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 ~~June~~September 30, 2017



¨	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, INC.

(Exact name of registrant as specified in its charter)



Delaware (State or other jurisdiction of incorporation or organization)	81-5366183 (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)

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, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.



Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	¨	(Do not check if a smaller reporting company)
		Smaller reporting company	x
		Emerging growth company	¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. Yes x No ¨

As of ~~July~~October 31, 2017, there were ~~88,511,309~~84,099,659 shares of Class A common stock, par value $0.001 per share, outstanding.

TABLE OF CONTENTS



		Page

	Glossary of Terms	ii

	Part I – Financial Information
Item 1.	Financial Statements
	Condensed Consolidated Balance Sheets	1
	Condensed Consolidated Statements of Operations	3
	Condensed Consolidated Statements of Equity	5
	Condensed Consolidated Statements of Cash Flows	6
	Notes to Condensed Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3840
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	6165
Item 4.	Controls and Procedures	6366

	Part II – Other Information
Item 1.	Legal Proceedings	6468
Item 1A.	Risk Factors	6468
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6468
Item 3.	Defaults Upon Senior Securities	6568
Item 4.	Mine Safety Disclosures	6568
Item 5.	Other Information	6568
Item 6.	Exhibits	6669

	Signatures	6770

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.

Table of Contents

PART I – FINANCIAL INFORMATION


Item 1.	Financial Statements

LINN ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	Successor			Predecessor			Successor			Predecessor
	June 30, 2017			December 31, 2016			September 30, 2017			December 31, 2016
(in thousands, except share and unit amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	16,903		$	694,857		$	32,042		$	694,857
Accounts receivable – trade, net	163,935			198,064			165,045			198,064
Derivative instruments	23,959			—			6,220			—
Restricted cash	98,616			1,602			51,322			1,602
Other current assets	71,836			105,310			85,937			105,310
Assets held for sale	236,421			—
Current assets of discontinued operations	235,643			701			—			701
Total current assets	847,313			1,000,534			340,566			1,000,534

Noncurrent assets:
Oil and natural gas properties (successful efforts method)	1,444,110			12,349,117			1,248,246			12,349,117
Less accumulated depletion and amortization	(37,572		)	(9,843,908		)	(53,370		)	(9,843,908		)
	1,406,538			2,505,209			1,194,876			2,505,209

Other property and equipment	441,483			618,262			472,332			618,262
Less accumulated depreciation	(12,739		)	(217,724		)	(22,067		)	(217,724		)
	428,744			400,538			450,265			400,538

Derivative instruments	12,759			—			4,582			—
Deferred income taxes	492,182			—			476,419			—
Equity method investments							461,460			6,200
Other noncurrent assets	13,980			13,984			7,449			7,784
Noncurrent assets of discontinued operations	—			740,326			—			740,326
	518,921			754,310			949,910			754,310
Total noncurrent assets	2,354,203			3,660,057			2,595,051			3,660,057
Total assets	$	3,201,516		$	4,660,591		$	2,935,617		$	4,660,591

LIABILITIES AND EQUITY (DEFICIT)
Current liabilities:
Accounts payable and accrued expenses	$	268,605		$	295,081		$	280,797		$	295,081
Derivative instruments	486			82,508			547			82,508
Current portion of long-term debt, net	—			1,937,729			—			1,937,729
Other accrued liabilities	135,416			25,979			100,755			25,979
Liabilities held for sale	36,387			—
Current liabilities of discontinued operations	28,218			321			—			321
Total current liabilities	469,112			2,341,618			382,099			2,341,618

Derivative instruments	—			11,349
Long-term debt	183,430			—
Other noncurrent liabilities	264,025			360,405
Noncurrent liabilities of discontinued operations	—			39,202
Liabilities subject to compromise	—			4,305,005

Table of Contents

LINN ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS - Continued

(Unaudited)

Successor Predecessor
June 30,
2017 December 31,
2016
(in thousands, except share and unit amounts)
Commitments and contingencies (Note 10)

Temporary equity:
Redeemable noncontrolling interests 28,132
—
Stockholders’/unitholders’ equity (deficit):
Predecessor units issued and outstanding (no units issued or outstanding at June 30, 2017; 352,792,474 units issued and outstanding at December 31, 2016) —
5,386,885
Predecessor accumulated deficit —
(7,783,873 )
Successor preferred stock ($0.001 par value, 30,000,000 shares authorized and no shares issued at June 30, 2017; no shares authorized or issued at December 31, 2016) —
—
Successor Class A common stock ($0.001 par value, 270,000,000 shares authorized and 89,241,558 shares issued at June 30, 2017; no shares authorized or issued at December 31, 2016) 89
—
Successor additional paid-in capital 2,043,927
—
Successor retained earnings 212,801
—
Total stockholders’/unitholders’ equity (deficit) 2,256,817
(2,396,988 )
Total liabilities and equity (deficit) $ 3,201,516
$ 4,660,591



	Successor		Predecessor
	September 30, 2017		December 31, 2016
(in thousands, except share and unit amounts)
Derivative instruments	229		11,349
Other noncurrent liabilities	260,133		360,405
Noncurrent liabilities of discontinued operations	—		39,202
Liabilities subject to compromise	—		4,305,005

Commitments and contingencies (Note 11)
Equity (deficit):
Predecessor units issued and outstanding (no units issued or outstanding at September 30, 2017; 352,792,474 units issued and outstanding at December 31, 2016)	—		5,386,885
Predecessor accumulated deficit	—		(7,783,873		)
Successor preferred stock ($0.001 par value, 30,000,000 shares authorized and no shares issued at September 30, 2017; no shares authorized or issued at December 31, 2016)	—		—
Successor Class A common stock ($0.001 par value, 270,000,000 shares authorized and 84,667,268 shares issued at September 30, 2017; no shares authorized or issued at December 31, 2016)	85		—
Successor additional paid-in capital	1,926,722		—
Successor retained earnings	349,864		—
Total common stockholders’/unitholders’ equity (deficit)	2,276,671		(2,396,988		)
Noncontrolling interests	16,485		—
Total equity (deficit)	2,293,156		(2,396,988		)
Total liabilities and equity (deficit)	$	2,935,617	$	4,660,591

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

Table of Contents

LINN ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Three Months Ended September 30, 2017			Three Months Ended September 30, 2016
(in thousands, except per share and per unit amounts)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	243,167		$	195,847		$	206,318		$	237,986
Gains (losses) on oil and natural gas derivatives	45,714			(183,794		)	(14,497		)	166
Marketing revenues	12,547			8,551			38,493			9,249
Other revenues	6,391			23,641			6,368			19,574
	307,819			44,245			236,682			266,975
Expenses:
Lease operating expenses	71,057			70,367			61,272			67,234
Transportation expenses	37,388			41,092			34,541			40,986
Marketing expenses	6,976			6,727			34,099			6,933
General and administrative expenses	34,458			52,169			30,035			48,471
Exploration costs	811			48			171			4
Depreciation, depletion and amortization	51,987			86,358			29,657			87,413
Impairment of long-lived assets							—			41,728
Taxes, other than income taxes	17,871			18,180			12,368			18,003
(Gains) losses on sale of assets and other, net	(306,969		)	2,517			(26,977		)	2,532
	(86,421		)	277,458			175,166			313,304
Other income and (expenses):
Interest expense, net of amounts capitalized	(7,551		)	(50,320		)	(223		)	(25,283		)
Earnings from equity method investments							2,575			222
Other, net	(1,163		)	(1,226		)	(4,237		)	(200		)
	(8,714		)	(51,546		)	(1,885		)	(25,261		)
Reorganization items, net	(3,377		)	485,798			(2,605		)	(28,361		)
Income from continuing operations before income taxes	382,149			201,039
Income (loss) from continuing operations before income taxes							57,026			(99,951		)
Income tax expense (benefit)	158,770			(3,652		)	5,996			(3,650		)
Income from continuing operations	223,379			204,691
Income (loss) from continuing operations							51,030			(96,301		)
Income (loss) from discontinued operations, net of income taxes	(3,322		)	3,801			86,099			(102,064		)
Net income	$	220,057		$	208,492
Net income (loss)							137,129			(198,365		)
Net income attributable to noncontrolling interests							66			—
Net income (loss) attributable to common stockholders/unitholders							$	137,063		$	(198,365	)

Income from continuing operations per share/unit – Basic	$	2.49		$	0.58
Income from continuing operations per share/unit – Diluted	$	2.47		$	0.58
Income (loss) per share/unit attributable to common stockholders/unitholders:
Income (loss) from continuing operations per share/unit – Basic							$	0.58		$	(0.27	)
Income (loss) from continuing operations per share/unit – Diluted							$	0.57		$	(0.27	)

Income (loss) from discontinued operations per share/unit – Basic	$	(0.04	)	$	0.01		$	0.98		$	(0.29	)
Income (loss) from discontinued operations per share/unit – Diluted	$	(0.04	)	$	0.01		$	0.97		$	(0.29	)

Net income per share/unit – Basic	$	2.45		$	0.59
Net income per share/unit – Diluted	$	2.43		$	0.59
Net income (loss) per share/unit – Basic							$	1.56		$	(0.56	)
Net income (loss) per share/unit – Diluted							$	1.54		$	(0.56	)

Weighted average shares/units outstanding – Basic	89,849			352,789			87,796			352,792
Weighted average shares/units outstanding – Diluted	90,484			352,789			88,999			352,792

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

Table of Contents

LINN ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - Continued

(Unaudited)


	Successor			Predecessor						Successor			Predecessor
	Four Months Ended June 30, 2017			Two Months Ended February 28, 2017			Six Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands, except per share and per unit amounts)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	323,492		$	188,885		$	380,288		$	529,810		$	188,885		$	618,274
Gains (losses) on oil and natural gas derivatives	33,755			92,691			(74,341		)	19,258			92,691			(74,175		)
Marketing revenues	15,461			6,636			17,612			53,954			6,636			26,861
Other revenues	8,419			9,915			51,947			14,787			9,915			71,521
	381,127			298,127			375,506			617,809			298,127			642,481
Expenses:
Lease operating expenses	95,687			49,665			153,613			156,959			49,665			220,847
Transportation expenses	51,111			25,972			83,623			85,652			25,972			124,609
Marketing expenses	9,515			4,820			14,560			43,614			4,820			21,493
General and administrative expenses	44,869			71,745			135,889			74,904			71,745			184,360
Exploration costs	866			93			2,741			1,037			93			2,745
Depreciation, depletion and amortization	71,901			47,155			175,467			101,558			47,155			262,880
Impairment of long-lived assets	—			—			123,316			—			—			165,044
Taxes, other than income taxes	24,948			14,877			35,541			37,316			14,877			53,544
(Gains) losses on sale of assets and other, net	(306,524		)	672			3,786			(333,371		)	829			6,607
	(7,627		)	214,999			728,536			167,669			215,156			1,042,129
Other income and (expenses):
Interest expense, net of amounts capitalized	(11,751		)	(16,725		)	(134,193		)	(11,974		)	(16,725		)	(159,476		)
Earnings from equity method investments										2,705			157			511
Other, net	(1,551		)	(149		)	(1,158		)	(5,788		)	(149		)	(1,358		)
	(13,302		)	(16,874		)	(135,351		)	(15,057		)	(16,717		)	(160,323		)
Reorganization items, net	(5,942		)	2,331,189			485,798			(8,547		)	2,331,189			457,437
Income (loss) from continuing operations before income taxes	369,510			2,397,443			(2,583		)	426,536			2,397,443			(102,534		)
Income tax expense (benefit)	153,455			(166		)	6,594			159,451			(166		)	2,944
Income (loss) from continuing operations	216,055			2,397,609			(9,177		)	267,085			2,397,609			(105,478		)
Loss from discontinued operations, net of income taxes	(3,254		)	(548		)	(1,130,077		)
Income (loss) from discontinued operations, net of income taxes										82,845			(548		)	(1,232,141		)
Net income (loss)	$	212,801		$	2,397,061		$	(1,139,254	)	349,930			2,397,061			(1,337,619		)
Net income attributable to noncontrolling interests										66			—			—
Net income (loss) attributable to common stockholders/unitholders										$	349,864		$	2,397,061		$	(1,337,619	)

Income (loss) per share/unit attributable to common stockholders/unitholders:
Income (loss) from continuing operations per share/unit – Basic	$	2.41		$	6.80		$	(0.02	)	$	3.00		$	6.80		$	(0.30	)
Income (loss) from continuing operations per share/unit – Diluted	$	2.40		$	6.80		$	(0.02	)	$	2.97		$	6.80		$	(0.30	)

Loss from discontinued operations per share/unit – Basic	$	(0.04	)	$	(0.01	)	$	(3.21	)
Loss from discontinued operations per share/unit – Diluted	$	(0.04	)	$	(0.01	)	$	(3.21	)
Income (loss) from discontinued operations per share/unit – Basic										$	0.93		$	(0.01	)	$	(3.49	)
Income (loss) from discontinued operations per share/unit – Diluted										$	0.93		$	(0.01	)	$	(3.49	)

Net income (loss) per share/unit – Basic	$	2.37		$	6.79		$	(3.23	)	$	3.93		$	6.79		$	(3.79	)
Net income (loss) per share/unit – Diluted	$	2.36		$	6.79		$	(3.23	)	$	3.90		$	6.79		$	(3.79	)

Weighted average shares/units outstanding – Basic	89,849			352,792			352,511			88,966			352,792			352,606
Weighted average shares/units outstanding – Diluted	90,065			352,792			352,511			89,784			352,792			352,606

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

Table of Contents

LINN ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENT OF EQUITY (PREDECESSOR)

(Unaudited)



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

December 31, 2016 (Predecessor)	352,792		$	5,386,885		$	(7,783,873	)	$	(2,396,988	)
Net income			—			2,397,061			2,397,061
Other			(73		)	—			(73		)
February 28, 2017 (Predecessor)	352,792		5,386,812			(5,386,812		)	—
Cancellation of predecessor equity	(352,792	)	(5,386,812		)	5,386,812			—
February 28, 2017 (Predecessor)	—		$	—		$	—		$	—

CONDENSED CONSOLIDATED STATEMENT OF EQUITY (SUCCESSOR)

(Unaudited)


	Class A Common Stock			Additional Paid-in Capital				Retained Earnings			Total Stockholders’ Equity			Class A Common Stock					Additional Paid-in Capital			Retained Earnings			Total Common Stockholders’ Equity			Noncontrolling Interests			Total Equity
	Shares	Amount					Shares							Amount
	(in thousands)													(in thousands)

Issuances of successor Class A common stock	89,230	$	89	$	2,021,142				$	—		$	2,021,231		89,230		$	89		$	2,021,142		$	—		$	2,021,231		$	—		$	2,021,231
Share-based compensation expenses		—		13,750				—			13,750					—			13,750			—			13,750			—			13,750
February 28, 2017 (Successor)	89,230	89		2,034,892				—			2,034,981			89,230		89			2,034,892			—			2,034,981			—			2,034,981
Net income		—		—				212,801			212,801					—			—			349,864			349,864			66			349,930
Issuances of successor Class A common stock	12	—		—				—			—			21		—			—			—			—			—			—
Repurchases of successor Class A common stock	—	—		(230		)		—			(230		)	(4,584	)	(4		)	(156,947		)	—			(156,951		)	—			(156,951		)
Share-based compensation expenses		—		9,454				—			9,454					—			62,381			—			62,381			—			62,381
Initial allocation of noncontrolling interests upon conversion of subsidiary units																—			(17,605		)	—			(17,605		)	17,605			—
Distributions to noncontrolling interests																—			—			—			—			(1,211		)	(1,211		)
Subsidiary equity transactions																—			(25		)	—			(25		)	25			—
Other		—		(189		)		—			(189		)			—			4,026			—			4,026			—			4,026
June 30, 2017 (Successor)	89,242	$	89	$	2,043,927			$	212,801		$	2,256,817
September 30, 2017 (Successor)														84,667		$	85		$	1,926,722		$	349,864		$	2,276,671		$	16,485		$	2,293,156

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

Table of Contents

LINN ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Successor			Predecessor						Successor			Predecessor
	Four Months Ended June 30, 2017			Two Months Ended February 28, 2017			Six Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Cash flow from operating activities:
Net income (loss)	$	212,801		$	2,397,061		$	(1,139,254	)	$	349,930		$	2,397,061		$	(1,337,619	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Loss from discontinued operations	3,254			548			1,130,077
(Income) loss from discontinued operations										(82,845		)	548			1,232,141
Depreciation, depletion and amortization	71,901			47,155			175,467			101,558			47,155			262,880
Impairment of long-lived assets	—			—			123,316			—			—			165,044
Deferred income taxes	131,055			(166		)	3,850			116,446			(166		)	831
Noncash (gains) losses on oil and natural gas derivatives	(25,826		)	(104,263		)	931,251			380			(104,263		)	931,085
Share-based compensation expenses	19,599			50,255			18,553			25,876			50,255			24,514
Amortization and write-off of deferred financing fees	82			1,338			9,227			3,349			1,338			11,288
(Gains) losses on sale of assets and other, net	(293,811		)	1,069			3,929			(357,510		)	1,069			5,534
Reorganization items, net	—			(2,359,364		)	(498,954		)	—			(2,359,364		)	(485,831		)
Changes in assets and liabilities:
(Increase) decrease in accounts receivable – trade, net	27,212			(7,216		)	(12,046		)	15,549			(7,216		)	(27,857		)
(Increase) decrease in other assets	(1,245		)	402			(19,039		)	3,908			402			(17,111		)
Increase in restricted cash	—			(80,164		)	—
(Increase) decrease in restricted cash										2,151			(80,164		)	—
Increase (decrease) in accounts payable and accrued expenses	(49,984		)	20,949			47,062			(43,213		)	20,949			64,252
Increase in other liabilities	22,421			2,801			26,150			56,460			2,801			21,679
Net cash provided by (used in) operating activities – continuing operations	117,459			(29,595		)	799,589			192,039			(29,595		)	850,830
Net cash provided by operating activities – discontinued operations	13,966			8,781			1,612			2,566			8,781			34,362
Net cash provided by (used in) operating activities	131,425			(20,814		)	801,201			194,605			(20,814		)	885,192

Cash flow from investing activities:
Development of oil and natural gas properties	(61,534		)	(50,597		)	(80,909		)	(136,638		)	(50,597		)	(118,920		)
Purchases of other property and equipment	(27,287		)	(7,409		)	(13,655		)	(60,656		)	(7,409		)	(25,955		)
Proceeds from sale of properties and equipment and other	641,219			(166		)	(2,713		)	703,234			(166		)	(3,321		)
Net cash provided by (used in) investing activities – continuing operations	552,398			(58,172		)	(97,277		)	505,940			(58,172		)	(148,196		)
Net cash provided by (used in) investing activities – discontinued operations	(1,645		)	(584		)	26,166			345,643			(584		)	19,133
Net cash provided by (used in) investing activities	550,753			(58,756		)	(71,111		)	851,583			(58,756		)	(129,063		)

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LINN ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - Continued

(Unaudited)


	Successor			Predecessor						Successor			Predecessor
	Four Months Ended June 30, 2017			Two Months Ended February 28, 2017			Six Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Cash flow from financing activities:
Proceeds from rights offerings, net	—			514,069			—			—			514,069			—
Repurchases of shares										(156,091		)	—			—
Proceeds from borrowings	160,000			—			978,500			190,000			—			978,500
Repayments of debt	(876,570		)	(1,038,986		)	(913,210		)	(1,090,000		)	(1,038,986		)	(913,210		)
Debt issuance costs paid	(2,973		)	—			(623		)	(7,229		)	—			(692		)
Payment to holders of claims under the second lien notes	—			(30,000		)	—			—			(30,000		)	—
Other	(87		)	(6,015		)	(20,687		)	(5,181		)	(6,015		)	(20,687		)
Net cash provided by (used in) financing activities – continuing operations	(719,630		)	(560,932		)	43,980			(1,068,501		)	(560,932		)	43,911
Net cash used in financing activities – discontinued operations	—			—			(1,593		)	—			—			(1,701		)
Net cash provided by (used in) financing activities	(719,630		)	(560,932		)	42,387			(1,068,501		)	(560,932		)	42,210

Net increase (decrease) in cash and cash equivalents	(37,452		)	(640,502		)	772,477			(22,313		)	(640,502		)	798,339
Cash and cash equivalents:
Beginning	54,355			694,857			2,168			54,355			694,857			2,168
Ending	16,903			54,355			774,645			32,042			54,355			800,507
Less cash and cash equivalents of discontinued operations at end of period	—			—			(15,008		)	—			—			(29,647		)
Ending – continuing operations	$	16,903		$	54,355		$	759,637		$	32,042		$	54,355		$	770,860

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

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 – Basis of Presentation

When referring to Linn Energy, Inc. (formerly known as Linn Energy, LLC) (“Successor,” “LINN Energy” or the “Company”), the intent is to refer to LINN Energy, a newly formed Delaware corporation, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. Linn Energy, Inc. is a successor issuer of Linn Energy, LLC pursuant to Rule 15d‑5 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). When referring to the “Predecessor” in reference to the period prior to the emergence from bankruptcy, the intent is to refer to Linn Energy, LLC, the predecessor that will be dissolved following the effective date of the Plan (as defined below) and resolution of all outstanding claims, 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 was an indirect 100% wholly owned subsidiary of the Predecessor through February 28, 2017. Berry was deconsolidated effective December 3, 2016 (see Note 4). The reference to “LinnCo” herein refers to LinnCo, LLC, an affiliate of the Predecessor.

Nature of Business

LINN Energy is an independent oil and natural gas company that was formed in February 2017, in connection with the reorganization of the Predecessor. The Predecessor was publicly traded from January 2006 to February 2017. As discussed further in Note 2, on May 11, 2016 (the “Petition Date”), Linn Energy, LLC, certain of its direct and indirect subsidiaries, and LinnCo (collectively, 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 were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16-60040. During the pendency of the Chapter 11 proceedings, the Debtors operated 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 Company emerged from bankruptcy effective February 28, 2017.

The Company’s properties are currently located in seven operating regions in the United States (“U.S.”), in the ~~Rockies, the~~ Hugoton Basin, the Mid-Continent, east Texas and north Louisiana (“TexLa”), the Rockies, the Permian Basin, Michigan/Illinois and south Texas. In July 2017, the Company divested all of its properties located in California. The Company also owns a 50% equity interest in Roan Resources LLC, which is focused on the accelerated development of the Merge/SCOOP/STACK play in Oklahoma.

