraction and uncertainty. A loss of key personnel or material erosion of employee morale could adversely affect our business and results of operations. Our ability to engage, motivate and retain key employees or take other measures intended to motivate and incent key employees to remain with us through the pendency of the Chapter 11 proceedings is limited by restrictions on implementation of incentive programs under the Bankruptcy Code. The loss of services of members of our senior management team could impair our ability to execute our strategy and implement operational initiatives, which would be likely to have a material adverse effect on our business, financial condition and results of operations.

In certain instances, a Chapter 11 case may be converted to a case under Chapter 7 of the Bankruptcy Code.

There can be no assurance as to whether we will successfully reorganize and emerge from the Chapter 11 proceedings or, if we do successfully reorganize, as to when we would emerge from the Chapter 11 proceedings.

If the Bankruptcy Court finds that it would be in the best interest of creditors and/or the Debtors, the Bankruptcy Court may convert our anticipated Chapter 11 bankruptcy case to a case under Chapter 7 of the Bankruptcy Code. In such event, a Chapter 7 trustee would be appointed or elected to liquidate the Debtors’ assets for distribution in accordance with the priorities

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Item 1A. Risk Factors - Continued

established by the Bankruptcy Code. The Debtors believe that liquidation under Chapter 7 would result in significantly smaller distributions being made to the Debtors’ creditors than those provided for in a Chapter 11 plan because of (i) the likelihood that the assets would have to be sold or otherwise disposed of in a disorderly fashion over a short period of time rather than reorganizing or selling in a controlled manner the Debtors’ businesses as a going concern, (ii) additional administrative expenses involved in the appointment of a Chapter 7 trustee, and (iii) additional expenses and claims, some of which would be entitled to priority, that would be generated during the liquidation and from the rejection of leases and other executory contracts in connection with a cessation of operations.

We may be unable to hedge anticipated production volumes on attractive terms or at all, which would subject us to further potential commodity price uncertainty and could adversely affect our net cash provided by operating activities, financial condition and results of operations.

Our anticipated production volumes remain mostly unhedged. Based on current expectations for continued low future commodity prices, reduced hedging market liquidity and potential reduced counterparty willingness to enter into new hedges with us, we may be unable to hedge anticipated production volumes on attractive terms or at all, which would subject us to further potential commodity price uncertainty and could adversely affect our net cash provided by operating activities, financial condition and results of operations.

Our units are no longer listed on a national securities exchange and are quoted only in over-the-counter markets, which carries substantial risks and could continue to negatively impact our unit price, volatility and liquidity.

As a result of our failure to comply with the NASDAQ Global Select Market (“NASDAQ”) continued listing requirements, on May 24, 2016, our units began trading over the counter on the OTC Markets Group Inc.’s Pink marketplace under the trading symbol “LINEQ.”

Our delisting from the NASDAQ and commencement of trading on the OTC Pink Sheets marketplace has resulted and may continue to result in a reduction in some or all of the following, each of which could have a material adverse effect on our unitholders:


•	the liquidity of our units;


•	the market price of our units;


•	our ability to obtain financing for the continuation of our operations;


•	the number of institutional and other investors that will consider investing in our units;


•	the number of market makers in our units;


•	the availability of information concerning the trading prices and volume of our units; and


•	the number of broker-dealers willing to execute trades in our units.


Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities

The Company’s Board of Directors had authorized the repurchase of up to $250 million of the Company’s outstanding units from time to time on the open market or in negotiated purchases. The Company did not repurchase any units during the nine months ended September 30, 2016, and as of September 30, 2016, the Company does not intend to make any purchases under the program.


Item 3.	Defaults Upon Senior Securities

See Part I. Item 1. Note 2 to the Company’s condensed consolidated financial statements entitled “Chapter 11 Proceedings, Ability to Continue as a Going Concern and Covenant Violations” which is incorporated in this item by reference.