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, 2016. 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. Noncontrolling interests represent ownership in the net assets of the Company’s consolidated subsidiary, Linn Energy Holdco LLC (“Holdco”), not attributable to LINN Energy, and are presented as a component of equity. Changes in the Company’s ownership interests in Holdco that do not result in deconsolidation are recognized in equity. See Note 13 for additional information about noncontrolling interests. Investments in noncontrolled entities over which the Company exercises significant influence are accounted for under the equity method. Redeemable noncontrolling interests on the condensed consolidated balance sheet as of June 30, 2017, relate to the noncontrolling Class B unitholders of the Company’s subsidiary, Linn Energy Holdco LLC (“Holdco”). See Note ~~12 and Note 17~~6 for additional ~~information.~~

The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. In addition, the Company has classified the assets and liabilities of its California properties, asinformation about equity method investments.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The condensed consolidated financial statements for previous periods include certain reclassifications that were made to conform to current presentation. The Company has also classified the assets and liabilities of its California properties, as well as the results of operations and cash flows of its California properties and Berry, as discontinued operations on its condensed consolidated financial statements. Such reclassifications have no impact on previously reported net income (loss), stockholders’/unitholders’ equity (deficit) or cash flows. See Note 4 for additional information.

In addition, during the third quarter of 2017, the Company corrected its allocation of value between proved and unproved oil and natural gas properties initially recorded as part of fresh start accounting (see Note 3) resulting in a reclassification of approximately $459 million from proved properties to unproved properties as of February 28, 2017. As a result, during the third quarter of 2017, the Company also recorded pretax out-of-period corrections of approximately $8 million to reduce depletion expense and approximately $1 million to increase net gains on sale of assets (combined $5 million after tax), as well as approximately $8 million to increase income from discontinued operations, net of income taxes, related to errors in the first and second quarters of 2017. The Company concluded that the correction of the errors was not material to these or any previously issued financial statements.

Bankruptcy Accounting

The condensed consolidated financial statements have been prepared as if the Company will continue as 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 December 31, 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.

Upon emergence from bankruptcy on February 28, 2017, the Company adopted fresh start accounting which resulted in the Company becoming a new entity for financial reporting purposes. As a result of the application of fresh start accounting and the effects of the implementation of the plan of reorganization, the condensed consolidated financial statements on or after February 28, 2017, are not comparable with the condensed consolidated financial statements prior to that date. See Note 3 for additional information.

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. In addition, as part of fresh start accounting, the Company made estimates and assumptions related to its reorganization value, liabilities subject to compromise, the fair value of assets and liabilities recorded as a result of the adoption of fresh start accounting and income taxes.

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.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Recently Issued Accounting Standards

In November 2016, the Financial Accounting Standards Board (“FASB”) issued an Accounting Standards Update (“ASU”) that is intended to address diversity in the classification and presentation of changes in restricted cash on the statement of cash flows. This ASU will be applied retrospectively as of the date of adoption and is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years (early adoption permitted). The Company is currently evaluating the impact of the adoption of this ASU on its financial statements and related disclosures. The adoption of this ASU is expected to result in the inclusion of restricted cash in the beginning and ending balances of cash on the statements of cash flows and disclosure reconciling cash and cash equivalents presented on the balance sheets to cash, cash equivalents and restricted cash on the statements of cash flows.

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~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

In March 2016, the FASB issued an 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. The Company adopted this ASU on January 1, 2017. The adoption of this ASU had no impact on the Company’s historical financial statements or related disclosures. Upon adoption and subsequently this ASU will result in excess tax benefits, which were previously recorded in equity on the balance sheets and classified as financing activities on the statements of cash flows, being recorded in the statements of operations and classified as operating activities on the statements of cash flows. Additionally, the Company elected to begin accounting for forfeitures as they occur.

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 financial statements and related disclosures. The Company expects the adoption of this ASU to impact its balance sheets resulting from an increase in both assets and liabilities related to the Company’s leasing activities.

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 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 does not plan to early adopt this ASU. The Company is currently evaluating the impact of the adoption of this ASU on its financial statements and related disclosures. The Company expects to use the cumulative-effect transition method, has completed an initial review of its contracts and is developing accounting policies to address the provisions of the ASU, but has not finalized any estimates of the potential impacts.

Note 2 – Emergence From Voluntary Reorganization Under Chapter 11

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 were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16‑60040.

On December 3, 2016, the LINN Debtors filed the Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and Its Debtor Affiliates Other Than Linn Acquisition Company, LLC (“LAC”) and Berry Petroleum Company, LLC (the “Plan”). The LINN Debtors subsequently filed amended versions of the Plan with the Bankruptcy Court.

On December 13, 2016, LAC and Berry filed the Amended Joint Chapter 11 Plan of Reorganization of Linn Acquisition Company, LLC and Berry Petroleum Company, LLC (the “Berry Plan” and together with the Plan, the “Plans”). LAC and Berry subsequently filed amended versions of the Berry Plan with the Bankruptcy Court.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Plans became effective in accordance with their respective terms and LINN Energy and Berry emerged from bankruptcy as stand-alone, unaffiliated entities.

Plan of Reorganization

In accordance with the Plan, on the Effective Date:

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~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

outstanding equity interests of the Successor, which the Predecessor distributed to certain of its creditors in satisfaction of their claims. Contemporaneously with the reorganization transactions and pursuant to the Plan, (i) LAC assigned all of its rights, title and interest in the membership interests of Berry to Berry Petroleum Corporation, (ii) all of the equity interests in LAC and the Predecessor were canceled and (iii) LAC and the Predecessor commenced liquidation, which is expected to be completed following the resolution of the respective companies’ outstanding claims.

The holders of claims under the Predecessor’s Sixth Amended and Restated Credit Agreement (“Predecessor Credit Facility”) received a full recovery, consisting of a cash paydown and their pro rata share of the $1.7 billion Successor Credit Facility. As a result, all outstanding obligations under the Predecessor Credit Facility were canceled.

Holdco II, as borrower, entered into the Successor Credit Facility with the holders of claims under the Predecessor Credit Facility, as lenders, and Wells Fargo Bank, National Association, as administrative agent, providing for a new reserve-based revolving loan with up to $1.4 billion in borrowing commitments and a new term loan in an original principal amount of $300 million. For additional information about the Successor Credit Facility, see Note 6.7.

The holders of the Company’s 12.00% senior secured second lien notes due December 2020 (the “Second Lien Notes”) received their pro rata share of (i) 17,678,889 shares of Class A common stock; (ii) certain rights to purchase shares of Class A common stock in the rights offerings, as described below; and (iii) $30 million in cash. The holders of the Company’s 6.50% senior notes due May 2019, 6.25% senior notes due November 2019, 8.625% senior notes due 2020, 7.75% senior notes due February 2021 and 6.50% senior notes due September 2021 (collectively, the “Unsecured Notes”) received their pro rata share of (i) 26,724,396 shares of Class A common stock; and (ii) certain rights to purchase shares of Class A common stock in the rights offerings, as described below. As a result, all outstanding obligations under the Second Lien Notes and the Unsecured Notes and the indentures governing such obligations were canceled.

The holders of general unsecured claims (other than claims relating to the Second Lien Notes and the Unsecured Notes) against the LINN Debtors (the “LINN Unsecured Claims”) received their pro rata share of cash from two cash distribution pools totaling $40 million, as divided between a $2.3 million cash distribution pool for the payment in full of allowed LINN Unsecured Claims in an amount equal to $2,500 or less (and larger claims for which the holders irrevocably agreed to reduce such claims to $2,500), and a ~~$37.7~~$37.7 million cash distribution pool for pro rata distributions to all remaining allowed general LINN Unsecured Claims. As a result, all outstanding LINN Unsecured Claims were fully satisfied, settled, released and discharged as of the Effective Date.

All units of the Predecessor that were issued and outstanding immediately prior to the Effective Date were extinguished without recovery. On the Effective Date, the Successor issued in the aggregate 89,229,892 shares of Class A common stock. No cash was raised from the issuance of the Class A common stock on account of claims held by the Predecessor’s creditors.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The Successor entered into a registration rights agreement with certain parties, pursuant to which the Company agreed to, among other things, file a registration statement with the SEC within 60 days of the Effective Date covering the offer and resale of “Registrable Securities” (as defined therein).

By operation of the Plan and the Confirmation Order, the terms of the Predecessor’s board of directors expired as of the Effective Date. The Successor formed a new board of directors, consisting of the Chief Executive Officer of the Predecessor, one director selected by the Successor and five directors selected by a six-person selection committee.

Rights Offerings

On October 25, 2016, the Company entered into a backstop commitment agreement (“Backstop Commitment Agreement”) with the parties thereto (collectively, the “Backstop Parties”). In accordance with the Plan, the Backstop Commitment Agreement and the rights offerings procedures filed in the Chapter 11 cases and approved by the Bankruptcy Court, the LINN Debtors offered eligible creditors the right to purchase Class A common stock upon emergence from the Chapter 11 cases for an aggregate purchase price of $530 million.

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~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Under the Backstop Commitment Agreement, certain Backstop Parties agreed to purchase their pro rata share of the shares that were not duly subscribed to pursuant to the offerings at the discounted per share price set forth in the Backstop Commitment Agreement by parties other than Backstop ~~Parties (the “Backstop Commitment”).~~Parties. Pursuant to the Backstop Commitment Agreement, the LINN Debtors agreed to pay the Backstop Parties on the Effective Date a commitment premium equal to 4.0% of the $530 million committed amount, ~~(the “Backstop Commitment Premium”),~~ of which 3.0% was paid in cash and 1.0% was paid in the form of Class A common stock at the discounted per share price set forth in the Backstop Commitment Agreement.

On the Effective Date, all conditions to the rights offerings and the Backstop Commitment Agreement were met, and the LINN Debtors completed the rights offerings and the related issuances of Class A common stock.

Liabilities Subject to Compromise

The Predecessor’s condensed consolidated balance sheet as of December 31, 2016, includes amounts classified as “liabilities subject to compromise,” which represent prepetition liabilities that were allowed, or that the Company estimated would be allowed, as claims in its Chapter 11 cases. The following table summarizes the components of liabilities subject to compromise included on the condensed consolidated balance sheet:



	Predecessor
	December 31, 2016
	(in thousands)

Accounts payable and accrued expenses	$	137,692
Accrued interest payable	144,184
Debt	4,023,129
Liabilities subject to compromise	$	4,305,005

Reorganization Items, Net

The Company incurred significant costs and recognized significant gains associated with the reorganization. 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 were determined. The following tables summarize the components of reorganization items included on the condensed consolidated statements of operations:

Successor Predecessor
Three Months Ended June 30, 2017 Three Months Ended June 30, 2016
(in thousands)
Legal and other professional advisory fees $ (3,446 ) $ (13,451 )
Unamortized deferred financing fees, discounts and premiums —
(52,045 )
Gain related to interest payable on Predecessor’s Second Lien Notes —
551,000
Other 69
294
Reorganization items, net $ (3,377 ) $ 485,798

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Gain on settlement of liabilities subject to compromise $ —
$ 3,724,750
$ —
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement —
(1,000,000 ) —
Fresh start valuation adjustments —
(591,525 ) —
Income tax benefit related to implementation of the Plan —
264,889
—
Legal and other professional advisory fees (6,016 ) (46,961 ) (13,451 )
Unamortized deferred financing fees, discounts and premiums —
—
(52,045 )
Gain related to interest payable on Predecessor’s Second Lien Notes —
—
551,000
Terminated contracts —
(6,915 ) —
Other 74
(13,049 ) 294
Reorganization items, net $ (5,942 ) $ 2,331,189
$ 485,798



	Successor			Predecessor
	Three Months Ended September 30, 2017			Three Months Ended September 30, 2016
(in thousands)
Legal and other professional advisory fees	$	(2,549	)	$	(16,714	)
Terminated contracts	—			(13,123		)
Other	(56		)	1,476
Reorganization items, net	$	(2,605	)	$	(28,361	)



	Successor			Predecessor
	Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Gain on settlement of liabilities subject to compromise	$	—		$	3,724,750		$	—
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement	—			(1,000,000		)	—
Fresh start valuation adjustments	—			(591,525		)	—
Income tax benefit related to implementation of the Plan	—			264,889			—
Legal and other professional advisory fees	(8,565		)	(46,961		)	(30,165		)
Unamortized deferred financing fees, discounts and premiums	—			—			(52,045		)
Gain related to interest payable on Predecessor’s Second Lien Notes	—			—			551,000
Terminated contracts	—			(6,915		)	(13,123		)
Other	18			(13,049		)	1,770
Reorganization items, net	$	(8,547	)	$	2,331,189		$	457,437

Note 3 – Fresh Start Accounting

Upon the Company’s emergence from Chapter 11 bankruptcy, it adopted fresh start accounting in accordance with the provisions of ASC 852 which resulted in the Company becoming a new entity for financial reporting purposes. In accordance with ASC 852, the Company was required to adopt fresh start accounting upon its emergence from Chapter 11 because (i) the holders of existing voting ownership interests of the Predecessor received less than 50% of the voting shares of the Successor and (ii) the reorganization value of the Company’s assets immediately prior to confirmation of the Plan was less than the total of all post-petition liabilities and allowed claims.

Upon adoption of fresh start accounting, the reorganization value derived from the enterprise value as disclosed in the Plan was allocated to the Company’s assets and liabilities based on their fair values (except for deferred income taxes) in accordance with ASC 805 “Business Combinations” (“ASC 805”). The amount of deferred income taxes recorded was determined in accordance with ASC 740 “Income Taxes” (“ASC 740”). The Effective Date fair values of the Company’s assets and liabilities differed materially from their recorded values as reflected on the historical balance sheet. The effects of the Plan and the application of fresh start accounting were reflected on the condensed consolidated balance sheet as of February 28, 2017, and the related adjustments thereto were recorded on the condensed consolidated statement of operations for the two months ended February 28, 2017.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

As a result of the adoption of fresh start accounting and the effects of the implementation of the Plan, the Company’s condensed consolidated financial statements subsequent to February 28, 2017, are not comparable to its condensed consolidated financial statements prior to February 28, 2017. References to “Successor” relate to the financial position and results of operations of the reorganized Company as of and subsequent to February 28, 2017. References to “Predecessor” relate to the financial position of the Company prior to, and results of operations through and including, February 28, 2017.

The Company’s condensed consolidated financial statements and related footnotes are presented with a black line division, which delineates the lack of comparability between amounts presented after February 28, 2017, and amounts presented on or prior to February 28, 2017. The Company’s financial results for future periods following the application of fresh start accounting will be different from historical trends and the differences may be material.

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~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Reorganization Value

Under ASC 852, the Successor determined a value to be assigned to the equity of the emerging entity as of the date of adoption of fresh start accounting. The Plan confirmed by the Bankruptcy Court estimated an enterprise value of $2.35 billion. The Plan enterprise value was prepared using an asset based methodology, as discussed further below. The enterprise value was then adjusted to determine the equity value of the Successor of approximately $2.03 billion. Adjustments to determine the equity value are presented below (in thousands):



Plan confirmed enterprise value	$	2,350,000
Fair value of debt	(900,000		)
Fair value of subsequently determined tax attributes	621,486
Fair value of vested Class B units	(36,505		)
Value of Successor’s stockholders’ equity	$	2,034,981

The subsequently determined tax attributes were primarily the result of the conversion from a limited liability company to a C corporation and differences in the accounting basis and tax basis of the Company’s oil and natural gas properties as of the Effective Date. The Class B units are incentive interest awards that were granted on the Effective Date by Holdco to certain members of its management (see Note ~~12)~~14), and the associated fair value was recorded as a liability of approximately $7 million in “other accrued liabilities” and temporary equity of approximately $29 million in “redeemable noncontrolling interests” on the condensed consolidated balance sheet at February 28, 2017.

The ~~Company's~~Company’s principal assets are its oil and natural gas properties. The fair values of oil and natural gas properties were estimated 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 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. The underlying commodity prices embedded in the Company’s estimated cash flows are the product of a process that begins with New York Mercantile Exchange (“NYMEX”) forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Company management believes will impact realizable prices.

See below under “Fresh Start Adjustments” for additional information regarding assumptions used in the valuation of the Company's various other significant assets and liabilities.

Condensed Consolidated Balance Sheet

The adjustments included in the following fresh start condensed consolidated balance sheet reflect the effects of the transactions contemplated by the Plan and executed by the Company on the Effective Date (reflected in the column “Reorganization Adjustments”) as well as fair value and other required accounting adjustments resulting from the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes provide additional information with regard to the adjustments recorded, the methods used to determine the fair values and significant assumptions.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)



	As of February 28, 2017
	Predecessor			Reorganization Adjustments ⁽¹⁾				Fresh Start Adjustments				Successor
	(in thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	734,166		$	(679,811	)	⁽²⁾	$	—			$	54,355
Accounts receivable – trade, net	212,099			—				(7,808		)	⁽¹⁶⁾	204,291
Derivative instruments	15,391			—				—				15,391
Restricted cash	1,602			80,164			⁽³⁾	—				81,766
Other current assets	106,426			(15,983		)	⁽⁴⁾	1,780			⁽¹⁷⁾	92,223
Total current assets	1,069,684			(615,630		)		(6,028		)		448,026

Noncurrent assets:
Oil and natural gas properties (successful efforts method)	13,269,035			—				(11,082,258		)	⁽¹⁸⁾	2,186,777
Less accumulated depletion and amortization	(10,044,240		)	—				10,044,240			⁽¹⁸⁾	—
	3,224,795			—				(1,038,018		)		2,186,777

Other property and equipment	641,586			—				(197,653		)	⁽¹⁹⁾	443,933
Less accumulated depreciation	(230,952		)	—				230,952			⁽¹⁹⁾	—
	410,634			—				33,299				443,933

Derivative instruments	4,492			—				—				4,492
Deferred income taxes	—			264,889			⁽⁵⁾	356,597			⁽⁵⁾	621,486
Other noncurrent assets	15,003			151			⁽⁶⁾	8,139			⁽²⁰⁾	23,293
	19,495			265,040				364,736				649,271
Total noncurrent assets	3,654,924			265,040				(639,983		)		3,279,981
Total assets	$	4,724,608		$	(350,590	)		$	(646,011	)		$	3,728,007

LIABILITIES AND EQUITY (DEFICIT)
Current liabilities:
Accounts payable and accrued expenses	$	324,585		$	41,266		⁽⁷⁾	$	(2,351	)	⁽²¹⁾	$	363,500
Derivative instruments	7,361			—				—				7,361
Current portion of long-term debt, net	1,937,822			(1,912,822		)	⁽⁸⁾	—				25,000
Other accrued liabilities	41,251			(1,026		)	⁽⁹⁾	1,104			⁽²²⁾	41,329
Total current liabilities	2,311,019			(1,872,582		)		(1,247		)		437,190

Derivative instruments	2,116			—				—				2,116
Long-term debt	—			875,000			⁽¹⁰⁾	—				875,000
Other noncurrent liabilities	402,776			(167		)	⁽¹¹⁾	(53,239		)	⁽²³⁾	349,370
Liabilities subject to compromise	4,301,912			(4,301,912		)	⁽¹²⁾	—				—

Temporary equity:
Redeemable noncontrolling interests	—			29,350			⁽¹³⁾	—				29,350

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)



	As of February 28, 2017
	Predecessor			Reorganization Adjustments ⁽¹⁾				Fresh Start Adjustments				Successor
Stockholders’/unitholders’ equity (deficit):
Predecessor units issued and outstanding	5,386,812			(5,386,812		)	⁽¹⁴⁾	—				—
Predecessor accumulated deficit	(7,680,027		)	2,884,740			⁽¹⁵⁾	4,795,287			⁽²⁴⁾	—
Successor Class A common stock	—			89			⁽¹⁴⁾	—				89
Successor additional paid-in capital	—			7,421,704			⁽¹⁴⁾	(5,386,812		)	⁽²⁴⁾	2,034,892
Successor retained earnings	—			—				—				—
Total stockholders’/unitholders’ equity (deficit)	(2,293,215		)	4,919,721				(591,525		)		2,034,981
Total liabilities and equity (deficit)	$	4,724,608		$	(350,590	)		$	(646,011	)		$	3,728,007

Reorganization Adjustments:

Represent amounts recorded as of the Effective Date for the implementation of the Plan, including, among other items, settlement of the Predecessor’s liabilities subject to compromise, repayment of certain of the Predecessor’s debt, cancellation of the Predecessor’s equity, issuances of the Successor’s Class A common stock, proceeds received from the Successor’s rights offerings and issuance of the Successor’s debt.


2)	Changes in cash and cash equivalents included the following:



(in thousands)
Borrowings under the Successor’s revolving loan	$	600,000
Borrowings under the Successor’s term loan	300,000
Proceeds from rights offerings	530,019
Removal of restriction on cash balance	1,602
Payment to holders of claims under the Predecessor Credit Facility	(1,947,357		)
Payment to holders of claims under the Second Lien Notes	(30,000		)
Payment of Berry’s ad valorem taxes	(23,366		)
Payment of the rights offerings backstop commitment premium	(15,900		)
Payment of professional fees	(13,043		)
Funding of the professional fees escrow account	(41,766		)
Funding of the general unsecured claims cash distribution pool	(40,000		)
Changes in cash and cash equivalents	$	(679,811	)


3)	Primarily reflects the transfer to restricted cash to fund the Predecessor’s professional fees escrow account and general unsecured claims cash distribution pool.


4)	Primarily reflects the write-off of the Predecessor’s deferred financing fees.


5)	Reflects deferred tax assets recorded as of the Effective Date as determined in accordance with ASC 740. The deferred tax assets were primarily the result of the conversion from a limited liability company to a C corporation and differences in the accounting basis and tax basis of the Company’s oil and natural gas properties as of the Effective Date.


6)	Reflects the capitalization of deferred financing fees related to the Successor’s revolving loan.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)


7)	Net increase in accounts payable and accrued expenses reflects:



(in thousands)
Recognition of payables for the professional fees escrow account	$	41,766
Recognition of payables for the general unsecured claims cash distribution pool	40,000
Payment of professional fees	(17,130		)
Payment of Berry’s ad valorem taxes	(23,366		)
Other	(4		)
Net increase in accounts payable and accrued expenses	$	41,266


8)	Reflects the settlement of the Predecessor Credit Facility through repayment of approximately $1.9 billion, net of the write-off of deferred financing fees and an increase of $25 million for the current portion of the Successor’s term loan.


9)	Reflects a decrease of approximately $8 million for the payment of accrued interest on the Predecessor Credit Facility partially offset by an increase of approximately $7 million related to noncash share-based compensation classified as a liability related to the incentive interest awards issued by Holdco to certain members of its management (see Note ~~12)~~14).