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Item 4.	Mine Safety Disclosures

Not applicable


Item 5.	Other Information

None

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Item 6.	Exhibits



Exhibit Number		Description

3.1	—	Certificate of Formation of Linn Energy Holdings, LLC (now Linn Energy, LLC) (incorporated herein by reference to Exhibit 3.1 to Registration Statement on Form S‑1 (File No. 333‑125501) filed on June 3, 2005)
3.2	—	Certificate of Amendment to Certificate of Formation of Linn Energy Holdings, LLC (now Linn Energy, LLC) (incorporated herein by reference to Exhibit 3.2 to Registration Statement on Form S‑1 (File No. 333-125501) filed on June 3, 2005)
3.3	—	Third Amended and Restated Limited Liability Company Agreement of Linn Energy, LLC dated September 3, 2010 (incorporated herein by reference to Exhibit 3.1 to Current Report on Form 8-K filed on September 7, 2010)
3.4	—	Amendment No. 1, dated April 23, 2013, to Third Amended and Restated LLC Agreement of Linn Energy, LLC, dated September 3, 2010 (incorporated herein by reference to Exhibit 3.1 to Quarterly Report on Form 10-Q filed on April 25, 2013)
10.1	—	First Amendment to Linn Energy, LLC Severance Plan, dated as of July 22, 2016 (incorporated herein by reference to Exhibit 10.6 to Quarterly Report on Form 10-Q filed on August 4, 2016)
10.2	—	First Amendment to Restructuring Support Agreement, dated as of September 8, 2016, by and among the Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on September 9, 2016)
10.3	—	Second Amendment to Restructuring Support Agreement, dated as of September 23, 2016, by and among the Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on September 26, 2016)
10.4	—	Third Amendment to Restructuring Support Agreement, dated as of October 7, 2016, by and among the Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.3 to Current Report on Form 8-K filed on October 11, 2016)
10.5	—	Fourth Amendment to Restructuring Support Agreement, dated as of October 14, 2016, by and among the Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.2 to Current Report on Form 8-K filed on October 18, 2016)
10.6	—	First Amendment to Settlement Agreement, dated as of July 12, 2016 (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on July 18, 2016)
10.7	—	Second Amendment to Settlement Agreement, dated as of September 8, 2016 (incorporated herein by reference to Exhibit 10.2 to Current Report on Form 8-K filed on September 9, 2016)
10.8	—	Third Amendment to Settlement Agreement, dated as of September 23, 2016 (incorporated herein by reference to Exhibit 10.2 to Current Report on Form 8-K filed on September 26, 2016)
10.9	—	Fourth Amendment to Settlement Agreement, dated as of October 7, 2016 (incorporated herein by reference to Exhibit 10.4 to Current Report on Form 8-K filed on October 11, 2016)
10.10	—	Restructuring Support Agreement, dated as of October 7, 2016, by and among the Linn Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on October 11, 2016)
10.11	—	First Amendment to Restructuring Support Agreement, dated as of October 14, 2016, by and among the Linn Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on October 18, 2016)
10.12	—	Backstop Commitment Letter, dated as of October 7, 2016, by and among the Company and backstop parties thereto (incorporated herein by reference to Exhibit 10.2 to Current Report on Form 8-K filed on October 11, 2016)
10.13	—	First Amended and Restated Restructuring Support Agreement, dated as of October 21, 2016, by and among the Linn Debtors and the supporting parties thereto (incorporated herein by reference to Exhibit 10.1 to Current Report on Form 8-K filed on October 27, 2016)

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Item 6.	Exhibits - Continued



Exhibit Number		Description

10.14	—	Backstop Commitment Agreement, dated as of October 25, 2016, by and among the Company and the parties thereto (incorporated herein by reference to Exhibit 10.2 to Current Report on Form 8-K filed on October 27, 2016)
31.1*	—	Section 302 Certification of Mark E. Ellis, Chairman, President and Chief Executive Officer of Linn Energy, LLC
31.2*	—	Section 302 Certification of David B. Rottino, Executive Vice President and Chief Financial Officer of Linn Energy, LLC
32.1*	—	Section 906 Certification of Mark E. Ellis, Chairman, President and Chief Executive Officer of Linn Energy, LLC
32.2*	—	Section 906 Certification of David B. Rottino, Executive Vice President and Chief Financial Officer of Linn Energy, LLC
101.INS**	—	XBRL Instance Document
101.SCH**	—	XBRL Taxonomy Extension Schema Document
101.CAL**	—	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF**	—	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB**	—	XBRL Taxonomy Extension Label Linkbase Document
101.PRE**	—	XBRL Taxonomy Extension Presentation Linkbase Document


*	Filed herewith.


**	Furnished herewith.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	LINN ENERGY, LLC
	(Registrant)

Date: November 3, 2016	/s/ Darren R. Schluter
	Darren R. Schluter
	Vice President and Controller
	(Duly Authorized Officer and Principal Accounting Officer)


Date: November 3, 2016	/s/ David B. Rottino
	David B. Rottino
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)