10)	Reflects borrowings of $900 million under the Successor Credit Facility, which includes a $600 million revolving loan and a $300 million term loan, net of $25 million for the current portion of the Successor’s term loan.


11)	Reflects a reduction in deferred tax liabilities as determined in accordance with ASC 740.


12)	Settlement of liabilities subject to compromise and the resulting net gain were determined as follows:



(in thousands)
Accounts payable and accrued expenses	$	134,599
Accrued interest payable	144,184
Debt	4,023,129
Total liabilities subject to compromise	4,301,912
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement	1,000,000
Funding of the general unsecured claims cash distribution pool	(40,000		)
Payment to holders of claims under the Second Lien Notes	(30,000		)
Issuance of Class A common stock to creditors	(1,507,162		)
Gain on settlement of liabilities subject to compromise	$	3,724,750


13)	Reflects redeemable noncontrolling interests classified as temporary equity related to the incentive interest awards issued by Holdco to certain members of its management. See Note ~~12 and Note 17~~14 for additional information.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)


14)	Net increase in capital accounts reflects:



(in thousands)
Issuance of Class A common stock to creditors	$	1,507,162
Issuance of Class A common stock pursuant to the rights offerings	530,019
Payment of the rights offerings backstop commitment premium	(15,900		)
Payment of issuance costs	(50		)
Share-based compensation expenses	13,750
Cancellation of the Predecessor’s units issued and outstanding	5,386,812
Par value of Class A common stock	(89		)
Change in additional paid-in capital	7,421,704
Par value of Class A common stock	89
Predecessor’s units issued and outstanding	(5,386,812		)
Net increase in capital accounts	$	2,034,981

See Note 1112 for additional information on the issuances of the Successor’s equity.


15)	Net decrease in accumulated deficit reflects:



(in thousands)
Recognition of gain on settlement of liabilities subject to compromise	$	3,724,750
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement	(1,000,000		)
Recognition of professional fees	(37,680		)
Write-off of deferred financing fees	(16,728		)
Recognition of deferred income taxes	264,889
Total reorganization items, net	2,935,231
Share-based compensation expenses	(50,255		)
Other	(236		)
Net decrease in accumulated deficit	$	2,884,740

Fresh Start Adjustments:


16)	Reflects a change in accounting policy from the entitlements method to the sales method for natural gas production imbalances.


17)	Reflects the recognition of intangible assets for the current portion of favorable leases, partially offset by decreases for well equipment inventory and the write-off of historical intangible assets.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)


18)	Reflects a decrease of oil and natural gas properties, based on the methodology discussed above, and the elimination of accumulated depletion and amortization. The following table summarizes the components of oil and natural gas properties as of the Effective Date:


	Successor		Predecessor			Successor		Predecessor
	Fair Value		Historical Book Value			Fair Value		Historical Book Value
(in thousands)
Proved properties	$	2,186,777	$	12,258,835		$	1,727,834	$	12,258,835
Unproved properties	—		1,010,200			458,943		1,010,200
	2,186,777		13,269,035			2,186,777		13,269,035
Less accumulated depletion and amortization	—		(10,044,240		)	—		(10,044,240		)
	$	2,186,777	$	3,224,795		$	2,186,777	$	3,224,795


19)	Reflects a decrease of other property and equipment and the elimination of accumulated depreciation. The following table summarizes the components of other property and equipment as of the Effective Date:



	Successor		Predecessor
	Fair Value		Historical Book Value
(in thousands)
Natural gas plants and pipelines	$	342,924	$	426,914
Office equipment and furniture	39,211		106,059
Buildings and leasehold improvements	32,817		66,023
Vehicles	16,980		30,760
Land	7,747		3,727
Drilling and other equipment	4,254		8,103
	443,933		641,586
Less accumulated depreciation	—		(230,952		)
	$	443,933	$	410,634

In estimating the fair value of other property and equipment, the Company used a combination of cost and market approaches. A cost approach was used to value the Company’s natural gas plants and pipelines and other operating assets, based on current replacement costs of the assets less depreciation based on the estimated economic useful lives of the assets and age of the assets. A market approach was used to value the Company’s vehicles and land, using recent transactions of similar assets to determine the fair value from a market participant perspective.

20)

Reflects the recognition of intangible assets for the noncurrent portion of favorable leases, as well as increases in equity method investments and carbon credit allowances. Assets and liabilities for out-of-market contracts were valued based on market terms as of February 28, 2017, and will be amortized over the remaining life of the respective lease. The Company’s equity method investments were valued based on a market approach using a market EBITDA multiple. Carbon credit allowances were valued using a market approach based on trading prices for carbon credits on February 28, 2017.


21)	Primarily reflects the write-off of deferred rent partially offset by an increase in carbon emissions liabilities.


22)	Reflects an increase of the current portion of asset retirement obligations.


23)	Primarily reflects a decrease of approximately $49 million for asset retirement obligations and approximately $5 million for deferred rent, partially offset by an increase of approximately $1 million for carbon emissions liabilities. The fair value of asset retirement obligations were estimated using valuation techniques that convert future cash flows to a single

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

~~of asset retirement obligations were 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. Carbon emissions liabilities were valued using a market approach based on trading prices for carbon credits on February 28, 2017.


24)	Reflects the cumulative impact of the fresh start accounting adjustments discussed above and the elimination of the Predecessor’s accumulated deficit.

Note 4 – Discontinued Operations, Other Divestitures and ~~Joint Venture~~Roan Contribution

Discontinued Operations

On July 31, 2017, the Company completed the sale of its interest in properties located in the San Joaquin Basin in California to Berry Petroleum Company, LLC (the “San Joaquin Basin Sale”) ~~and~~. Cash proceeds received ~~cash proceeds~~from the sale of these properties were approximately $253 million, net of costs to sell of approximately ~~$257~~$4 million, and the Company recognized a net gain of approximately $120 million. The gain is included in “income (loss) from discontinued operations, net of income taxes” on the condensed consolidated statements of operations.

On July 21, 2017, the Company completed the sale of its interest in properties located in the Los Angeles Basin in California to Bridge Energy LLC (the “Los Angeles Basin Sale”) ~~and~~. Cash proceeds received ~~cash proceeds~~from the sale of these properties were approximately $93 million, net of costs to sell of approximately ~~$94~~$1 million, and the Company recognized a net gain of approximately $2 million. The gain is included in “income (loss) from discontinued operations, net of income taxes” on the condensed consolidated statements of operations. The Company will receive an additional $7 million contingent payment if certain operational requirements are satisfied within one year.

As a result of the Company’s strategic exit from California (completed by the San Joaquin Basin Sale and Los Angeles Basin Sale), the Company classified the assets and liabilities, results of operations and cash flows of its California properties as discontinued operations on its condensed consolidated financial statements.

On December 3, 2016, LINN Energy filed an amended plan of reorganization that excluded Berry (see Note 2). As a result of its loss of control of Berry, LINN Energy concluded that it was appropriate to deconsolidate Berry effective on the aforementioned date and classified it as discontinued operations.

The following table presents carrying amounts of the assets and liabilities of the Company’s California properties classified as discontinued operations on the condensed consolidated balance ~~sheets:~~sheet:

Successor Predecessor
June 30, 2017 December 31, 2016
(in thousands)
Assets:
Oil and natural gas properties $ 213,442
$ 728,190
Other property and equipment 11,339
11,402
Other 10,862
1,435
Total assets of discontinued operations $ 235,643
$ 741,027
Liabilities:
Asset retirement obligations $ 26,774
$ 38,042
Other 1,444
1,481
Total liabilities of discontinued operations $ 28,218
$ 39,523

All balances of discontinued operations on the condensed consolidated balance sheets relate to the Company’s California properties, as Berry was deconsolidated effective December 3, 2016. At June 30, 2017, the carrying values of the California properties were reduced to fair value less costs to sell, resulting in an impairment charge of approximately $13 million for the three months and four months ended June 30, 2017. The impairment charge is included in “income (loss) from discontinued



	Predecessor
	December 31, 2016
(in thousands)
Assets:
Oil and natural gas properties	$	728,190
Other property and equipment	11,402
Other	1,435
Total assets of discontinued operations	$	741,027
Liabilities:
Asset retirement obligations	$	38,042
Other	1,481
Total liabilities of discontinued operations	$	39,523

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

~~operations, net~~All balances of income taxes” on the condensed consolidated statements of operations. Other assets primarily include restricted cash and inventories, and other liabilities primarily include carbon emissions liabilities. All assets and liabilities related to the California properties were classified as currentdiscontinued operations on the condensed consolidated balance sheet relate to the Company’s California properties, as ~~of June 30, 2017.~~Berry was deconsolidated effective December 3, 2016.

The following tables present summarized financial results of the Company’s California properties and Berry classified as discontinued operations on the condensed consolidated statements of operations:


	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Three Months Ended September 30, 2017			Three Months Ended September 30, 2016
(in thousands)
Revenues and other	$	20,511		$	129,245		$	6,048		$	133,163
Expenses	25,935			156,176			(11,113		)	132,387
Other income and (expenses)	(2,074		)	(18,190		)	(750		)	(14,891		)
Reorganization items, net	—			49,086			—			(87,915		)
Income (loss) from discontinued operations before income taxes	(7,498		)	3,965			16,411			(102,030		)
Income tax expense (benefit)	(4,176		)	164
Income tax expense							6,347			34
Income (loss) from discontinued operations, net of income taxes	$	(3,322	)	$	3,801		$	10,064		$	(102,064	)


	Successor			Predecessor						Successor			Predecessor
	Four Months Ended June 30, 2017			Two Months Ended February 28, 2017			Six Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Revenues and other	$	27,636		$	14,891		$	235,949		$	33,684		$	14,891		$	369,112
Expenses	30,344			13,758			1,375,480			19,231			13,758			1,507,867
Other income and (expenses)	(2,791		)	(1,681		)	(39,470		)	(3,541		)	(1,681		)	(54,361		)
Reorganization items, net	—			—			49,086			—			—			(38,829		)
Loss from discontinued operations before income taxes	(5,499		)	(548		)	(1,129,915		)
Income tax expense (benefit)	(2,245		)	—			162
Loss from discontinued operations, net of income taxes	$	(3,254	)	$	(548	)	$	(1,130,077	)
Income (loss) from discontinued operations before income taxes										10,912			(548		)	(1,231,945		)
Income tax expense										4,102			—			196
Income (loss) from discontinued operations, net of income taxes										$	6,810		$	(548	)	$	(1,232,141	)

In addition, for the three months and seven months ended September 30, 2017, the Company recognized a net gain on the sale of the California properties of approximately $76 million (net of income tax expense of approximately $46 million).

Results of operations of Berry are only included in the three months and ~~six~~nine months ended ~~June~~September 30, 2016, as Berry was deconsolidated effective December 3, 2016. Other income and (expenses) include an allocation of interest expense for the California properties of approximately $1 million and $2 million for ~~each of~~ the three months ended ~~June~~September 30, 2017, and ~~June~~September 30, 2016, respectively, and approximately $3$4 million, $2 million and $3$6 million for the ~~four~~seven months ended ~~June~~September 30, 2017, the two months ended February 28, 2017, and the ~~six~~nine months ended ~~June~~September 30, 2016, respectively, which represents interest on debt that was required to be repaid as a result of the sales.

Berry Transition Services and Separation Agreement

On the Effective Date, Berry entered into a Transition Services and Separation Agreement (the “TSSA”) with LINN Energy and certain of its subsidiaries to facilitate the separation of Berry’s operations from LINN Energy’s operations. Pursuant to the TSSA, LINN Energy continued to provide, or caused to be provided, certain administrative, management, operating, and other services and support to Berry during a transitional period following the Effective Date (the “Transition Services”).

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Under the TSSA, Berry reimbursed LINN Energy for any and all reasonable, third-party out-of-pocket costs and expenses, without markup, actually incurred by LINN Energy, to the extent documented, in connection with providing the Transition Services. Additionally, Berry paid to LINN Energy a management fee of $6 million per month, prorated for partial months, during the period from the Effective Date through the last day of the second full calendar month after the Effective Date (the “Transition Period”) and paid $2.7 million per month, prorated for partial months, from the first day following the Transition Period through the last day of the second full calendar month thereafter (the “Accounting Period”). During the Accounting Period, the scope of the Transition Services was reduced to specified accounting and administrative functions. The Transition Period ended April 30, 2017, and the Accounting Period ended June 30, 2017.

Other Divestitures

On September 12, 2017, August 1, 2017, and July 31, 2017, the Company completed the sales of its interest in certain properties located in south Texas (the “South Texas Assets Sales”). Combined cash proceeds received from the sale of these properties were approximately $49 million, net of costs to sell of approximately $1 million, and the Company recognized a combined net gain of approximately $14 million.

On August 23, 2017, July 28, 2017, and May 9, 2017, the Company completed the sales of its interest in certain properties located in Texas and New Mexico (the “Permian Assets Sales”). Combined cash proceeds received from the sale of these properties were approximately $31 million and the Company recognized a combined net gain of approximately $29 million.

On June 30, 2017, the Company completed the sale of its interest in properties located in the Salt Creek Field in Wyoming to Denbury Resources Inc. (the “Salt Creek Assets Sale”). Cash proceeds received from the sale of these properties were approximately ~~$76~~$75 million, net of costs to sell of approximately $1 million, and the Company recognized a net gain of approximately ~~$22~~$33 million.

On May 31, 2017, the Company completed the sale of its interest in properties located in western Wyoming to Jonah Energy LLC (the “Jonah Assets Sale”). Cash proceeds received from the sale of these properties were approximately $560 million, net of costs to sell of approximately $6 million, and the Company recognized a net gain of approximately ~~$279~~$272 million.

~~On May 9, 2017, the Company completed the sale of undeveloped acreage located in Ward County, Texas and received cash proceeds of approximately $4 million.~~

The ~~three~~ divestitures discussed above are not presented as discontinued operations because they do not represent a strategic shift that will have a major effect on the Company’s operations and financial results. The gains on these divestitures are included in “gains (losses) on sale of assets and other, net” on the condensed consolidated statements of operations.

Divestitures – ~~Subsequent Events~~

On August 1, 2017, and July 31, 2017, the Company completed the sales of its interest in certain properties located in south Texas (the “South Texas Assets Sales”) related to definitive purchase and sale agreements entered into in June 2017 and received cash proceeds of approximately $9 million and approximately $23 million, respectively.

On July 28, 2017, the Company completed the sale of undeveloped acreage located in Lea and Eddy counties in New Mexico (the “Permian Acreage Sale”) related to a definitive purchase and sale agreement entered into in June 2017 and received cash proceeds of approximately $21 million.

~~Joint Venture –~~ Pending

On ~~June 27,~~October 20, 2017, the Company, through certain of its ~~wholly owned~~ subsidiaries, entered into ana definitive purchase and sale agreement ~~with Citizen Energy II, LLC (“Citizen”)~~to sell its interest in ~~which LINN Energy and Citizen will each contribute certain upstream assets~~properties located in ~~Oklahoma~~the Williston Basin for a contract price of $285 million, subject to closing adjustments.

On October 3, 2017, the Company, through certain of its subsidiaries, entered into a newly formed company, Roan Resources LLC (“Roan”), focused on the accelerated development of the Merge/SCOOP/STACK play in the Mid-Continent region. In exchange for their respective contributions, LINN Energydefinitive purchase and ~~Citizen will equally split the equity~~sale agreement to sell its interest in ~~Roan.~~ properties located in Wyoming for a contract price of $200 million, subject to closing adjustments.

The ~~transaction is~~sales are anticipated to close ~~in the third quarter of~~on November 30, 2017, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied.

~~Assets~~Roan Contribution

On August 31, 2017, the Company, through certain of its subsidiaries, completed the transaction in which LINN Energy and ~~Liabilities Held For Sale~~

~~The~~Citizen Energy II, LLC (“Citizen”) each contributed certain upstream assets located in Oklahoma to a newly formed company, Roan Resources LLC (“Roan” and the contribution, the “Roan Contribution”), focused on the accelerated development of the Merge/SCOOP/STACK play. In exchange for their respective contributions, LINN Energy and Citizen each received a 50% equity interest in Roan, subject to customary post-closing adjustments. As of August 31, 2017, the date of the Roan Contribution, the Company recognized its equity investment at a carryover basis of approximately $452 million. In connection with the Roan Contribution, the Company paid approximately $17 million in advisory fees, which are included in “gains (losses) on sale of assets and liabilities associated with the South Texas Assets Sales and the Permian Acreage Sale, as well as the properties to be contributed in the pending Roan joint venture, are classified as “held for sale”other, net” on the condensed consolidated ~~balance sheet. At June 30, 2017,~~statements of operations.

See Note 6 for additional information about the Company’s ~~condensed consolidated balance sheet included current assets of approximately $236 million included~~equity method investment in ~~“assets held for sale” and current liabilities of approximately $36 million included in “liabilities held for sale” related to these transactions.~~Roan.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

~~The following table presents carrying amounts of the assets and liabilities of the Company’s properties classified as held for sale on the condensed consolidated balance sheet:~~

Successor
June 30, 2017
(in thousands)

Assets:
Oil and natural gas properties $ 224,918
Other property and equipment 11,070
Other 433
Total assets held for sale $ 236,421
Liabilities:
Asset retirement obligations $ 21,210
Other 15,177
Total liabilities held for sale $ 36,387

~~Other assets primarily include inventories and other liabilities primarily include accounts payable.~~

Note 5 – Oil and Natural Gas Properties

Oil and Natural Gas Capitalized Costs

As a result of the application of fresh start accounting, the Company recorded its oil and natural gas properties at fair value as of the Effective Date. The fair values of oil and natural gas properties are estimated 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 and unproved 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. The fair value was estimated using inputs characteristic of a Level 3 fair value measurement. Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:


	Successor			Predecessor			Successor			Predecessor
	June 30, 2017			December 31, 2016			September 30, 2017			December 31, 2016
(in thousands)
Proved properties	$	1,443,916		$	11,350,257		$	1,188,652		$	11,350,257
Unproved properties	194			998,860			59,594			998,860
	1,444,110			12,349,117			1,248,246			12,349,117
Less accumulated depletion and amortization	(37,572		)	(9,843,908		)	(53,370		)	(9,843,908		)
	$	1,406,538		$	2,505,209		$	1,194,876		$	2,505,209

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.

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~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Based on the analysis described above, for the ~~six~~three months and nine months ended ~~June~~September 30, 2016, the Company recorded an impairment ~~charge~~charges of approximately ~~$123~~$42 million and $165 million, respectively, associated with proved oil and natural gas properties in the Mid-Continent ~~region~~and Rockies regions due to a decline in commodity prices, changes in expected capital development and a decline in 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 ~~statement~~statements of operations. The Company recorded no impairment charges for the ~~six~~nine months ended ~~June~~September 30, ~~2017, or the three months ended June 30, 2016.~~2017.

Note 6 – Equity Method Investments

The Company uses the equity method of accounting for its investment in Roan. The Company’s equity earnings (losses) consists of its share of Roan’s earnings or losses and the amortization of the difference between the Company’s investment in Roan and Roan’s underlying net assets attributable to certain assets. At both September 30, 2017, and August 31, 2017 (the date of the Roan Contribution), the Company owned 50% of Roan’s outstanding units. The percentage ownership in Roan is subject to customary post-closing adjustments.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

At September 30, 2017, the carrying amount of the Company’s investment in Roan of approximately $454 million was less than the Company’s ownership interest in Roan’s underlying net assets by approximately $344 million. The difference is attributable to proved and unproved oil and natural gas properties and is amortized over the lives of the related assets. Such amortization is included in the equity earnings (losses) from the Company’s investment in Roan.

Impairment testing on the Company’s investment in Roan is performed when events or circumstances warrant such testing and considers whether there is an inability to recover the carrying value of the investment that is other than temporary. No impairments occurred with respect to the Company’s investment in Roan for the one month ended September 30, 2017.

Following is summarized statement of operations information for Roan.

Summarized Roan Resources LLC Statement of Operations Information



	One Month Ended September 30, 2017
	(in thousands)

Revenues	$	16,819
Expenses	12,145
Other income and (expenses)	(160		)
Net income	$	4,514

Note 7 – Debt

The following summarizes the Company’s outstanding debt:

Successor Predecessor
June 30, 2017 December 31, 2016
(in thousands, except percentages)
Successor revolving loan ⁽¹⁾
$ 183,430
$ —
Predecessor credit facility ⁽²⁾
—
1,654,745
Predecessor term loan ⁽²⁾
—
284,241
6.50% senior notes due May 2019 —
562,234
6.25% senior notes due November 2019 —
581,402
8.625% senior notes due April 2020 —
718,596
12.00% senior secured second lien notes due December 2020 —
1,000,000
7.75% senior notes due February 2021 —
779,474
6.50% senior notes due September 2021 —
381,423
Net unamortized deferred financing fees —
(1,257 )
Total debt, net 183,430
5,960,858
Less current portion, net ⁽³⁾
—
(1,937,729 )
Less liabilities subject to compromise ⁽⁴⁾
—
(4,023,129 )
Long-term debt $ 183,430
$ —



	Successor		Predecessor
	September 30, 2017		December 31, 2016
(in thousands, except percentages)
Revolving credit facility	$	—	$	—
Predecessor credit facility ⁽¹⁾	—		1,654,745
Predecessor term loan ⁽¹⁾	—		284,241
6.50% senior notes due May 2019	—		562,234
6.25% senior notes due November 2019	—		581,402
8.625% senior notes due April 2020	—		718,596
12.00% senior secured second lien notes due December 2020	—		1,000,000
7.75% senior notes due February 2021	—		779,474
6.50% senior notes due September 2021	—		381,423
Net unamortized deferred financing fees	—		(1,257		)
Total debt, net	—		5,960,858
Less current portion, net ⁽²⁾	—		(1,937,729		)
Less liabilities subject to compromise ⁽³⁾	—		(4,023,129		)
Long-term debt	$	—	$	—


⁽¹⁾	~~Variable interest rate of 4.59%at June 30, 2017.~~


⁽²⁾	Variable interest rate of 5.50% at December 31, 2016.


⁽³⁾⁽²⁾	Due to covenant violations, the Predecessor’s credit facility and term loan were classified as current at December 31, 2016.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)


⁽⁴⁾⁽³⁾	The Predecessor’s senior notes and Second Lien Notes were classified as liabilities subject to compromise at December 31, 2016. On the Effective Date, pursuant to the terms of the Plan, all outstanding amounts under these debt instruments were canceled.

Fair Value

The Company’s debt is recorded at the carrying amount on the condensed consolidated balance sheets. The carrying amounts of the credit facilities and term loans approximate fair value because the interest rates are variable and reflective of market rates. The Company used a market approach to determine the fair value of the Predecessor’s 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.



	Predecessor
	December 31, 2016
	Carrying Value		Fair Value
	(in thousands)

Senior secured second lien notes	$	1,000,000	$	863,750
Senior notes, net	3,023,129		1,179,224

Revolving Credit Facility

On August 4, 2017, the Company entered into a credit agreement with Holdco II, as borrower, Royal Bank of Canada, as administrative agent, and the lenders and agents party thereto, providing for a new senior secured reserve-based revolving loan facility (the “Revolving Credit Facility”) with $500 million in borrowing commitments and an initial borrowing base of $500 million.

As of September 30, 2017, there were no borrowings outstanding under the Revolving Credit Facility and there was approximately $455 million of available borrowing capacity (which includes a $45 million reduction for outstanding letters of credit). The maturity date is August 4, 2020.

Redetermination of the borrowing base under the Revolving Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and October, with the first scheduled borrowing base redetermination to occur on March 15, 2018. At the Company’s election, interest on borrowings under the Revolving Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin ranging from 2.50% to 3.50% per annum or the alternate base rate (“ABR”) plus an applicable margin ranging from 1.50% to 2.50% per annum, depending on utilization of the borrowing base. Interest is generally payable in arrears quarterly for loans bearing interest based at the ABR and at the end of the applicable interest period for loans bearing interest at the LIBOR, or if such interest period is longer than three months, at the end of the three month intervals during such interest period. The Company is required to pay a commitment fee to the lenders under the Revolving Credit Facility, which accrues at a rate per annum of 0.50% on the average daily unused amount of the available revolving loan commitments of the lenders.

The obligations under the Revolving Credit Facility are secured by mortgages covering approximately 85% of the total value of the proved reserves of the oil and natural gas properties of the Company and certain of its subsidiaries, along with liens on substantially all personal property of the Company and certain of its subsidiaries, and are guaranteed by the Company, Holdco and certain of Holdco II’s subsidiaries, subject to customary exceptions. Under the Revolving Credit Facility, the Company is required to maintain (i) a maximum total net debt to last twelve months EBITDA ratio of 4.0 to 1.0, and (ii) a minimum adjusted current ratio of 1.0 to 1.0.

The Revolving Credit Facility also contains affirmative and negative covenants, including as to compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and gas engineering reports and budgets, maintenance and operation of property (including oil and gas properties), restrictions on the incurrence of liens and indebtedness, mergers, consolidations and sales of assets, paying

2425

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

dividends or other distributions in respect of, or repurchasing or redeeming, the Company’s capital stock, making certain investments and transactions with affiliates.

Predecessor
December 31, 2016
Carrying Value Fair Value
(in thousands)

Senior secured second lien notes $ 1,000,000
$ 863,750
Senior notes, net 3,023,129
1,179,224
The Revolving Credit Facility contains events of default and remedies customary for credit facilities of this nature. Failure to comply with the financial and other covenants in the Revolving Credit Facility would allow the lenders, subject to customary cure rights, to require immediate payment of all amounts outstanding under the Revolving Credit Facility.

In September 2017, the Company entered into an amendment to the Revolving Credit Facility to provide for, among other things, an increase in the size of the letter of credit subfacility from $25 million to $50 million.

Successor Credit Facility

On the Effective Date, pursuant to the terms of the Plan, the Company entered into the Successor Credit Facility with Holdco II as borrower and Wells Fargo Bank, National Association, as administrative agent, providing for: 1) a reserve-based revolving loan with an initial borrowing base of $1.4 billion and 2) a term loan in an original principal amount of $300 million.

On May 31, 2017, the Company entered into the First Amendment and Consent to Credit Agreement, pursuant to which among other modifications: 1) the term loan was paid in full and terminated using cash proceeds from the Jonah Assets Sale, and 2) the borrowing base for the revolving loan was reduced to $1 billion with additional agreed upon reductions for the Company’s other announced sales. ~~As of June 30, 2017, total borrowings outstanding under~~In connection with the entry into the Revolving Credit Facility, the Successor Credit Facility ~~were approximately $183 million~~was terminated and ~~there was approximately $774 million of remaining available borrowing capacity (which includes a $7 million reduction for outstanding letters of credit). The maturity date is February 27, 2021.~~

~~Redetermination of the borrowing base under the Successor Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually,~~repaid in April and October. The next scheduled borrowing base redetermination is to occur on October 1, 2017. At the Company’s election, interest on borrowings under the Successor Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin of 3.50% per annum or the alternate base rate (“ABR”) plus an applicable margin of 2.50% per annum. Interest is generally payable in arrears monthly for loans bearing interest based at 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 Successor Credit Facility, which accrues at a rate per annum of 0.50% on the average daily unused amount of the available revolving loan commitments of the lenders.

~~Holdco II has the right to prepay any borrowings under the Successor Credit Facility at any time without a prepayment penalty, other than customary “breakage” costs with respect to LIBOR loans.~~

The obligations under the Successor Credit Facility are secured by mortgages covering approximately 95% of the total value of the proved reserves of the oil and natural gas properties of the Company, and certain equipment and facilities associated therewith, along with liens on substantially all personal property of the Company and are guaranteed by the Company, Linn Energy Holdco LLC and Holdco II’s subsidiaries, subject to customary exceptions. Under the Successor Credit Facility, the Company is required to maintain certain financial covenants including the maintenance of (i) a reserve coverage ratio of at least 1.1 to 1.0, tested on (a) the date of each scheduled borrowing base redetermination and (b) the date of each additional borrowing base redetermination done in conjunction with an asset sale, (ii) a maximum total net debt to last twelve months EBITDAX ratio of 4.0 to 1.0 beginning with the quarter ending September 30, 2017, and (iii) a minimum current ratio of 1.0 to 1.0 beginning with the quarter ending September 30, 2017.

The Successor Credit Facility also contains customary affirmative and negative covenants, including as to compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and natural gas engineering reports and budgets, maintenance and operation of property (including oil and natural gas properties), restrictions on the incurrence of liens and indebtedness, mergers, consolidations and sales of assets, transactions with affiliates and other customary covenants.

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

The Successor Credit Facility contains customary events of default and remedies for credit facilities of this nature. Failure to comply with the financial and other covenants in the Successor Credit Facility would allow the lenders, subject to customary cure rights, to require immediate payment of all amounts outstanding under the Successor Credit Facility.full.

Predecessor’s Credit Facility, Second Lien Notes and Senior Notes

On the Effective Date, pursuant to the terms of the Plan, all outstanding obligations under the Predecessor’s credit facility, Second Lien Notes and senior notes were canceled. See Note 2 for additional information.

Predecessor Covenant Violations

The Company’s filing of the Bankruptcy Petitions described in Note 2 constituted an event of default that accelerated the obligations under the Predecessor’s credit facility, Second Lien Notes and senior notes. For the two months ended February 28, 2017, contractual interest, which was not recorded, on the Second Lien Notes and senior notes was approximately $57 million. Under the Bankruptcy Code, the creditors under these debt agreements were stayed from taking any action against the Company as a result of an event of default.

Note 78 – 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. 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 differentials in certain operating areas but does not currently hedge exposure to oil or natural gas 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, collars 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 89 for fair value disclosures about oil and natural gas commodity derivatives.

~~The following table presents derivative positions for the periods indicated as of June 30, 2017:~~

July 1 – December 31, 2017
2018 2019
Natural gas positions:
Fixed price swaps (NYMEX Henry Hub):
Hedged volume (MMMBtu) 68,080
47,815
11,315
Average price ($/MMBtu) $ 3.17
$ 3.01
$ 2.97
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls) 2,208
548
—
Average price ($/Bbl) $ 52.13
$ 54.07
$ —
Collars (NYMEX WTI):
Hedged volume (MBbls) —
1,825
1,825
Average floor price ($/Bbl) $ —
$ 50.00
$ 50.00
Average ceiling price ($/Bbl) $ —
$ 55.50
$ 55.50

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The following table presents derivative positions for the periods indicated as of September 30, 2017:



	October 1 – December 31, 2017		2018		2019
Natural gas positions:
Fixed price swaps (NYMEX Henry Hub):
Hedged volume (MMMBtu)	31,280		47,815		11,315
Average price ($/MMBtu)	$	3.18	$	3.01	$	2.97
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls)	1,104		548		—
Average price ($/Bbl)	$	52.13	$	54.07	$	—
Collars (NYMEX WTI):
Hedged volume (MBbls)	—		1,825		1,825
Average floor price ($/Bbl)	$	—	$	50.00	$	50.00
Average ceiling price ($/Bbl)	$	—	$	55.50	$	55.50

During the ~~four~~seven months ended ~~June~~September 30, 2017, the Company entered into commodity derivative contracts consisting of oil swaps for January 2018 through December 2018 and natural gas swaps for January 2018 through December 2019. The Company did not enter into any commodity derivative contracts during the two months ended February 28, 2017.

In October 2017, or the ~~six months ended June 30, 2016.~~Company entered into commodity derivative contracts consisting of natural gas swaps for January 2018 through December 2018. Including these new hedges, as of October 31, 2017, the Company had natural gas swaps of approximately 69,715 MMMBtu at an average price of approximately $3.02 per MMBtu for 2018.

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 table summarizes the fair value of derivatives outstanding on a gross basis:


	Successor		Predecessor		Successor		Predecessor
	June 30, 2017		December 31, 2016		September 30, 2017		December 31, 2016
(in thousands)
Assets:
Commodity derivatives	$	55,058	$	19,369	$	27,897	$	19,369
Liabilities:
Commodity derivatives	$	18,826	$	113,226	$	17,871	$	113,226

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

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Company’s counterparties are participants in the Revolving Credit Facility or were participants in the Successor Credit Facility or ~~were participants in the~~ Predecessor Credit Facility. The ~~Successor~~Revolving Credit Facility is secured by certain of the Company’s and its subsidiaries’ oil, natural gas and NGL reserves and personal property; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties.

The maximum amount of loss due to credit risk that the Company would incur if its counterparties failed completely to perform according to the terms of the contracts, based on the gross fair value of financial instruments, was approximately ~~$55~~$28 million at ~~June~~September 30, 2017. The Company minimizes the credit risk in derivative instruments by: (i) limiting its exposure to any single counterparty; (ii) entering into derivative instruments only with counterparties that meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity derivatives are subject to counterparty netting under agreements governing such derivatives and therefore the risk of loss due to counterparty nonperformance is somewhat mitigated.

Gains and Losses on Derivatives

Gains and losses on derivatives were net losses of approximately ~~$46 million and $34~~$14 million for the three months ended September 30, 2017, and ~~four~~net gains of approximately $19 million and $93 million for the seven months ended ~~June~~September 30, 2017, ~~respectively,~~ and ~~approximately $93 million for~~ the two months ended February 28, ~~2017. Losses~~2017, respectively. Gains and losses on derivatives were net gains of approximately ~~$184 million~~$166,000 and net losses of approximately $74 million for the three months and ~~six~~nine months ended ~~June~~September 30, 2016, respectively. Gains and losses on derivatives are reported on the condensed consolidated statements of operations in “gains (losses) on oil and natural gas derivatives.”

The Company received net cash settlements of approximately $2$12 million and $8$20 million for the three months and ~~four~~seven months ended ~~June~~September 30, 2017, respectively, and paid net cash settlements of approximately $12 million for the two months ended

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

February 28, 2017. The Company received net cash settlements of approximately ~~$522 million and $856~~$857 million for the nine months ended September 30, 2016. The Company had no cash settlements during the three months ~~and six months~~ ended ~~June~~September 30, ~~2016, respectively.~~2016.

Note 89 – Fair Value Measurements on a Recurring Basis

The Company accounts for its commodity derivatives at fair value (see Note 7)8) 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 and public bond yield 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 into a three-level fair value hierarchy based on the priority of inputs to the valuation technique. 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).

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The following presents the fair value hierarchy for assets and liabilities measured at fair value on a recurring basis:


	Successor							Successor
	June 30, 2017							September 30, 2017
	Level 2		Netting ⁽¹⁾			Total		Level 2		Netting ⁽¹⁾			Total
	(in thousands)							(in thousands)
Assets:
Commodity derivatives	$	55,058	$	(18,340	)	$	36,718	$	27,897	$	(17,095	)	$	10,802
Liabilities:
Commodity derivatives	$	18,826	$	(18,340	)	$	486	$	17,871	$	(17,095	)	$	776



	Predecessor
	December 31, 2016
	Level 2		Netting ⁽¹⁾			Total
	(in thousands)
Assets:
Commodity derivatives	$	19,369	$	(19,369	)	$	—
Liabilities:
Commodity derivatives	$	113,226	$	(19,369	)	$	93,857


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

Note 910 – 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

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

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.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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


Asset retirement obligations at December 31, 2016 (Predecessor)	$	402,162		$	402,162
Liabilities added from drilling	146			146
Accretion expense	4,024			4,024
Settlements	(618		)	(618		)
Asset retirement obligations at February 28, 2017 (Predecessor)	$	405,714		$	405,714
Fresh start adjustment ⁽¹⁾	(48,317		)	(48,317		)
Asset retirement obligations at February 28, 2017 (Successor)	$	357,397		$	357,397
Liabilities added from drilling	277			510
Liabilities associated with assets sold	(43,507		)	(96,349		)
Liabilities associated with assets held for sale	(21,210		)
Liabilities associated with discontinued operations	(26,774		)
Accretion expense	7,107			11,233
Settlements	(3,172		)	(5,406		)
Asset retirement obligations at June 30, 2017 (Successor)	$	270,118
Asset retirement obligations at September 30, 2017 (Successor)				$	267,385


⁽¹⁾	As a result of the application of fresh start accounting, the Successor recorded its asset retirement obligations at fair value as of the Effective Date.

Note 1011 – Commitments and Contingencies

On May 11, 2016, the Debtors filed Bankruptcy Petitions for relief under Chapter 11 of the Bankruptcy Code in the Bankruptcy Court. The Debtors’ Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16‑60040. On January 27, 2017, the Bankruptcy Court entered the Confirmation Order. Consummation of the Plan was subject to certain conditions set forth in the Plan. On the Effective Date, all of the conditions were satisfied or waived and the Plan became effective and was implemented in accordance with its terms. The LINN Debtors Chapter 11 cases will remain pending until the final resolution of all outstanding claims.

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. ~~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.~~ However, the Company is, and will continue to be until the final resolution of all claims, subject to certain contested matters and adversary proceedings stemming from the Chapter 11 proceedings.

In March 2017, Wells Fargo Bank, National Association (“Wells Fargo”), the administrative agent under the Predecessor Credit Facility, filed a motion in the Bankruptcy Court seeking payment of post-petition default interest of approximately $31 million. The Company has vigorously disputed that Wells Fargo is entitled to any default interest based on the plain language of the Plan and Confirmation Order. A hearing was held on April 27, 2017, and ~~the parties are awaiting a ruling from~~on November 13, 2017, the Bankruptcy Court ~~on this matter.~~ruled that the secured lenders are not entitled to payment of post-petition default interest. The ruling is subject to appeal by Wells Fargo.

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.

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

During the ~~six~~nine months ended ~~June~~September 30, 2017, and the ~~six~~nine months ended ~~June~~September 30, 2016, 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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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Note 1112 – Equity (Deficit)

Shares Issued and Outstanding

As of September 30, 2017, there were 84,667,268 shares of Class A common stock issued and outstanding. An additional 622,839 vested but not issued restricted stock units and 2,986,554 unvested restricted stock units were outstanding under the Company’s Omnibus Incentive Plan. As of September 30, 2017, the Company’s consolidated subsidiary, Holdco, had 778,898 vested Class A-2 units and 2,336,693 unvested Class A-2 units, which may be converted into shares of Class A common stock pursuant to the terms of the Limited Liability Company Operating Agreement of Holdco (the “Holdco LLC Agreement”). See Note 14 for additional information related to the restricted stock units and Class A-2 units.

Cancellation of Units and Issuance of Class A Common Stock

In accordance with the Plan, on the Effective Date:

All units in the Predecessor that were issued and outstanding immediately prior to the Effective Date were extinguished without recovery;

17,678,889 shares of Class A common stock were issued pro rata to holders of the Second Lien Notes with claims allowed under the Plan;

26,724,396 shares of Class A common stock were issued pro rata to holders of Unsecured Notes with claims allowed under the Plan;

471,110 shares of Class A common stock were issued to commitment parties under the Backstop Commitment Agreement in respect of premium due thereunder;

2,995,691 shares of Class A common stock were issued to commitment parties under the Backstop Commitment Agreement in connection with their backstop obligation thereunder; and

41,359,806 shares of Class A common stock were issued to participants in the rights offerings extended by the Company to certain holders of claims arising under the Second Lien Notes and the Unsecured Notes (including, in each case, certain of the commitment parties party to the Backstop Commitment Agreement).

With the exception of shares of Class A common stock issued to commitment parties pursuant to their obligations under the Backstop Commitment Agreement, shares of Class A common stock were issued under the Plan pursuant to an exemption from the registration requirements of the Securities Act of 1933, as amended (the “Securities Act”), under Section 1145 of the Bankruptcy Code. Shares of Class A common stock issued to commitment parties pursuant to their obligations under the Backstop Commitment Agreement were issued pursuant to an exemption from the registration requirements of the Securities Act provided by Section 4(a)(2) thereof.

As of the Effective Date, there were 89,229,892 shares of Class A common stock, par value $0.001 per share, issued and outstanding.

Share Repurchase Program

On June 1, 2017, the Company’s Board of Directors announced that it had authorized the repurchase of up to $75 million of the Company’s outstanding shares of Class A common stock. On June 28, 2017, the Company’s Board of Directors announced that it had authorized an increase in the previously announced share repurchase program to up to a total of $200 million of the Company’s outstanding shares of Class A common stock. InAny share repurchases are subject to restrictions in the Revolving Credit Facility. During the period from June 2017 through September 2017, the Company repurchased ~~7,540~~an aggregate of 4,607,598 shares of Class A common stock at an average price of ~~$30.48~~$34.06 per share for a total cost of approximately ~~$230,000.~~

~~In addition, in July 2017, the Company repurchased 833,763 shares of Class A common stock at an average price of $32.43 per share for a total cost of approximately $27~~$157 million.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

On October 4, 2017, the Company’s Board of Directors announced that it had authorized an additional increase in the previously announced share repurchase program to up to a total of $400 million of the Company’s outstanding shares of a Class A common stock. In October 2017, the Company repurchased 590,118 shares of Class A common stock at an average price of $38.09 per share for a total cost of approximately $22 million. At October 31, 2017, approximately $221 million was available for share repurchases under the program.

Dividends/Distributions

Under the Predecessor’s limited liability company agreement, unitholders were entitled to receive a distribution of available cash, which included cash on hand plus borrowings less any reserves established by the Predecessor’s Board of Directors to provide for the proper conduct of the Predecessor’s business (including reserves for future capital expenditures, acquisitions and anticipated future credit needs) or to fund distributions, if any, over the next four quarters. In October 2015, the Predecessor’s Board of Directors determined to suspend payment of the Predecessor’s distribution. The Successor is not currently ~~has no intention~~paying a cash dividend; however, the Board of ~~paying~~Directors periodically reviews the Company’s liquidity position to evaluate whether or not to pay a cash ~~dividends and any~~dividend. Any future payment of cash dividends would be subject to the restrictions in the ~~Successor~~Revolving Credit Facility.

Note 13 – Noncontrolling Interests

Noncontrolling interests represent ownership in the net assets of the Company’s consolidated subsidiary, Holdco, not attributable to LINN Energy. On the Effective Date, Holdco granted incentive interest awards to certain members of its management in the form of Class B units (see Note 14). In accordance with the terms of the Holdco LLC Agreement, on July 31, 2017, all of the Class B units were converted to Class A-2 units of Holdco. At both September 30, 2017, and July 31, 2017 (the date of the conversion), the noncontrolling Class A-2 units represented approximately 0.88% of Holdco’s total outstanding units.

Note 1214 – Share-Based Compensation

The Company had no equity awards outstanding as of December 31, 2016. In accordance with the Plan, in February 2017, the Company implemented the Linn Energy, Inc. 2017 Omnibus Incentive Plan (the “Omnibus Incentive Plan”) pursuant to which employees and consultants of the Company and its affiliates are eligible to receive stock options, restricted stock, performance awards, other stock-based awards and other cash-based awards.

The Committee (as defined in the Omnibus Incentive Plan) has broad authority under the Omnibus Incentive Plan to, among other things: (i) select participants; (ii) determine the types of awards that participants receive and the number of shares that are subject to such awards; and (iii) establish the terms and conditions of awards, including the price (if any) to be paid for the shares or the award. As of the Effective Date, an aggregate of 6,444,381 shares of Class A common stock were reserved for issuance under the Omnibus Incentive Plan (the “Share Reserve”). Additional shares of Class A common stock may be issued in excess of the Share Reserve for the sole purpose of satisfying any conversion of Class ~~B units or Class~~ A‑2 units of Holdco ~~as applicable,~~ into shares of Class A common stock pursuant to the ~~Limited Liability Company Operating~~Holdco LLC Agreement, ~~of Holdco (the “Holdco LLC Agreement”),~~ and the conversion procedures set forth therein. If any stock option or other stock-based award granted under the Omnibus Incentive Plan expires, terminates or is canceled for any reason without having been exercised in full, the number of shares of Class A common stock underlying any unexercised award shall again be available for the purpose of awards under the Omnibus Incentive Plan. If any shares of restricted stock, performance awards or other stock-based awards denominated in shares of Class A common stock awarded under the Omnibus Incentive Plan are forfeited for any reason, the number of forfeited shares shall again be available for purposes of awards under the Omnibus Incentive Plan. Any award under the Omnibus Incentive Plan settled in cash shall not be counted against the maximum share limitation.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

As is customary in incentive plans of this nature, each share limit and the number and kind of shares available under the Omnibus Incentive Plan and any outstanding awards, as well as the exercise or purchase prices of awards, and performance targets under certain types of performance-based awards, are subject to adjustment in the event of certain reorganizations, mergers, combinations, recapitalizations, stock splits, stock dividends or other similar events that change the number or kind of shares outstanding, and extraordinary dividends or distributions of property to the Company’s stockholders.

Restricted Stock Units

On the Effective Date, the Company granted to certain employees 2,478,606 restricted stock units (the “Emergence Awards”). The portion of the Share Reserve that does not constitute the Emergence Awards, plus any subsequent awards forfeited before vesting (the “Remaining Share Reserve”), will be fully granted within the 36-month period immediately following the Effective Date (with such 36-month anniversary, the “Final Allocation Date”). If a Change in Control (as defined in the Omnibus Incentive Plan) occurs before the Final Allocation Date, the Company will allocate the entire Remaining Share Reserve on a fully-vested basis to actively employed employees (pro-rata based upon each such employee’s relative awards) upon the consummation of the Change in Control. During the ~~four~~seven months ended ~~June~~September 30, 2017, the Company granted to certain employees ~~1,255,345~~1,324,750 restricted stock units from the Remaining Share Reserve. The restricted stock units vest over three years.

Upon a participant’s termination of employment and/or service (as applicable), the Company has the right (but not the obligation) to repurchase all or any portion of the shares of Class A common stock acquired pursuant to an award at a price equal to the fair market value (as determined under the Omnibus Incentive Plan) of the shares of Class A common stock to be repurchased, measured as of the date of the Company’s repurchase notice.

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Holdco Incentive Interest Plan

On the Effective Date, Holdco granted incentive interest awards to certain members of its management in the form of 3,470,051 Class B units, which are intended to qualify as “profits interests” for U.S. income tax purposes. The Class B units vested 25% on the Effective Date and the remaining amount vest ratably over the following three years, subject to meeting a performance condition described in the agreements. Each Class B unit represents a non-voting equity interest in Holdco that entitles the holder to Holdco distributions, after an applicable hurdle amount is met, such that each Class B unit only participates in Holdco’s increase in value following the grant date.years. In accordance with the Holdco LLC Agreement, the requirements entitling Class B unitholders to Holdco distributions had not been met as of June 30, 2017. Class B units can be converted at any time by the holder to Class A-2 units of Holdco or Class A common stock of the Company in accordance with the terms of the Holdco LLC ~~Agreement.~~Agreement, on July 31, 2017, all of the Class B units were converted to Class A-2 units of Holdco. The Class A-2 units will continue to vest over three years.

Accounting for Share-Based Compensation

The Company recognizes expense for share-based compensation over the requisite service period in an amount equal to the fair value of share-based awards granted. The fair value of share-based awards, excluding liability awards, is computed at the date of grant and is not remeasured. The fair value of liability awards is remeasured at each reporting date through the settlement date with the change in fair value recognized as compensation expense over that period. The Company has no outstanding liability awards as of September 30, 2017. The Company has made a policy decision to recognize compensation expense for service-based awards on a straight-line basis over the requisite service period for the entire award. Beginning in 2017, the Company accounts for forfeitures as they occur.

The Company’s restricted stock units are equity-classified ~~and its~~on the condensed consolidated balance sheet. The Company’s incentive interest awards in the form of Class B units ~~are~~were liability-classified on the condensed consolidated balance ~~sheet.~~sheet through July 31, 2017 (the date of the conversion to Class A-2 units) and are subsequently equity-classified. The fair value of the Company’s restricted stock units was determined based on the fair value of the Company’s shares on the date of grant and the fair value of the incentive interest awards in the form of Class B units (Class A-2 units upon conversion) was initially determined based on the estimated amount to settle the ~~awards.~~awards and the fair value of the awards at the date of the conversion became the measurement basis from that point forward.

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Share-Based Compensation Expenses

A summary of share-based compensation expenses included on the condensed consolidated statements of operations is presented below:


	Successor		Predecessor		Successor		Predecessor
	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016		Three Months Ended September 30, 2017		Three Months Ended September 30, 2016
(in thousands)
General and administrative expenses	$	15,422	$	4,946	$	6,277	$	4,832
Lease operating expenses	—		1,182		—		1,129
Total share-based compensation expenses	$	15,422	$	6,128	$	6,277	$	5,961
Income tax benefit	$	3,128	$	2,264	$	3,157	$	2,203


	Successor		Predecessor				Successor		Predecessor
	Four Months Ended June 30, 2017		Two Months Ended February 28, 2017		Six Months Ended June 30, 2016		Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017		Nine Months Ended September 30, 2016
(in thousands)
General and administrative expenses	$	19,599	$	50,255	$	14,406	$	25,876	$	50,255	$	19,238
Lease operating expenses	—		—		4,147		—		—		5,276
Total share-based compensation expenses	$	19,599	$	50,255	$	18,553	$	25,876	$	50,255	$	24,514
Income tax benefit	$	3,555	$	5,170	$	6,855	$	6,712	$	5,170	$	9,058

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Note 1315 – Earnings Per Share/Unit

Basic earnings per share/unit is computed by dividing net earnings attributable to common stockholders/unitholders by the weighted average number of shares/units outstanding during the period. Diluted earnings per share/unit is computed by adjusting the average number of shares/units outstanding for the dilutive effect, if any, of potential common shares/units. ~~The Company uses the treasury stock method to determine the dilutive effect~~

Table of ~~restricted stock units and the if-converted method to determine the dilutive effect of Class B units.~~Contents

LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

The following tables provide a reconciliation of the numerators and denominators of the basic and diluted per share/unit computations for net income (loss):

Successor Predecessor
Three Months Ended June 30, 2017 Three Months Ended June 30, 2016
(in thousands, except per share/unit data)
Income from continuing operations $ 223,379
$ 204,691
Allocated to participating securities —
(1,617 )
223,379
203,074
Income (loss) from discontinued operations, net of income taxes (3,322 ) 3,801
$ 220,057
$ 206,875

Weighted average shares/units outstanding – Basic
89,849
352,789
Dilutive effect of restricted stock units 635
—
Weighted average shares/units outstanding – Diluted
90,484
352,789

Income from continuing operations per share/unit – Basic
$ 2.49
$ 0.58
Income from continuing operations per share/unit – Diluted
$ 2.47
$ 0.58

Income (loss) from discontinued operations per share/unit – Basic
$ (0.04 ) $ 0.01
Income (loss) from discontinued operations per share/unit – Diluted
$ (0.04 ) $ 0.01

Net income per share/unit – Basic
$ 2.45
$ 0.59
Net income per share/unit – Diluted
$ 2.43
$ 0.59



	Successor
	Three Months Ended September 30, 2017
	Income			Shares	Per Share
	(in thousands, except per share data)

Basic:
Income from continuing operations	$	50,964		87,796	$	0.58
Income from discontinued operations, net of income taxes	86,099			87,796	0.98
Net income attributable to common stockholders	$	137,063		87,796	$	1.56

Effect of Dilutive Securities:
Dilutive effect of restricted stock units	$	—		1,203
Dilutive effect of unvested Class A-2 units of Holdco	$	(31	)	—

Diluted:
Income from continuing operations	$	50,933		88,999	$	0.57
Income from discontinued operations	86,099			88,999	0.97
Net income attributable to common stockholders	$	137,032		88,999	$	1.54



	Predecessor
	Three Months Ended September 30, 2016
	Loss			Units	Per Unit
	(in thousands, except per unit data)

Basic and Diluted:
Loss from continuing operations	$	(96,301	)	352,792	$	(0.27	)
Loss from discontinued operations, net of income taxes	(102,064		)	352,792	(0.29		)
Net loss attributable to common unitholders	$	(198,365	)	352,792	$	(0.56	)

3335

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands, except per share/unit data)
Income (loss) from continuing operations $ 216,055
$ 2,397,609
$ (9,177 )
Allocated to participating securities —
—
—
216,055
2,397,609
(9,177 )
Loss from discontinued operations, net of income taxes (3,254 ) (548 ) (1,130,077 )
$ 212,801
$ 2,397,061
$ (1,139,254 )

Weighted average shares/units outstanding – Basic
89,849
352,792
352,511
Dilutive effect of restricted stock units 216
—
—
Weighted average shares/units outstanding – Diluted
90,065
352,792
352,511

Income (loss) from continuing operations per share/unit – Basic
$ 2.41
$ 6.80
$ (0.02 )
Income (loss) from continuing operations per share/unit – Diluted
$ 2.40
$ 6.80
$ (0.02 )

Loss from discontinued operations per share/unit – Basic
$ (0.04 ) $ (0.01 ) $ (3.21 )
Loss from discontinued operations per share/unit – Diluted
$ (0.04 ) $ (0.01 ) $ (3.21 )

Net income (loss) per share/unit – Basic
$ 2.37
$ 6.79
$ (3.23 )
Net income (loss) per share/unit – Diluted
$ 2.36
$ 6.79
$ (3.23 )



	Successor
	Seven Months Ended September 30, 2017
	Income			Shares	Per Share
	(in thousands, except per share data)

Basic:
Income from continuing operations	$	267,019		88,966	$	3.00
Income from discontinued operations, net of income taxes	82,845			88,966	0.93
Net income attributable to common stockholders	$	349,864		88,966	$	3.93

Effect of Dilutive Securities:
Dilutive effect of restricted stock units	$	—		818
Dilutive effect of unvested Class A-2 units of Holdco	$	(31	)	—

Diluted:
Income from continuing operations	$	266,988		89,784	$	2.97
Income from discontinued operations	82,845			89,784	0.93
Net income attributable to common stockholders	$	349,833		89,784	$	3.90

The 3,470,051 Class B units associated with management’s profits interests awards were not considered to be dilutive as the applicable hurdle rate had not been met as of June 30, 2017, and, therefore, are excluded for the purpose of the diluted earnings per share calculation.



	Predecessor
	Two Months Ended February 28, 2017
	Income (Loss)			Units	Per Unit
	(in thousands, except per unit data)

Basic and Diluted:
Income from continuing operations	$	2,397,609		352,792	$	6.80
Loss from discontinued operations, net of income taxes	(548		)	352,792	(0.01		)
Net income attributable to common unitholders	$	2,397,061		352,792	$	6.79



	Predecessor
	Nine Months Ended September 30, 2016
	Loss			Units	Per Unit
	(in thousands, except per unit data)

Basic and Diluted:
Loss from continuing operations	$	(105,478	)	352,606	$	(0.30	)
Loss from discontinued operations, net of income taxes	(1,232,141		)	352,606	(3.49		)
Net loss attributable to common unitholders	$	(1,337,619	)	352,606	$	(3.79	)

The diluted earnings per unit calculation excludes approximately 8,000 restricted stock units that were anti-dilutive for the seven months ended September 30, 2017, and approximately 1 million unit options and warrants that were anti-dilutive for each of the three months and ~~six~~nine months ended ~~June~~September 30, 2016. There were no anti-dilutive restricted stock units for the three

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

months ended September 30, 2017. There were no potential common units outstanding during the two months ended February 28, 2017.

Note 1416 – Income Taxes

Effective February 28, 2017, upon consummation of the Plan, the Successor became a C corporation subject to federal and state income taxes. Prior to the consummation of the Plan, the Predecessor was a limited liability company treated as a partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits ~~of the Company~~ were passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Predecessor’s subsidiaries were C corporations subject to federal and state income taxes. As such, with the exception of the state of Texas and certain subsidiaries, the Predecessor did not directly pay federal and state income taxes and recognition was not given to federal and state income taxes for the operations of the Predecessor.

The effective income tax rates were approximately ~~42%~~11% and 37% for ~~each of~~ the three months and ~~four~~seven months ended ~~June~~September 30, 2017, respectively, and zero for the two months ended February 28, 2017. The deferred tax effects of the Company’s change to a C corporation are included in income from continuing operations for the two months ended February 28, 2017. Amounts recognized as income taxes are included in “income tax expense (benefit),” as well as discontinued operations, on the condensed consolidated statements of operations.

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

Note 1517 – Supplemental Disclosures to the Condensed Consolidated Balance Sheets and Condensed Consolidated Statements of Cash Flows

“Other current assets” reported on the condensed consolidated balance sheets include the following:


	Successor		Predecessor		Successor		Predecessor
	June 30, 2017		December 31, 2016		September 30, 2017		December 31, 2016
(in thousands)
Prepaid expenses	$	58,095	$	70,116
Prepaids					$	53,702	$	70,116
Receivable from related party					18,262		—
Inventories	10,984		15,097		11,251		15,097
Deferred financing fees	—		16,809		—		16,809
Other	2,757		3,288		2,722		3,288
Other current assets	$	71,836	$	105,310	$	85,937	$	105,310

“Other accrued liabilities” reported on the condensed consolidated balance sheets include the following:


	Successor		Predecessor		Successor		Predecessor
	June 30, 2017		December 31, 2016		September 30, 2017		December 31, 2016
(in thousands)
Accrued compensation	$	21,214	$	16,443	$	25,057	$	16,443
Share-based payment liability	18,517		—
Asset retirement obligations (current portion)	8,120		9,361		7,361		9,361
Deposits for pending divestitures	60,112		—
Deposits					8,153		—
Income taxes payable					56,333		—
Other	27,453		175		3,851		175
Other accrued liabilities	$	135,416	$	25,979	$	100,755	$	25,979

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

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


	Successor		Predecessor				Successor		Predecessor
	Four Months Ended June 30, 2017		Two Months Ended February 28, 2017		Six Months Ended June 30, 2016		Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017		Nine Months Ended September 30, 2016
(in thousands)
Cash payments for interest, net of amounts capitalized	$	14,436	$	17,651	$	92,192	$	15,140	$	17,651	$	117,794
Cash payments for income taxes	$	215	$	—	$	3,033	$	275	$	—	$	4,427
Cash payments for reorganization items, net	$	6,300	$	21,571	$	—	$	10,802	$	21,571	$	5,728

Noncash investing activities:
Accrued capital expenditures	$	34,547	$	22,191	$	20,124	$	42,388	$	22,191	$	24,817

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 ~~June~~September 30, 2017, “restricted cash” on the condensed consolidated balance sheet consists of approximately ~~$42~~$38 million that will be used to settle certain claims ~~and pay certain professional fees~~ in accordance with the Plan (which is the remainder of approximately $80 million transferred to restricted cash in February 2017 to fund such items) ~~and~~, approximately ~~$57~~$8 million related to deposits and approximately $5 million for ~~pending divestitures.~~other items. At December 31, 2016, “restricted cash” on the condensed consolidated balance sheet represents amounts restricted related to

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

utility services providers. In addition, restricted cash of approximately $8 million is included in “other noncurrent assets” on the condensed consolidated balance sheet at December 31, 2016, and represents cash deposited by the Company into a separate account designated for asset retirement obligations in accordance with contractual agreements.

At December 31, 2016, net outstanding checks of approximately $6 million were reclassified and included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet. The change in net outstanding checks is presented as cash flows from financing activities and included in “other” on the condensed consolidated statements of cash flows.

Note 1618 – Related Party Transactions

Roan Resources LLC

On August 31, 2017, the Company completed the transaction in which LINN Energy and Citizen each contributed certain upstream assets located in Oklahoma to a newly formed company, Roan. In exchange for their respective contributions, LINN Energy and Citizen each received a 50% equity interest in Roan, subject to customary post-closing adjustments. See Note 4 for additional information. Also on such date, Roan entered into a Master Services Agreement (the “MSA”) with Linn Operating, LLC (“Linn Operating”), a subsidiary of LINN Energy, pursuant to which Linn Operating will provide certain operating, administrative and other services in respect of the assets contributed to Roan during a transitional period.

Under the MSA, Roan will reimburse Linn Operating for certain costs and expenses incurred by Linn Operating in connection with providing the services, and Roan will pay to Linn Operating a service fee of $1.25 million per month, prorated for partial months. The termination of the MSA will be the earliest of: (a) mutual agreement of the parties; (b) upon 30 days’ prior written notice from Roan to Linn Operating; (c) upon five days’ prior written notice from Linn Operating to Roan of a material default by Roan under the MSA, provided Linn Operating must have provided prior written notice to Roan of such material default providing Roan 10 days to cure such material default and such material default has not been cured by the end of the 10 day time period; and (d) eight months from the date of the MSA.

In addition to the service fee, for the one month ended September 30, 2017, the Company recognized marketing revenues of approximately $1 million associated with charges incurred by Roan from its properties. The Company has accounts receivable due from Roan of approximately $2 million included in “accounts receivable – trade, net” and accounts payable due to Roan of

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LINN ENERGY, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued

(Unaudited)

approximately $1 million included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet at September 30, 2017. In addition, approximately $18 million due from Roan associated with capital spending is included in “other current assets” on the Company’s condensed consolidated balance sheet at September 30, 2017.

Berry Petroleum Company, LLC

Berry, a former subsidiary of the Predecessor, was deconsolidated effective December 3, 2016 (see Note 4). The employees of Linn Operating, Inc. (“LOI”), a subsidiary of the Predecessor, provided services and support to Berry in accordance with an agency agreement and power of attorney between Berry and LOI. Upon deconsolidation, transactions between the Predecessor and Berry were no longer eliminated in consolidation and were treated as related party transactions. These transactions include, but are not limited to, management fees paid to the Company by Berry. On the Effective Date, Berry emerged from bankruptcy as a stand-alone, unaffiliated entity.

For the two months ended February 28, 2017, and the three months and the ~~six~~nine months ended ~~June~~September 30, 2016, Berry incurred management fees of approximately $6 million, ~~$18~~$14 million and ~~$41~~$56 million, respectively, for services provided by LOI. The Predecessor also had accounts payable due to Berry of approximately $3 million included in “accounts payable and accrued expenses” on the condensed consolidated balance sheet at December 31, 2016. In addition, $25 million due to Berry was included in “liabilities subject to compromise” on the Predecessor’s condensed consolidated balance sheet at December 31, 2016.

LinnCo, LLC

LinnCo, an affiliate of the Predecessor, was formed on April 30, 2012. All of LinnCo’s common shares were held by the public. As of December 31, 2016, LinnCo had no significant assets or operations other than those related to its interest in the Predecessor and owned approximately 71% of the Predecessor’s then outstanding units. In accordance with the Plan, LinnCo will be dissolved following the resolution of all outstanding claims.

The Predecessor had 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 Predecessor had 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 the Predecessor on LinnCo’s behalf were expensed by the Predecessor.

For the two months ended February 28, 2017, LinnCo incurred total general and administrative expenses of approximately $287,000, including approximately $240,000 related to services provided by the Predecessor. All of the expenses incurred during the two months ended February 28, 2017, had been paid by the Predecessor on LinnCo’s behalf as of February 28, 2017.

For the three months and ~~six~~nine months ended ~~June~~September 30, 2016, LinnCo incurred total general and administrative expenses, reorganization expenses and offering costs of approximately ~~$2.5~~$1.0 million and ~~$4.2~~$5.2 million, respectively, including approximately $603,000 and ~~$1.2~~$1.8 million, respectively, related to services provided by the LINN Energy. Of the expenses and costs incurred during the ~~six~~nine months ended ~~June~~September 30, 2016, approximately ~~$4.0~~$5.1 million had been paid by LINN Energy on LinnCo’s behalf as of ~~June~~September 30, 2016.

~~Table of Contents~~

~~LINN ENERGY, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – Continued~~

~~(Unaudited)~~

~~Note 17 – Redeemable Noncontrolling Interests~~

Redeemable noncontrolling interests on the condensed consolidated balance sheet as of June 30, 2017, relate to the noncontrolling Class B unitholders of Holdco. Class B units can be converted at any time by the holder to Class A-2 units of Holdco or Class A common stock of the Company in accordance with the terms of the Holdco LLC Agreement. As of June 30, 2017, the redeemable noncontrolling interests of approximately $28 million presented as temporary equity on the condensed consolidated balance sheet consists solely of the noncash share-based compensation related to the vested portion of the incentive interest awards in the form of Class B units issued to certain members of management (see Note 12). In accordance with the Holdco LLC Agreement, the requirements entitling Class B unitholders to Holdco distributions had not been met as of June 30, 2017, and, therefore, no allocation of net income (loss) was made to the redeemable noncontrolling interests for the four months ended June 30, 2017.

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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, 2016. 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 the Company’s Annual Report on Form 10-K for the year ended December 31, 2016, and elsewhere in the Annual Report.

When referring to Linn Energy, Inc. (formerly known as Linn Energy, LLC) (“Successor,” “LINN Energy” or the “Company”), the intent is to refer to LINN Energy, a newly formed Delaware corporation, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. Linn Energy, Inc. is a successor issuer of Linn Energy, LLC pursuant to Rule 15d-5 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). When referring to the “Predecessor” in reference to the period prior to the emergence from bankruptcy, the intent is to refer to Linn Energy, LLC, the predecessor that will be dissolved following the effective date of the Plan (as defined below) and resolution of all outstanding claims, 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 was an indirect 100% wholly owned subsidiary of the Predecessor through February 28, 2017. Berry was deconsolidated effective December 3, 2016 (see below and Note 4). The reference to “LinnCo” herein refers to LinnCo, LLC, an affiliate of the Predecessor.

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 is an independent oil and natural gas company that was formed in February 2017, in connection with the reorganization of the Predecessor. The Predecessor was publicly traded from January 2006 to February 2017. As discussed further below and in Note 2, on May 11, 2016 (the “Petition Date”), Linn Energy, LLC, certain of its direct and indirect subsidiaries, and LinnCo (collectively, 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 were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16‑60040. During the pendency of the Chapter 11 proceedings, the Debtors operated 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 Company emerged from bankruptcy effective February 28, 2017.

On December 3, 2016, LINN Energy filed an amended plan of reorganization that excluded Berry. As a result of its loss of control of Berry, LINN Energy concluded that it was appropriate to deconsolidate Berry effective on the aforementioned date and classified it as discontinued operations.

The Company’s properties are currently located in seven operating regions in the United States (“U.S.”):

~~Rockies, which includes properties located in Wyoming (Washakie Basin), Utah (Uinta Basin) and North Dakota (Williston Basin);~~

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

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;

Rockies, which includes properties located in Wyoming (Washakie Basin), Utah (Uinta Basin) and North Dakota (Williston Basin);

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

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

South Texas.

In July 2017, the Company divested all of its properties located in California. See below and Note 4 for details of the Company’s divestitures.

The Company also owns a 50% equity interest in Roan Resources LLC (“Roan”), which is focused on the accelerated development of the Merge/SCOOP/STACK play in Oklahoma. The Company’s current focus is the ~~upstream and midstream~~ development of the Merge/SCOOP/STACK through its equity interest in ~~Oklahoma.~~Roan, as well as through its midstream operations in the area. Additionally, the Company is pursuing emerging horizontal opportunities in the Mid-Continent ~~Rockies~~ and TexLa regions while continuing to add value by efficiently operating and applying new technology to a diverse set of long-life producing assets.

For the three months ended ~~June~~September 30, 2017, the Company’s results included the following:

oil, natural gas and NGL sales of approximately ~~$243~~$206 million compared to ~~$196~~$238 million for the three months ended ~~June~~September 30, 2016;

average daily production of approximately ~~710~~586 MMcfe/d compared to ~~802~~809 MMcfe/d for the three months ended ~~June~~September 30, 2016;

net income attributable to common stockholders of approximately ~~$220~~$137 million compared to ~~$208~~a net loss attributable to common unitholders of approximately $198 million for the three months ended ~~June~~September 30, 2016;

capital expenditures of approximately ~~$96~~$123 million compared to ~~$23~~$44 million for the three months ended ~~June~~September 30, 2016; and

1422 wells drilled (all successful) compared to 3746 wells drilled (all successful) for the three months ended ~~June~~September 30, 2016.

For the ~~six~~nine months ended ~~June~~September 30, 2017, the Company’s results included the following:

oil, natural gas and NGL sales of approximately ~~$323~~$530 million and $189 million for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to ~~$380~~$618 million for the ~~six~~nine months ended ~~June~~September 30, 2016;

average daily production of approximately ~~722~~664 MMcfe/d and 745 MMcfe/d for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to ~~813~~812 MMcfe/d for the ~~six~~nine months ended ~~June~~September 30, 2016;

net income attributable to common stockholders/unitholders of approximately ~~$213~~$350 million and $2.4 billion for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to a net loss attributable to unitholders of approximately ~~$1.1~~$1.3 billion for the ~~six~~nine months ended ~~June~~September 30, 2016;

net cash provided by operating activities from continuing operations of approximately ~~$117~~$192 million and net cash used in operating activities of approximately $30 million for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to net cash provided by operating activities of approximately ~~$800~~$851 million for the ~~six~~nine months ended ~~June~~September 30, 2016;

capital expenditures of approximately ~~$114~~$237 million and $46 million for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to ~~$53~~$98 million for the ~~six~~nine months ended ~~June~~September 30, 2016; and

4163 wells drilled (all successful) compared to 96142 wells drilled ~~(95~~(141 successful) for the ~~six~~nine months ended ~~June~~September 30, 2016.

Predecessor and Successor Reporting

As a result of the application of fresh start accounting (see Note 3), the Company’s condensed consolidated financial statements and certain note presentations are separated into two distinct periods, the period before the Effective Date (labeled Predecessor) and the period after that date (labeled Successor), to indicate the application of a different basis of accounting between the periods presented. Despite this separate presentation, there was continuity of the Company’s operations.

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

Chapter 11 Proceedings

On January 27, 2017, the Bankruptcy Court entered an order approving and confirming the Plans (the “Confirmation Order”). On February 28, 2017 (the “Effective Date”), the Debtors satisfied the conditions to effectiveness of the respective Plans, the Plans became effective in accordance with their respective terms and LINN Energy and Berry emerged from bankruptcy as stand-alone, unaffiliated entities.

Plan of Reorganization

In accordance with the Plan, on the Effective Date:

The Predecessor transferred all of its assets, including equity interests in its subsidiaries, other than LAC and Berry, to Linn Energy Holdco II LLC (“Holdco II”), a newly formed subsidiary of the Predecessor and the borrower under the Credit Agreement (as amended, the “Successor Credit Facility”) entered into in connection with the reorganization, in exchange for 100% of the equity of Holdco II and the issuance of interests in the Successor Credit Facility to certain of the Predecessor’s creditors in partial satisfaction of their claims (the “Contribution”). Immediately following the Contribution, the Predecessor transferred 100% of the equity interests in Holdco II to the Successor in exchange for approximately $530 million in cash and an amount of equity securities in the Successor not to exceed 49.90% of the outstanding equity interests of the Successor, which the Predecessor distributed to certain of its creditors in satisfaction of their claims. Contemporaneously with the reorganization transactions and pursuant to the Plan, (i) LAC assigned all of its rights, title and interest in the membership interests of Berry to Berry Petroleum Corporation, (ii) all of the equity interests in LAC and the Predecessor were canceled and (iii) LAC and the Predecessor commenced liquidation, which is expected to be completed following the resolution of the respective companies’ outstanding claims.

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

The holders of general unsecured claims (other than claims relating to the Second Lien Notes and the Unsecured Notes) against the LINN Debtors (the “LINN Unsecured Claims”) received their pro rata share of cash from two cash distribution pools totaling $40 million, as divided between a $2.3 million cash distribution pool for the payment in full of allowed LINN Unsecured Claims in an amount equal to $2,500 or less (and larger claims for which the holders irrevocably agreed to reduce such claims to $2,500), and a $37.7 million cash distribution pool for pro rata distributions to all remaining allowed general LINN Unsecured Claims. As a result, all outstanding LINN Unsecured Claims were fully satisfied, settled, released and discharged as of the Effective Date.

The Successor entered into a registration rights agreement with certain parties, pursuant to which the Company agreed to, among other things, file a registration statement with the Securities and Exchange Commission within 60 days of the Effective Date covering the offer and resale of “Registrable Securities” (as defined therein).

Rights Offerings

Divestitures

Below are the Company’s completed divestitures in 2017:

~~The Company entered into two definitive purchase and sale agreements for the sales of its interest in certain properties located in south Texas.~~ On September 12, 2017, August 1, 2017, and July 31, 2017, the Company completed the sales ~~and received~~of its interest in certain properties located in south Texas (the “South Texas Assets Sales”). Combined cash proceeds received from the sale of these properties were approximately $49 million, net of costs to sell of approximately $9$1 million, and the Company recognized a combined net gain of approximately ~~$23 million, respectively.~~$14 million.

~~The Company entered into two definitive purchase and sale agreements for the sales of undeveloped acreage located in the Permian Basin.~~ On August 23, 2017, July 28, 2017, ~~the Company completed the sale of undeveloped acreage located in Lea~~ and ~~Eddy counties in New Mexico and received cash proceeds of approximately $21 million. On~~ May 9, 2017, the Company completed the sales of its interest in certain properties located in Texas and New Mexico (the “Permian Assets Sales”). Combined cash proceeds received from the sale of ~~undeveloped acreage located in Ward County, Texas~~these properties were approximately $31 million and ~~received cash proceeds~~the Company recognized a combined net gain of approximately $4$29 million.

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

of these properties were approximately $253 million, net of costs to sell of approximately $4 million, and the Company recognized a net gain of approximately $120 million.

On July 21, 2017, the Company completed the sale of its interest in properties located in the Los Angeles Basin in California to Bridge Energy LLC (the “Los Angeles Basin Sale”) ~~and~~. Cash proceeds received ~~cash proceeds~~from the sale of these properties were approximately $93 million, net of costs to sell of approximately ~~$94~~$1 million, and the Company recognized a net gain of approximately $2 million. The Company will receive an additional $7 million contingent payment if certain operational requirements are satisfied within one year.

~~The Company continues to market the previously announced non-core assets located in the Permian Basin, the Williston Basin and south Texas.~~

~~Joint Venture~~Divestitures – Pending

On October 3, 2017, the Company, through certain of its subsidiaries, entered into a ~~newly formed company, Roan Resources LLC (“Roan”), focused~~definitive purchase and sale agreement to sell its interest in properties located in Wyoming for a contract price of $200 million, subject to closing adjustments.

Proceeds from these sales are expected to be added as additional cash on the ~~accelerated development~~Company’s balance sheet to be used for funding of the ~~Merge/SCOOP/STACK play in the Mid-Continent region. In exchange for their respective contributions, LINN Energy~~Company’s announced share repurchase program and ~~Citizen will equally split the equity interest in Roan.~~other general corporate purposes. The ~~transaction is~~sales are anticipated to close ~~in the third quarter of~~on November 30, 2017, subject to closing conditions. There can be no assurance that all of the conditions to closing will be satisfied.

The Company continues to market the previously announced non-core assets located in the Permian Basin and south Texas.

Roan Contribution

On August 31, 2017, the Company, through certain of its subsidiaries, completed the transaction in which LINN Energy and Citizen Energy II, LLC (“Citizen”) each contributed certain upstream assets located in Oklahoma to a newly formed company, Roan (the contribution, the “Roan Contribution”), focused on the accelerated development of the Merge/SCOOP/STACK play. In exchange for their respective contributions, LINN Energy and Citizen each received a 50% equity interest in Roan, subject to customary post-closing adjustments. As of August 31, 2017, the date of the Roan Contribution, the Company recognized its equity investment at a carryover basis of approximately $452 million.

Construction of Cryogenic Plant

In July 2017 the Company renamed its ~~wholly owned~~ subsidiary LINN Midstream, LLC to Blue Mountain Midstream LLC (“Blue Mountain”) and entered into a definitive agreement with BCCK Engineering, Inc. (“BCCK”) to construct the Chisholm Trail Cryogenic Gas Plant. Blue Mountain’s assets include the Chisholm Trail midstream business (“Chisholm Trail”) located in Oklahoma. Chisholm Trail is located in the Merge/SCOOP/STACK play in the Mid-Continent region and has approximately 30 miles of existing natural gas gathering pipeline and approximately 60 MMcf/d of current refrigeration capacity. Infrastructure expansions are underway to add 35 miles of low pressure gathering, increase compression throughput and

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

construct a new cryogenic plant to improve liquids recoveries. Blue Mountain has entered into a definitive agreement with BCCK to construct a 225 MMcf/d cryogenic natural gas processing facility with a total capacity of 250 MMcf/d. Construction is underway and it is expected to be commissioned during the second quarter of 2018.

2017 Oil and Natural Gas Capital Budget

For 2017, the Company estimates its total capital expenditures, excluding acquisitions, will be approximately ~~$338~~$360 million, including approximately ~~$229~~$245 million related to its oil and natural gas capital program and approximately ~~$100~~$107 million related to its plant and pipeline capital. This estimate is under continuous review and subject to ongoing adjustments.

Financing Activities

~~Successor~~Revolving Credit Facility

On ~~the Effective Date, pursuant to the terms of the Plan,~~August 4, 2017, the Company entered into ~~the Successor Credit Facility~~a credit agreement with Holdco II, as borrower, ~~and Wells Fargo~~Royal Bank ~~National Association,~~of Canada, as administrative agent, and the lenders and agents party thereto, providing ~~for: 1)~~for a new senior secured reserve-based revolving loan facility (the “Revolving Credit Facility”) with $500 million in borrowing commitments and an initial borrowing base of ~~$1.4 billion and 2) a term loan in an original principal amount of $300~~$500 million.

~~Table of Contents~~


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

On May 31, 2017, the Company entered into the First Amendment and Consent to Credit Agreement, pursuant to which among other modifications: 1) the term loan was paid in full and terminated using cash proceeds from the Jonah Assets Sale, and 2) the borrowing base for the revolving loan was reduced to $1 billion. As of ~~June~~September 30, 2017, ~~total~~there were no borrowings outstanding under the ~~Successor~~Revolving Credit Facility ~~were approximately $183 million~~ and there was approximately ~~$774~~$455 million of ~~remaining~~ available borrowing capacity (which includes a $7$45 million reduction for outstanding letters of credit). The maturity date is ~~February 27, 2021.~~August 4, 2020.

Redetermination of the borrowing base under the ~~Successor~~Revolving Credit Facility, based primarily on reserve reports using lender commodity price expectations at such time, occurs semi-annually, in April and ~~October. The next~~October, with the first scheduled borrowing base redetermination is to occur on ~~October 1, 2017.~~March 15, 2018. At the Company’s election, interest on borrowings under the ~~Successor~~Revolving Credit Facility is determined by reference to either the London Interbank Offered Rate (“LIBOR”) plus an applicable margin ofranging from 2.50% to 3.50% per annum or the alternate base rate (“ABR”) plus an applicable margin ofranging from 1.50% to 2.50% per ~~annum.~~annum, depending on utilization of the borrowing base. Interest is generally payable in arrears ~~monthly~~quarterly for loans bearing interest based at the ABR and at the end of the applicable interest period for loans bearing interest at the ~~LIBOR.~~LIBOR, or if such interest period is longer than three months, at the end of the three month intervals during such interest period. The Company is required to pay a commitment fee to the lenders under the ~~Successor~~Revolving Credit Facility, which accrues at a rate per annum of 0.50% on the average daily unused amount of the available revolving loan commitments of the lenders.

The obligations under the ~~Successor~~Revolving Credit Facility are secured by mortgages covering approximately ~~95%~~85% of the total value of the proved reserves of the oil and natural gas properties of the Company and certain ~~equipment and facilities associated therewith,~~of its subsidiaries, along with liens on substantially all personal property of the Company and certain of its subsidiaries, and are guaranteed by the Company, ~~Linn Energy~~ Holdco ~~LLC~~ and certain of Holdco II’s subsidiaries, subject to customary exceptions. Under the ~~Successor~~Revolving Credit Facility, the Company is required to maintain ~~certain financial covenants including the maintenance of~~ (i) a reserve coverage ratio of at least 1.1 to 1.0, tested on (a) the date of each scheduled borrowing base redetermination and (b) the date of each additional borrowing base redetermination done in conjunction with an asset sale, (ii) a maximum total net debt to last twelve months ~~EBITDAX~~EBITDA ratio of 4.0 to 1.0, ~~beginning with the quarter ending September 30, 2017,~~ and ~~(iii)~~(ii) a minimum adjusted current ratio of 1.0 to ~~1.0 beginning with the quarter ending September 30, 2017.~~1.0.

The ~~Successor~~Revolving Credit Facility also contains ~~customary~~ affirmative and negative covenants, including as to compliance with laws (including environmental laws, ERISA and anti-corruption laws), maintenance of required insurance, delivery of quarterly and annual financial statements, oil and ~~natural~~ gas engineering reports and budgets, maintenance and operation of property (including oil and ~~natural~~ gas properties), restrictions on the incurrence of liens and indebtedness, mergers, consolidations and sales of assets, paying dividends or other distributions in respect of, or repurchasing or redeeming, the Company’s capital stock, making certain investments and transactions with ~~affiliates and other customary covenants.~~affiliates.

The ~~Successor~~Revolving Credit Facility contains ~~customary~~ events of default and remedies customary for credit facilities of this nature. Failure to comply with the financial and other covenants in the ~~Successor~~Revolving Credit Facility would allow the lenders, subject to customary cure rights, to require immediate payment of all amounts outstanding under the ~~Successor~~Revolving Credit Facility.

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

Share Repurchase Program

On June 1, 2017, the Company’s Board of Directors announced that it had authorized the repurchase of up to $75 million of the Company’s outstanding shares of Class A common stock. On June 28, 2017, the Company’s Board of Directors announced that it had authorized an increase in the previously announced share repurchase program to up to a total of $200 million of the Company’s outstanding shares of Class A common stock. InAny share repurchases are subject to restrictions in the Revolving Credit Facility. During the period from June 2017 ~~and July~~through September 2017, the Company repurchased an aggregate of ~~841,303~~4,607,598 shares of Class A common stock at an average price of ~~$32.41~~$34.06 per share for a total cost of approximately ~~$27~~$157 million.

Listing on the OTCQB Market

On the Effective Date, the Predecessor’s units were canceled and ceased to trade on the OTC Markets Group Inc.’s Pink marketplace. In April 2017, the Successor’s Class A common stock was approved for trading on the OTCQB market under the symbol “LNGG.”

Commodity Derivatives

In October 2017, the Company entered into commodity derivative contracts consisting of natural gas swaps for January 2018 through December 2018. Including these new hedges, as of October 31, 2017, the Company had natural gas swaps of approximately 69,715 MMMBtu at an average price of approximately $3.02 per MMBtu for 2018.

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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 ~~June~~September 30, 2017, Compared to Three Months Ended ~~June~~September 30, 2016


	Successor			Predecessor						Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Variance			Three Months Ended September 30, 2017			Three Months Ended September 30, 2016			Variance
(in thousands)
Revenues and other:
Natural gas sales	$	110,481		$	82,718		$	27,763		$	92,470		$	121,842		$	(29,372	)
Oil sales	89,237			81,499			7,738			74,384			82,244			(7,860		)
NGL sales	43,449			31,630			11,819			39,464			33,900			5,564
Total oil, natural gas and NGL sales	243,167			195,847			47,320			206,318			237,986			(31,668		)
Gains (losses) on oil and natural gas derivatives	45,714			(183,794		)	229,508			(14,497		)	166			(14,663		)
Marketing and other revenues ⁽¹⁾	18,938			32,192			(13,254		)	44,861			28,823			16,038
	307,819			44,245			263,574			236,682			266,975			(30,293		)
Expenses:
Lease operating expenses	71,057			70,367			690			61,272			67,234			(5,962		)
Transportation expenses	37,388			41,092			(3,704		)	34,541			40,986			(6,445		)
Marketing expenses	6,976			6,727			249			34,099			6,933			27,166
General and administrative expenses ⁽²⁾	34,458			52,169			(17,711		)	30,035			48,471			(18,436		)
Exploration costs	811			48			763			171			4			167
Depreciation, depletion and amortization	51,987			86,358			(34,371		)	29,657			87,413			(57,756		)
Impairment of long-lived assets										—			41,728			(41,728		)
Taxes, other than income taxes	17,871			18,180			(309		)	12,368			18,003			(5,635		)
(Gains) losses on sale of assets and other, net	(306,969		)	2,517			(309,486		)	(26,977		)	2,532			(29,509		)
	(86,421		)	277,458			(363,879		)	175,166			313,304			(138,138		)
Other income and (expenses)	(8,714		)	(51,546		)	42,832			(1,885		)	(25,261		)	23,376
Reorganization items, net	(3,377		)	485,798			(489,175		)	(2,605		)	(28,361		)	25,756
Income from continuing operations before income taxes	382,149			201,039			181,110
Income (loss) from continuing operations before income taxes										57,026			(99,951		)	156,977
Income tax expense (benefit)	158,770			(3,652		)	162,422			5,996			(3,650		)	9,646
Income from continuing operations	223,379			204,691			18,688
Income (loss) from continuing operations										51,030			(96,301		)	147,331
Income (loss) from discontinued operations, net of income taxes	(3,322		)	3,801			(7,123		)	86,099			(102,064		)	188,163
Net income	$	220,057		$	208,492		$	11,565
Net income (loss)										137,129			(198,365		)	335,494
Net income attributable to noncontrolling interests										66			—			66
Net income (loss) attributable to common stockholders/unitholders										$	137,063		$	(198,365	)	$	335,428


⁽¹⁾	Marketing and other revenues for the three months ended ~~June~~September 30, 2016, include approximately ~~$18~~$14 million of management fee revenues recognized by the Company from Berry. Management fee revenues are included in “other revenues” on the condensed consolidated statement of operations.

⁽²⁾

General and administrative expenses for the three months ended ~~June~~September 30, 2017, and ~~June~~September 30, 2016, include approximately ~~$15~~$6 million and $5 million, respectively, of noncash share-based compensation expenses. In addition, general and administrative expenses for the three months ended ~~June~~September 30, 2016, include expenses incurred by LINN Energy associated with the operations of Berry. On February 28, 2017, LINN Energy and Berry emerged from Bankruptcy as stand-alone, unaffiliated entities.

4447

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


	Successor		Predecessor				Successor		Predecessor
	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016		Variance		Three Months Ended September 30, 2017		Three Months Ended September 30, 2016		Variance
Average daily production:
Natural gas (MMcf/d)	432		511		(15	)%	368		518		(29	)%
Oil (MBbls/d)	21.6		21.9		(1	)%	17.7		22.0		(20	)%
NGL (MBbls/d)	24.8		26.6		(7	)%	18.5		26.6		(30	)%
Total (MMcfe/d)	710		802		(11	)%	586		809		(28	)%

Weighted average prices: ⁽¹⁾
Average daily production – Equity method investments: ⁽¹⁾
Total (MMcfe/d)							23		—

Weighted average prices: ⁽²⁾
Natural gas (Mcf)	$	2.81	$	1.78	58	%	$	2.73	$	2.56	7	%
Oil (Bbl)	$	45.42	$	40.96	11	%	$	45.58	$	40.60	12	%
NGL (Bbl)	$	19.29	$	13.08	47	%	$	23.18	$	13.87	67	%

Average NYMEX prices:
Natural gas (MMBtu)	$	3.18	$	1.95	63	%	$	3.00	$	2.81	7	%
Oil (Bbl)	$	48.28	$	45.59	6	%	$	48.20	$	44.94	7	%

Costs per Mcfe of production:
Lease operating expenses	$	1.10	$	0.96	15	%	$	1.14	$	0.90	27	%
Transportation expenses	$	0.58	$	0.56	4	%	$	0.64	$	0.55	16	%
General and administrative expenses ⁽²⁾	$	0.53	$	0.71	(25	)%
General and administrative expenses ⁽³⁾							$	0.56	$	0.65	(14	)%
Depreciation, depletion and amortization	$	0.80	$	1.18	(32	)%	$	0.55	$	1.17	(53	)%
Taxes, other than income taxes	$	0.28	$	0.25	12	%	$	0.23	$	0.24	(4	)%

Average daily production – discontinued operations:
Average daily production – discontinued operations: ⁽⁴⁾
Total (MMcfe/d)	29		277				8		265


⁽¹⁾	Represents the Company’s 50% equity interest in Roan. Production of Roan for 2017 is for the period from September 1, 2017 through September 30, 2017.


⁽²⁾	Does not include the effect of gains (losses) on derivatives.

⁽²⁾⁽³⁾


⁽⁴⁾	Production of discontinued operations for 2017 is for the period from July 1, 2017 through July 31, 2017.

4548

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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 ~~increased~~decreased by approximately ~~$47~~$32 million or ~~24%~~13% to approximately ~~$243~~$206 million for the three months ended ~~June~~September 30, 2017, from approximately ~~$196~~$238 million for the three months ended ~~June~~September 30, 2016, due to ~~higher natural gas, NGL and oil prices,~~lower production volumes partially offset by ~~lower production volumes.~~higher commodity prices. Higher NGL, oil and natural gas ~~NGL and oil~~ prices resulted in an increase in revenues of approximately ~~$40~~$16 million, ~~$14~~$8 million and $9$5 million, respectively.

Average daily production volumes decreased to approximately ~~710~~586 MMcfe/d for the three months ended ~~June~~September 30, 2017, from ~~802~~809 MMcfe/d for the three months ended ~~June~~September 30, 2016. Lower natural gas, ~~NGL~~oil and ~~oil~~NGL production volumes resulted in a decrease in revenues of approximately ~~$13~~$35 million, $2$16 million and $1$10 million, respectively.

The following table sets forth average daily production by region:


	Successor	Predecessor					Successor		Predecessor
	Three Months Ended June 30, 2017	Three Months Ended June 30, 2016	Variance				Three Months Ended September 30, 2017		Three Months Ended September 30, 2016	Variance
Average daily production (MMcfe/d):
Rockies	244	330	(86	)	(26	)%	160		343	(183	)	(54	)%
Hugoton Basin	165	181	(16	)	(9	)%	171		178	(7	)	(4	)%
Mid-Continent	125	102	23		23	%	91		102	(11	)	(11	)%
TexLa	76	71	5		8	%	81		73	8		12	%
Permian Basin	46	58	(12	)	(21	)%	43		54	(11	)	(19	)%
Michigan/Illinois	29	31	(2	)	(6	)%	29		30	(1	)	(6	)%
South Texas	25	29	(4	)	(13	)%	11		29	(18	)	(62	)%
	710	802	(92	)	(11	)%	586		809	(223	)	(28	)%
Equity method investments							23	—	—

The ~~increases~~increase in average daily production volumes in the TexLa region primarily reflects increased development capital spending in the region. The decrease in average daily production volumes in the Mid-Continent ~~and TexLa~~region primarily ~~reflect~~reflects lower production volumes as a result of the Roan Contribution on August 31, 2017, partially offset by increased development capital spending in the ~~regions.~~region. The decreases in average daily production volumes in the Rockies, Permian Basin and South Texas regions primarily reflect lower production volumes as a result of divestitures completed during 2017. See Note 4 for additional information of divestitures. In addition, the decreases in average daily production volumes in these and the remaining regions ~~primarily~~ reflect lower production volumes as a result of reduced development capital spending, ~~throughout the Company’s various regions,~~ as well as marginal well shut-ins, driven by continued low commodity prices. ~~The decrease~~Equity method investments represents the Company’s 50% equity interest in ~~average daily production volumes in~~Roan. Production of Roan for 2017 is for the ~~Rockies region also reflects lower production volumes as a result of the Jonah Assets Sale on May 31,~~period from September 1, 2017 through September 30, 2017.

Gains (Losses) on Oil and Natural Gas Derivatives

~~Gains~~Losses on oil and natural gas derivatives were approximately ~~$46~~$14 million for the three months ended ~~June~~September 30, 2017, compared to ~~losses~~gains of approximately ~~$184 million~~$166,000 for the three months ended ~~June~~September 30, 2016, representing a variance of approximately ~~$230~~$15 million. Gains and losses 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.

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 78 and Note 89 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.

Table of Contents


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

Marketing and Other Revenues

~~Table of Contents~~


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

and helium sales revenue. Marketing and other revenues ~~decreased~~increased by approximately ~~$13~~$16 million or ~~41%~~56% to approximately ~~$19~~$45 million for the three months ended ~~June~~September 30, 2017, from approximately ~~$32~~$29 million for the three months ended ~~June~~September 30, 2016. The ~~decrease~~increase was primarily due to ~~the management fee revenues from Berry included in the Predecessor period, partially offset by~~ higher revenues generated by the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms, and higher helium sales revenue in the Hugoton ~~Basin.~~Basin, partially offset by the management fee revenues from Berry included in the Predecessor period.

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 ~~remained relatively consistent at~~decreased by approximately ~~$71~~$6 million or 9% to approximately $61 million for the three months ended ~~June~~September 30, 2017, ~~compared to~~from approximately ~~$70~~$67 million for the three months ended ~~June~~September 30, 2016. The decrease was primarily due to reduced labor costs for field operations as a result of cost savings initiatives and the divestitures completed in 2017. Lease operating expenses per Mcfe increased to ~~$1.10~~$1.14 per Mcfe for the three months ended ~~June~~September 30, 2017, from ~~$0.96~~$0.90 per Mcfe for the three months ended ~~June~~September 30, 2016.

Transportation Expenses

Transportation expenses decreased by approximately $4$6 million or 9%16% to approximately ~~$37~~$35 million for the three months ended ~~June~~September 30, 2017, from approximately $41 million for the three months ended ~~June~~September 30, 2016. The decrease was primarily due to reduced costs as a result of lower production volumes and as a result of the ~~properties sold~~divestitures completed in ~~May~~ 2017. Transportation expenses per Mcfe increased ~~$0.58~~to $0.64 per Mcfe for the three months ended ~~June~~September 30, 2017, from ~~$0.56~~$0.55 per Mcfe for the three months ended ~~June~~September 30, ~~2016.~~2016, primarily due to lower unit rates on the properties sold in 2017.

Marketing Expenses

Marketing expenses represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing expenses ~~remained relatively consistent at~~increased by approximately $27 million or 392% to approximately $34 million for the three months ended September 30, 2017, from approximately $7 million for ~~each of~~ the three months ended ~~June~~September 30, ~~2017, and June 30,~~ 2016. The increase was primarily due to higher expenses associated with the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms.

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. In addition, general and administrative expenses in the Predecessor period includes expenses incurred by LINN Energy associated with the operations of Berry. General and administrative expenses decreased by approximately $18 million or ~~34%~~38% to approximately ~~$34~~$30 million for the three months ended ~~June~~September 30, 2017, from approximately ~~$52~~$48 million for the three months ended ~~June~~September 30, 2016. The decrease was primarily due to lower salaries and benefits related expenses, the costs associated with the operations of Berry in the Predecessor period and lower various other administrative expenses including insurance and rent, partially offset by higher noncash share-based compensation expenses and higher professional services expenses. General and administrative expenses per Mcfe also decreased to ~~$0.53~~$0.56 per Mcfe for the three months ended ~~June~~September 30, 2017, from ~~$0.71~~$0.65 per Mcfe for the three months ended ~~June~~September 30, 2016.

For the professional services expenses related to the Chapter 11 proceedings that were incurred since the Petition Date, see “Reorganization Items, Net.”

Exploration Costs

Exploration costs increased by approximately ~~$763,000~~$167,000 to approximately ~~$811,000~~$171,000 for the three months ended ~~June~~September 30, 2017, from approximately ~~$48,000~~$4,000 for the three months ended ~~June~~September 30, 2016. The increase was primarily due to higher seismic data expenses.

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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 ~~$34~~$57 million or ~~40%~~66% to approximately ~~$52~~$30 million for the three months ended ~~June~~September 30, 2017, from approximately ~~$86~~$87 million for the three months ended ~~June~~September 30, 2016. The decrease was primarily due to lower rates as a result of the application of fresh start accounting, as well as lower total production volumes. Depreciation, depletion and amortization per Mcfe also decreased to ~~$0.80~~$0.55 per Mcfe for the three months ended ~~June~~September 30, 2017, from ~~$1.18~~$1.17 per Mcfe for the three months ended ~~June~~September 30, 2016.

Impairment of Long-Lived Assets

The Company recorded no impairment charges for the three months ended September 30, 2017. During the three months ended September 30, 2016, the Company recorded an impairment charge of approximately $42 million associated with proved oil and natural gas properties in the Mid-Continent and Rockies regions due to a decline in commodity prices, changes in expected capital development and a decline in the Company’s estimates of proved reserves.

Taxes, Other Than Income Taxes



	Successor			Predecessor
	Three Months Ended September 30, 2017			Three Months Ended September 30, 2016		Variance
(in thousands)
Severance taxes	$	7,610		$	10,871	$	(3,261	)
Ad valorem taxes	4,983			7,120		(2,137		)
Other	(225		)	12		(237		)
	$	12,368		$	18,003	$	(5,635	)

Taxes, other than income taxes decreased by approximately $6 million or 31% for the three months ended September 30, 2017, compared to the three months ended September 30, 2016. Severance taxes, which are a function of revenues generated from production, decreased primarily due to lower production volumes partially offset by higher commodity prices. Ad valorem taxes, which are based on the value of reserves and production equipment and vary by location, decreased primarily due to divestitures completed in 2017 and lower estimated valuations on certain of the Company’s properties.

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

During the three months ended September 30, 2017, the Company recorded the following amounts related to divestitures (see Note 4):

Advisory fees of approximately $17 million associated with the Roan Contribution;

Net gain of approximately $25 million on the Permian Assets Sales; and

Net gain of approximately $14 million, including costs to sell of approximately $1 million, on the South Texas Assets Sales.

Other Income and (Expenses)



	Successor			Predecessor
	Three Months Ended September 30, 2017			Three Months Ended September 30, 2016			Variance
(in thousands)
Interest expense, net of amounts capitalized	$	(223	)	$	(25,283	)	$	25,060
Earnings from equity method investments	2,575			222			2,353
Other, net	(4,237		)	(200		)	(4,037		)
	$	(1,885	)	$	(25,261	)	$	23,376

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

~~Taxes,~~ Other ~~Than Income Taxes~~

Successor Predecessor

Three Months Ended June 30,
2017

Three Months Ended June 30,
2016
Variance
(in thousands)
Severance taxes $ 10,669
$ 10,208
$ 461
Ad valorem taxes 6,933
6,991
(58 )
Other 269
981
(712 )
$ 17,871
$ 18,180
$ (309 )

~~Taxes, other than~~ income ~~taxes~~and (expenses) decreased by approximately ~~$309,000~~$23 million or 2%93% for the three months ended ~~June~~September 30, 2017, compared to the three months ended June 30, 2016. Severance taxes, which are a function of revenues generated from production, increased primarily due to higher commodity prices partially offset by 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.

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

~~During the three months ended June 30, 2017, the Company recorded the following net gains on divestitures (see Note 4):~~

~~Net gain of approximately $22 million on the Salt Creek Assets Sale; and~~

~~Net gain of approximately $279 million, including costs to sell of approximately $6 million, on the Jonah Assets Sale.~~

~~Other Income and (Expenses)~~

Successor Predecessor

Three Months Ended June 30,
2017

Three Months Ended June 30,
2016
Variance
(in thousands)
Interest expense, net of amounts capitalized $ (7,551 ) $ (50,320 ) $ 42,769
Other, net (1,163 ) (1,226 ) 63
$ (8,714 ) $ (51,546 ) $ 42,832

~~Other income and (expenses) decreased by approximately $43 million or 83% for the three months ended June 30, 2017, compared to the three months ended June~~September 30, 2016. Interest expense decreased ~~primarily~~ due to lower outstanding debt during the period. For the ~~period from May 12, 2016 through June 30,~~three months ended September 2016, contractual interest, which was not recorded, on the senior notes was approximately ~~$31~~$56 million. See “Debt” under “Liquidity and Capital Resources” below for additional details.

The Second Lien Notes 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 June~~three months ended September 30, 2016, contractual interest, which was not recorded, on the Second Lien Notes was approximately ~~$16~~$30 million.

Equity method investments primarily include the Company’s 50% equity interest in Roan. The Company’s equity earnings consists of its share of Roan’s earnings and the amortization of the difference between the Company’s investment in Roan and Roan’s underlying net assets attributable to certain assets. See Note 4 for additional information.

Reorganization Items, Net

The Company incurred significant costs and recognized significant gains associated with the reorganization. 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:



	Successor			Predecessor
	Three Months Ended September 30, 2017			Three Months Ended September 30, 2016
(in thousands)
Legal and other professional advisory fees	$	(2,549	)	$	(16,714	)
Terminated contracts	—			(13,123		)
Other	(56		)	1,476
Reorganization items, net	$	(2,605	)	$	(28,361	)

Income Tax Expense (Benefit)

Effective February 28, 2017, upon the consummation of the Plan, the Successor became a C corporation. Prior to the consummation of the Plan, the Predecessor was 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 were passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Predecessor’s subsidiaries were C corporations subject to federal and state income taxes. The Company recognized income tax expense of approximately $6 million and an income tax benefit of approximately $4 million for the three months ended September 30, 2017, and September 30, 2016, respectively.

Income (loss) from Discontinued Operations, Net of Income Taxes

As a result of the Company’s strategic exit from California (completed by the San Joaquin Basin Sale and Los Angeles Basin Sale) and the deconsolidation of Berry, the Company has classified the results of operations of its California properties and Berry as discontinued operations. Income from discontinued operations, net of income taxes was approximately $86 million for the three months ended September 30, 2017, compared to loss from discontinued operations, net of income taxes of approximately $l02 million for the three months ended and September 30, 2016. See Note 4 for additional information.

Net Income (Loss) Attributable to Common Stockholders/Unitholders

Net income attributable to common stockholders/unitholders increased by approximately $335 million to approximately $137 million for the three months ended September 30, 2017, from a net loss of approximately $198 million for the three months ended September 30, 2016. The increase was primarily due to lower expenses, including interest, and gains on the divestitures completed in 2017, partially offset by lower production revenues, losses compared to gains on commodity derivatives and income tax expense compared to income tax benefit. See discussion above for explanations of variances.

4852

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

Results of Operations

The following table reflects the Company’s results of operations for each of the Successor and Predecessor periods presented:



	Successor			Predecessor
	Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Revenues and other:
Natural gas sales	$	241,021		$	99,561		$	300,585
Oil sales	193,859			58,560			228,766
NGL sales	94,930			30,764			88,923
Total oil, natural gas and NGL sales	529,810			188,885			618,274
Gains (losses) on oil and natural gas derivatives	19,258			92,691			(74,175		)
Marketing and other revenues ⁽¹⁾	68,741			16,551			98,382
	617,809			298,127			642,481
Expenses:
Lease operating expenses	156,959			49,665			220,847
Transportation expenses	85,652			25,972			124,609
Marketing expenses	43,614			4,820			21,493
General and administrative expenses ⁽²⁾	74,904			71,745			184,360
Exploration costs	1,037			93			2,745
Depreciation, depletion and amortization	101,558			47,155			262,880
Impairment of long-lived assets	—			—			165,044
Taxes, other than income taxes	37,316			14,877			53,544
(Gains) losses on sale of assets and other, net	(333,371		)	829			6,607
	167,669			215,156			1,042,129
Other income and (expenses)	(15,057		)	(16,717		)	(160,323		)
Reorganization items, net	(8,547		)	2,331,189			457,437
Income (loss) from continuing operations before income taxes	426,536			2,397,443			(102,534		)
Income tax expense (benefit)	159,451			(166		)	2,944
Income (loss) from continuing operations	267,085			2,397,609			(105,478		)
Income (loss) from discontinued operations, net of income taxes	82,845			(548		)	(1,232,141		)
Net income (loss)	349,930			2,397,061			(1,337,619		)
Net income attributable to noncontrolling interests	66			—			—
Net income (loss) attributable to common stockholders/unitholders	$	349,864		$	2,397,061		$	(1,337,619	)


⁽¹⁾	Marketing and other revenues for the two months ended February 28, 2017, and the nine months ended September 30, 2016, include approximately $6 million and $56 million, respectively, of management fee revenues recognized by the Company from Berry. Management fee revenues are included in “other revenues” on the condensed consolidated statements of operations.

⁽²⁾

General and administrative expenses for the seven months ended September 30, 2017, the two months ended February 28, 2017, and the nine months ended September 30, 2016, include approximately $26 million, $50 million and $19 million, respectively, of noncash share-based compensation expenses. In addition, general and administrative expenses for the two months ended February 28, 2017, and the nine months ended September 30, 2016, include expenses incurred by LINN Energy associated with the operations of Berry. On February 28, 2017, LINN Energy and Berry emerged from bankruptcy as stand-alone, unaffiliated entities.

Table of Contents


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



	Successor		Predecessor
	Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017		Nine Months Ended September 30, 2016
Average daily production:
Natural gas (MMcf/d)	414		495		521
Oil (MBbls/d)	19.8		20.2		22.6
NGL (MBbls/d)	21.8		21.4		25.8
Total (MMcfe/d)	664		745		812

Average daily production – Equity method investments: ⁽¹⁾
Total (MMcfe/d)	10		—		—

Weighted average prices: ⁽²⁾
Natural gas (Mcf)	$	2.72	$	3.41	$	2.10
Oil (Bbl)	$	45.71	$	49.16	$	36.96
NGL (Bbl)	$	20.32	$	24.37	$	12.57

Average NYMEX prices:
Natural gas (MMBtu)	$	3.03	$	3.66	$	2.29
Oil (Bbl)	$	48.45	$	53.04	$	41.33

Costs per Mcfe of production:
Lease operating expenses	$	1.11	$	1.13	$	0.99
Transportation expenses	$	0.60	$	0.59	$	0.56
General and administrative expenses ⁽³⁾	$	0.53	$	1.63	$	0.83
Depreciation, depletion and amortization	$	0.72	$	1.07	$	1.18
Taxes, other than income taxes	$	0.26	$	0.34	$	0.24

Average daily production – discontinued operations: ⁽⁴⁾
Total (MMcfe/d)	20		30		277


⁽¹⁾	Represents the Company’s 50% equity interest in Roan. Production of Roan for 2017 is for the period from September 1, 2017 through September 30, 2017.


⁽²⁾	Does not include the effect of gains (losses) on derivatives.

⁽³⁾


⁽⁴⁾	Production of discontinued operations for 2017 is for the period from January 1, 2017 through July 31, 2017.

Table of Contents


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 increased by approximately $101 million or 16% to approximately $530 million and $189 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $618 million for the nine months ended September 30, 2016, due to higher commodity prices partially offset by lower production volumes. Higher natural gas, oil and NGL prices resulted in an increase in revenues of approximately $93 million, $52 million and $51 million, respectively.

Average daily production volumes decreased to approximately 664 MMcfe/d and 745 MMcfe/d for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately 812 MMcfe/d for the nine months ended September 30, 2016. Lower natural gas, oil and NGL production volumes resulted in a decrease in revenues of approximately $53 million, $28 million and $14 million, respectively.

The following table sets forth average daily production by region:



	Successor		Predecessor
	Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017	Nine Months Ended September 30, 2016
Average daily production (MMcfe/d):
Rockies	213		294	339
Hugoton Basin	168		159	183
Mid-Continent	111		109	100
TexLa	79		80	72
Permian Basin	45		49	58
Michigan/Illinois	29		29	31
South Texas	19		25	29
	664		745	812
Equity method investments	10	—	—	—

The increase from 2016 in average daily production volumes in the TexLa region primarily reflects increased development capital spending in the region. The increase in average daily production volumes in the Mid-Continent region primarily reflects increased development capital spending in the region, partially offset by lower production volumes as a result of the Roan Contribution on August 31, 2017. The decreases in average daily production volumes in the Rockies, Permian Basin and South Texas regions primarily reflect lower production volumes as a result of divestitures completed during 2017. See Note 4 for additional information of divestitures. In addition, the decreases in average daily production volumes in these and the remaining regions reflect lower production volumes as a result of reduced development capital spending, as well as marginal well shut-ins, driven by continued low commodity prices. Equity method investments represents the Company’s 50% equity interest in Roan. Production of Roan for 2017 is for the period from September 1, 2017 through September 30, 2017.

Gains (Losses) on Oil and Natural Gas Derivatives

Gains on oil and natural gas derivatives were approximately $19 million and $93 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to losses on oil and natural gas derivatives of approximately $74 million for the nine months ended September 30, 2016, representing a variance of approximately $186 million. Gains and losses 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.

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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 8 and Note 9 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. Other revenues primarily include management fee revenues recognized by the Company from Berry (in the Predecessor periods) and helium sales revenue. Marketing and other revenues decreased by approximately $12 million or 13% to approximately $69 million and $17 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $98 million for the nine months ended September 30, 2016. The decrease was primarily due to the management fee revenues from Berry included in the Predecessor periods, partially offset by higher revenues generated by the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms, and 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 $14 million or 6% to approximately $157 million and $50 million for the seven months ended September��30, 2017, and the two months ended February 28, 2017, respectively, from approximately $221 million for the nine months ended September 30, 2016. The decrease was primarily due to reduced labor costs for field operations as a result of cost savings initiatives and the divestitures completed in 2017. Lease operating expenses per Mcfe increased to $1.11 per Mcfe and $1.13 per Mcfe for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to $0.99 per Mcfe for the nine months ended September 30, 2016.

Transportation Expenses

Transportation expenses decreased by approximately $13 million or 10% to approximately $86 million and $26 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $125 million for the nine months ended September 30, 2016. The decrease was primarily due to reduced costs as a result of lower production volumes and as a result of the divestitures completed in 2017. Transportation expenses per Mcfe increased to $0.60 per Mcfe and $0.59 per Mcfe for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to $0.56 per Mcfe for the nine months ended September 30, 2016, primarily due to lower unit rates on the properties sold in 2017.

Marketing Expenses

Marketing expenses represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing expenses increased by approximately $28 million or 125% to approximately $44 million and $5 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to approximately $21 million for the nine months ended September 30, 2016. The increase was primarily due to higher expenses associated with the Jayhawk natural gas processing plant in Kansas, principally driven by a change in contract terms.

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. In addition, general and administrative expenses in the Predecessor periods include expenses incurred by LINN Energy associated with the operations of Berry. General and administrative expenses decreased by approximately $37 million or 20% to approximately $75 million and $72 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $184 million for the nine months ended September 30, 2016. The decrease was primarily due to lower salaries and benefits related expenses, the costs associated with the operations of Berry in the Predecessor periods, lower various other administrative expenses including insurance and rent, and lower professional services expenses, partially offset by higher noncash share-based compensation expenses principally driven by the immediate vesting of certain awards on the Effective

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

Date. General and administrative expenses per Mcfe were $0.53 per Mcfe and $1.63 per Mcfe for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to $0.83 per Mcfe for the nine months ended September 30, 2016.

For professional services expenses related to the Chapter 11 proceedings that were incurred since the Petition Date, see “Reorganization Items, Net.”

Exploration Costs

Exploration costs decreased by approximately $2 million to approximately $1 million and $93,000 for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $3 million for the nine months ended September 30, 2016. The decrease was primarily due to lower seismic data expenses.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization decreased by approximately $114 million or 43% to approximately $102 million and $47 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $263 million for the nine months ended September 30, 2016. The decrease was primarily due to lower rates as a result of the application of fresh start accounting and impairments recorded in the first quarter of 2016, as well as lower total production volumes. Depreciation, depletion and amortization per Mcfe also decreased to $0.72 per Mcfe and $1.07 per Mcfe for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, from $1.18 per Mcfe for the nine months ended September 30, 2016.

Impairment of Long-Lived Assets

The Company recorded no impairment charges for the seven months ended September 30, 2017, or the two months ended February 28, 2017. During the nine months ended September 30, 2016, the Company recorded an impairment charge of approximately $165 million associated with proved oil and natural gas properties in the Mid-Continent and Rockies regions due to a decline in commodity prices, changes in expected capital development and a decline in the Company’s estimates of proved reserves.

Taxes, Other Than Income Taxes



	Successor		Predecessor
	Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017		Nine Months Ended September 30, 2016
(in thousands)
Severance taxes	$	22,142	$	9,107	$	28,028
Ad valorem taxes	15,084		5,744		24,501
Other	90		26		1,015
	$	37,316	$	14,877	$	53,544

Severance taxes, which are a function of revenues generated from production, increased primarily due to higher commodity prices partially offset by 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 divestitures completed in 2017 and lower estimated valuations on certain of the Company’s properties.

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

During the seven months ended September 30, 2017, the Company recorded the following amounts related to divestitures (see Note 4):

Advisory fees of approximately $17 million associated with the Roan Contribution;

Net gain of approximately $29 million on the Permian Assets Sales;

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

Net gain of approximately $14 million, including costs to sell of approximately $1 million, on the South Texas Assets Sales;

Net gain of approximately $33 million, including costs to sell of approximately $1 million, on the Salt Creek Assets Sale; and

Net gain of approximately $272 million, including costs to sell of approximately $6 million, on the Jonah Assets Sale.

Other Income and (Expenses)



	Successor			Predecessor
	Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Interest expense, net of amounts capitalized	$	(11,974	)	$	(16,725	)	$	(159,476	)
Earnings from equity method investments	2,705			157			511
Other, net	(5,788		)	(149		)	(1,358		)
	$	(15,057	)	$	(16,717	)	$	(160,323	)

Interest expense decreased primarily due to the Company’s discontinuation of interest expense recognition on the senior notes for the two months ended February 28, 2017, as a result of the Chapter 11 proceedings, lower outstanding debt and lower amortization of discounts and financing fees. For the two months ended February 28, 2017, and the period from May 12, 2016 through September 30, 2016, contractual interest, which was not recorded, on the senior notes was approximately $37 million and $86 million, respectively. See “Debt” under “Liquidity and Capital Resources” below for additional details.

The Second Lien Notes 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 two months ended February 28, 2017, and the period from May 12, 2016 through September 30, 2016, unrecorded contractual interest on the Second Lien Notes was approximately $20 million and $46 million, respectively.

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

Reorganization Items, Net

The Company incurred significant costs and recognized significant gains associated with the reorganization. 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~~were determined. The following table summarizes the components of reorganization items included on the condensed consolidated statements of operations:


	Successor			Predecessor			Successor			Predecessor
	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Gain on settlement of liabilities subject to compromise							$	—		$	3,724,750		$	—
Recognition of an additional claim for the Predecessor’s Second Lien Notes settlement							—			(1,000,000		)	—
Fresh start valuation adjustments							—			(591,525		)	—
Income tax benefit related to implementation of the Plan							—			264,889			—
Legal and other professional advisory fees	$	(3,446	)	$	(13,451	)	(8,565		)	(46,961		)	(30,165		)
Unamortized deferred financing fees, discounts and premiums	—			(52,045		)	—			—			(52,045		)
Gain related to interest payable on Predecessor’s Second Lien Notes	—			551,000			—			—			551,000
Terminated contracts							—			(6,915		)	(13,123		)
Other	69			294			18			(13,049		)	1,770
Reorganization items, net	$	(3,377	)	$	485,798		$	(8,547	)	$	2,331,189		$	457,437

Income Tax Expense (Benefit)

Effective February 28, 2017, upon the consummation of the Plan, the Successor became a C corporation. Prior to the consummation of the Plan, the Predecessor was 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 were passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Predecessor’s subsidiaries were C corporations subject to federal and state income taxes. The Company recognized income tax expense of approximately $159 million and an income tax benefit of approximately $4$166,000 for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to income tax expense of approximately $3 million for the ~~three~~nine months ended ~~June~~September 30, ~~2017, and June 30, 2016, respectively.~~2016.

Income ~~(Loss)~~(loss) from Discontinued Operations, Net of Income Taxes

As a result of the Company’s strategic exit from California (completed by the San Joaquin Basin Sale and Los Angeles Basin Sale) and the deconsolidation of Berry, the Company has classified the results of operations of its California properties and Berry as discontinued operations. ~~Loss~~Income from discontinued operations, net of income taxes was approximately $3$83 million ~~and income~~for the seven months ended September 30, 2017, compared to loss from discontinued operations, ~~was~~net of income taxes of approximately ~~$4 million~~$548,000 and $1.2 billion for the ~~three~~two months ended ~~June 30,~~February 28, 2017, and ~~June~~the nine months ended September 30, 2016, respectively. See Note 4 for additional information.

Net Income (Loss) Attributable to Common Stockholders/Unitholders

Net income attributable to common stockholders/unitholders increased by approximately ~~$12~~$4.1 billion to net income of approximately $350 million ~~to approximately $220 million~~and $2.4 billion for the ~~three~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, from a net loss of approximately ~~$208 million~~$1.3 billion for the ~~three~~nine months ended ~~June~~September 30, 2016. The increase was primarily due ~~gains on sales of assets, gains compared~~ to ~~losses on commodity derivatives, lower expenses and~~ higher ~~production revenues partially offset by~~ gains included in reorganization items, ~~during the three months ended June 30, 2016,~~ income ~~tax expense~~ compared to ~~income tax benefit and loss on~~losses from discontinued ~~operations compared to income. 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~~

~~The following table reflects the Company’s results of operations for each of the Successor and Predecessor periods presented:~~

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Revenues and other:
Natural gas sales $ 148,551
$ 99,561
$ 178,743
Oil sales 119,475
58,560
146,522
NGL sales 55,466
30,764
55,023
Total oil, natural gas and NGL sales 323,492
188,885
380,288
Gains (losses) on oil and natural gas derivatives 33,755
92,691
(74,341 )
Marketing and other revenues ⁽¹⁾
23,880
16,551
69,559
381,127
298,127
375,506
Expenses:
Lease operating expenses 95,687
49,665
153,613
Transportation expenses 51,111
25,972
83,623
Marketing expenses 9,515
4,820
14,560
General and administrative expenses ⁽²⁾
44,869
71,745
135,889
Exploration costs 866
93
2,741
Depreciation, depletion and amortization 71,901
47,155
175,467
Impairment of long-lived assets —
—
123,316
Taxes, other than income taxes 24,948
14,877
35,541
(Gains) losses on sale of assets and other, net (306,524 ) 672
3,786
(7,627 ) 214,999
728,536
Other income and (expenses) (13,302 ) (16,874 ) (135,351 )
Reorganization items, net (5,942 ) 2,331,189
485,798
Income (loss) from continuing operations before income taxes 369,510
2,397,443
(2,583 )
Income tax expense (benefit) 153,455
(166 ) 6,594
Income (loss) from continuing operations 216,055
2,397,609
(9,177 )
Loss from discontinued operations, net of income taxes (3,254 ) (548 ) (1,130,077 )
Net income (loss) $ 212,801
$ 2,397,061
$ (1,139,254 )


⁽¹⁾	Marketing and other revenues for the two months ended February 28, 2017, and the six months ended June 30, 2016, include approximately $6 million and $41 million, respectively, of management fee revenues recognized by the Company from Berry. Management fee revenues are included in “other revenues” on the condensed consolidated statements of operations.

⁽²⁾

General and administrative expenses for the four months ended June 30, 2017, the two months ended February 28, 2017, and the six months ended June 30, 2016, include approximately $20 million, $50 million and $14 million, respectively, of noncash share-based compensation expenses. In addition, general and administrative expenses for the two months ended February 28, 2017, and the six months ended June 30, 2016, include expenses incurred by LINN Energy associated with the operations of Berry. On February 28, 2017, LINN Energy and Berry emerged from bankruptcy as stand-alone, unaffiliated entities.

5059

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

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
Average daily production:
Natural gas (MMcf/d) 448
495
523
Oil (MBbls/d) 21.4
20.2
22.9
NGL (MBbls/d) 24.3
21.4
25.4
Total (MMcfe/d) 722
745
813

Weighted average prices: ⁽¹⁾

Natural gas (Mcf) $ 2.72
$ 3.41
$ 1.88
Oil (Bbl) $ 45.79
$ 49.16
$ 35.18
NGL (Bbl) $ 18.68
$ 24.37
$ 11.89

Average NYMEX prices:
Natural gas (MMBtu) $ 3.05
$ 3.66
$ 2.02
Oil (Bbl) $ 48.63
$ 53.04
$ 39.52

Costs per Mcfe of production:
Lease operating expenses $ 1.09
$ 1.13
$ 1.04
Transportation expenses $ 0.58
$ 0.59
$ 0.57
General and administrative expenses ⁽²⁾
$ 0.51
$ 1.63
$ 0.92
Depreciation, depletion and amortization $ 0.82
$ 1.07
$ 1.19
Taxes, other than income taxes $ 0.28
$ 0.34
$ 0.24

Average daily production – discontinued operations:
Total (MMcfe/d) 29
30
283


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

⁽²⁾

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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 increased by approximately $132 million or 35% to approximately $323 million and $189 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $380 million for the six months ended June 30, 2016, due to higher natural gas, oil and NGL prices, partially offset by lower production volumes. Higher natural gas, oil and NGL prices resulted in an increase in revenues of approximately $91 million, $44 million and $36 million, respectively.

Average daily production volumes decreased to approximately 722 MMcfe/d and 745 MMcfe/d for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately 813 MMcfe/d for the six months ended June 30, 2016. Lower natural gas, oil and NGL production volumes resulted in a decrease in revenues of approximately $21 million, $13 million and $5 million, respectively.

~~The following table sets forth average daily production by region:~~

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
Average daily production (MMcfe/d):
Rockies 254
294
338
Hugoton Basin 166
159
185
Mid-Continent 125
109
99
TexLa 77
80
71
Permian Basin 46
49
60
Michigan/Illinois 29
29
31
South Texas 25
25
29
722
745
813

The increases in average daily production volumes in the Mid-Continent and TexLa primarily reflect increased development capital spending in the regions. The decreases in average daily production volumes in the remaining regions primarily reflect lower production volumes as a result of reduced development capital spending throughout the Company’s various regions, as well as marginal well shut-ins, driven by continued low commodity prices. The decrease in average daily production volumes in the Rockies region also reflects lower production volumes as a result of the Jonah Assets Sale on May 31, 2017.

~~Gains (Losses) on Oil and Natural Gas Derivatives~~

Gains on oil and natural gas derivatives were approximately $34 million and $93 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to losses on oil and natural gas derivatives of approximately $74 million for the six months ended June 30, 2016, representing a variance of approximately $201 million. Gains and losses 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.

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.

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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. Other revenues primarily include management fee revenues recognized by the Company from Berry (in the Predecessor periods) and helium sales revenue. Marketing and other revenues decreased by approximately $29 million or 42% to approximately $24 million and $17 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $70 million for the six months ended June 30, 2016. The decrease was primarily due to the management fee revenues from Berry included in the Predecessor periods, partially offset by higher revenues generated by the Jayhawk natural gas processing plant in Kansas and 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 $8 million or 5% to approximately $96 million and $50 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $154 million for the six months ended June 30, 2016. The decrease was primarily due to reduced labor costs for field operations as a result of cost savings initiatives. Lease operating expenses per Mcfe increased to $1.09 per Mcfe and $1.13 per Mcfe for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to $1.04 per Mcfe for the six months ended June 30, 2016.

~~Transportation Expenses~~

Transportation expenses decreased by approximately $7 million or 8% to approximately $51 million and $26 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $84 million for the six months ended June 30, 2016. The decrease was primarily due to reduced costs as a result of lower production volumes and as a result of the properties sold in May 2017. Transportation expenses per Mcfe increased to $0.58 per Mcfe and $0.59 per Mcfe for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to $0.57 per Mcfe for the six months ended June 30, 2016.

~~Marketing Expenses~~

Marketing expenses represent third-party activities associated with company-owned gathering systems, plants and facilities. Marketing expenses remained relatively consistent at approximately $10 million and $5 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to approximately $15 million for the six months ended June 30, 2016.

~~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. In addition, general and administrative expenses in the Predecessor periods include expenses incurred by LINN Energy associated with the operations of Berry. General and administrative expenses decreased by approximately $19 million or 14% to approximately $45 million and $72 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $136 million for the six months ended June 30, 2016. The decrease was primarily due to lower salaries and benefits related expenses, the costs associated with the operations of Berry in the Predecessor periods, lower professional services expenses and lower various other administrative expenses including insurance and rent, partially offset by higher noncash share-based compensation expenses principally driven by the immediate vesting of certain awards on the Effective Date. General and administrative expenses per Mcfe were $0.51 per Mcfe and $1.63 per Mcfe for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to $0.92 per Mcfe for the six months ended June 30, 2016.

~~For professional services expenses related to the Chapter 11 proceedings that were incurred since the Petition Date, see “Reorganization Items, Net.”~~

~~Exploration Costs~~

Exploration costs decreased by approximately $2 million to approximately $866,000 and $93,000 for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $3 million for the six months ended June 30, 2016. The decrease was primarily due to lower seismic data expenses.

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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 $56 million or 32% to approximately $72 million and $47 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $175 million for the six months ended June 30, 2016. The decrease was primarily due to lower rates as a result of the application of fresh start accounting and impairments recorded in the first quarter of 2016, as well as lower total production volumes. Depreciation, depletion and amortization per Mcfe also decreased to $0.82 per Mcfe and $1.07 per Mcfe for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from $1.19 per Mcfe for the six months ended June 30, 2016.

~~Impairment of Long-Lived Assets~~

The Company recorded no impairment charges for the four months ended June 30, 2017, or the two months ended February 28, 2017. During the six months ended June 30, 2016, the Company recorded an impairment charge of approximately $123 million associated with proved oil and natural gas properties in the Mid-Continent region due to a decline in commodity prices, changes in expected capital development and a decline in the Company’s estimates of proved reserves.

~~Taxes, Other Than Income Taxes~~

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Severance taxes $ 14,532
$ 9,107
$ 17,157
Ad valorem taxes 10,101
5,744
17,381
Other 315
26
1,003
$ 24,948
$ 14,877
$ 35,541

Severance taxes, which are a function of revenues generated from production, increased primarily due to higher commodity prices partially offset by 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.

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

~~During the four months ended June 30, 2017, the Company recorded the following net gains on divestitures (see Note 4):~~

~~Net gain of approximately $22 million on the Salt Creek Assets Sale; and~~

~~Net gain of approximately $279 million, including costs to sell of approximately $6 million, on the Jonah Assets Sale.~~

~~Other Income and (Expenses)~~

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Interest expense, net of amounts capitalized $ (11,751 ) $ (16,725 ) $ (134,193 )
Other, net (1,551 ) (149 ) (1,158 )
$ (13,302 ) $ (16,874 ) $ (135,351 )

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

through June 30, 2016, contractual interest, which was not recorded, on the senior notes was approximately $37 million and $31 million, respectively. See “Debt” under “Liquidity and Capital Resources” below for additional details.

The Second Lien Notes 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 two months ended February 28, 2017, and the period from May 12, 2016 through June 30, 2016, unrecorded contractual interest on the Second Lien Notes was $20 million and approximately $16 million, respectively.

~~Reorganization Items, Net~~

The Company incurred significant costs and recognized significant gains associated with the reorganization. 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 were determined. The following table summarizes the components of reorganization items included on the condensed consolidated statements of operations:

~~Income Tax Expense (Benefit)~~

Effective February 28, 2017, upon the consummation of the Plan, the Successor became a C corporation. Prior to the consummation of the Plan, the Predecessor was 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 were passed through to its unitholders. Limited liability companies are subject to Texas margin tax. In addition, certain of the Predecessor’s subsidiaries were C corporations subject to federal and state income taxes. The Company recognized income tax expense of approximately $153 million and an income tax benefit of approximately $166,000 for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to income tax expense of approximately $7 million for the six months ended June 30, 2016.

~~Loss from Discontinued Operations, Net of Income Taxes~~

As a result of the Company’s strategic exit from California (completed by the San Joaquin Basin Sale and Los Angeles Basin Sale) and the deconsolidation of Berry, the Company has classified the results of operations of its California properties and Berry as discontinued operations. Loss from discontinued operations, net of income taxes decreased to approximately $3 million and $548,000 for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from approximately $1.1 billion for the six months ended June 30, 2016. See Note 4 for additional information.

~~Table of Contents~~


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

~~Net Income (Loss)~~

Net income increased by approximately $3.7 billion to net income of approximately $213 million and $2.4 billion for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, from a net loss of approximately $1.1 billion for the six months ended June 30, 2016. The increase was primarily due to higher gains included in reorganization items, lower losses from discontinued operations, gains on ~~sales of assets,~~the divestitures completed in 2017, gains compared to losses on commodity derivatives, lower impairment charges, lower expenses and higher production revenues. See discussion above for explanations of variances.

Liquidity and Capital Resources

Since its emergence from Chapter 11 bankruptcy in February 2017, the Company’s sources of cash have primarily consisted of proceeds from its 2017 oil and natural gas properties divestitures and net cash provided by operating activities. As a result of divesting certain oil and natural gas properties, the Company received over $1 billion in cash proceeds and repaid all of its outstanding debt as of July 31, 2017. The Company has also used its cash to fund capital expenditures, principally for the development of its oil and natural gas properties, and plant and pipeline ~~construction.~~construction, as well as repurchases of its Class A common stock. The Company expects to fund the remaining 2017 capital program and any share repurchases with excess cash from its pending divestitures and net cash provided by operating activities.

Prior to its emergence from bankruptcy, the Company utilized funds from debt and equity offerings, borrowings under its credit facilities and net cash provided by operating activities for liquidity and capital resources, and the primary use was for the development of oil and natural gas properties, as well as for acquisitions.

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


	Successor		Predecessor				Successor		Predecessor
	Four Months Ended June 30, 2017		Two Months Ended February 28, 2017		Six Months Ended June 30, 2016		Seven Months Ended September 30, 2017		Two Months Ended February 28, 2017		Nine Months Ended September 30, 2016
(in thousands)
Oil and natural gas	$	87,632	$	39,409	$	40,184	$	168,446	$	39,409	$	66,066
Plant and pipeline	22,724		4,990		7,729		63,923		4,990		25,188
Other	3,919		1,243		5,562		5,015		1,243		6,259
Capital expenditures, excluding acquisitions	$	114,275	$	45,642	$	53,475	$	237,384	$	45,642	$	97,513
Capital expenditures, excluding acquisitions – discontinued operations	$	1,790	$	436	$	12,806	$	2,007	$	436	$	17,282

The increase in capital expenditures was primarily due to oil and natural gas development activities in the Merge/SCOOP/STACK and plant and pipeline construction activities associated with the Chisholm Trail Cryogenic Gas Plant. For 2017, the Company estimates its total capital expenditures, excluding acquisitions, will be ~~approximately $229~~approximately $360 million, including approximately ~~$338~~$245 million related to its oil and natural gas capital program and approximately ~~$100~~$107 million related to its plant and pipeline capital. This estimate is under continuous review and subject to ongoing adjustments.

Statements of Cash Flows

The following provides a comparative cash flow summary:



	Successor			Predecessor
	Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Net cash:
Provided by (used in) operating activities	$	194,605		$	(20,814	)	$	885,192
Provided by (used in) investing activities	851,583			(58,756		)	(129,063		)
Provided by (used in) financing activities	(1,068,501		)	(560,932		)	42,210
Net increase (decrease) in cash and cash equivalents	$	(22,313	)	$	(640,502	)	$	798,339

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

~~Statements of Cash Flows~~

~~The following provides a comparative cash flow summary:~~

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Net cash:
Provided by (used in) operating activities $ 131,425
$ (20,814 ) $ 801,201
Provided by (used in) investing activities 550,753
(58,756 ) (71,111 )
Provided by (used in) financing activities (719,630 ) (560,932 ) 42,387
Net increase (decrease) in cash and cash equivalents $ (37,452 ) $ (640,502 ) $ 772,477

Operating Activities

Cash provided by operating activities was approximately ~~$131~~$195 million and cash used in operating activities was approximately $21 million for the ~~four~~seven months ended ~~June~~September 30, 2017, and the two months ended February 28, 2017, respectively, compared to cash provided by operating activities of approximately ~~$801~~$885 million for the ~~six~~nine months ended ~~June~~September 30, 2016. The decrease was primarily due to lower cash settlements on derivatives partially offset by higher production related revenues principally due to higher commodity prices. In addition, in February 2017, restricted cash increased by approximately $80 million in order to fund the settlement of certain claims and pay certain professional fees in accordance with the Plan.

Investing Activities

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


	Successor			Predecessor						Successor			Predecessor
	Four Months Ended June 30, 2017			Two Months Ended February 28, 2017			Six Months Ended June 30, 2016			Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Cash flow from investing activities:
Capital expenditures	$	(88,821	)	$	(58,006	)	$	(94,564	)	$	(197,294	)	$	(58,006	)	$	(144,875	)
Proceeds from sale of properties and equipment and other	641,219			(166		)	(2,713		)	703,234			(166		)	(3,321		)
Net cash provided by (used in) investing activities – continuing operations	552,398			(58,172		)	(97,277		)	505,940			(58,172		)	(148,196		)
Net cash provided by (used in) investing activities – discontinued operations	(1,645		)	(584		)	26,166			345,643			(584		)	19,133
Net cash provided by (used in) investing activities	$	550,753		$	(58,756	)	$	(71,111	)	$	851,583		$	(58,756	)	$	(129,063	)

The primary use of cash in investing activities is for the development of the Company’s oil and natural gas properties. Capital expenditures increased primarily due to higher spending on development activities in the Company’s Mid-Continent, Rockies and TexLa regions. The Company made no acquisitions of properties during the ~~six~~nine months ended ~~June~~September 30, 2017, or ~~June~~September 30, 2016. The Company has classified the cash flows of its California properties and Berry as discontinued operations.

Proceeds from sale of properties and equipment and other for the ~~four~~seven months ended ~~June~~September 30, 2017, include cash proceeds received of approximately $50 million from the South Texas Assets Sales, approximately $31 million from the Permian Basin Assets Sales, approximately $76 million ~~in net cash proceeds received~~ from the Salt Creek Assets Sale ~~in June 2017~~ and approximately ~~$555~~$561 million ~~in net cash proceeds received~~ from the Jonah Assets ~~Sale in May 2017.~~Sale. An additional $5$8 million received from the ~~Jonah Assets Sale~~2017 divestitures remains in escrow and is currently classified as restricted cash. See Note 4 for additional details of divestitures.

Financing Activities

Cash used in financing activities was approximately $1.1 billion and $561 million for the seven months ended September 30, 2017, and the two months ended February 28, 2017, respectively, compared to cash provided by financing activities of approximately $42 million for the nine months ended September 30, 2016. In 2017, the primary use of cash in financing activities has been for repayments of debt.

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

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

Cash used in financing activities was approximately $720 million and $561 million for the four months ended June 30, 2017, and the two months ended February 28, 2017, respectively, compared to cash provided by financing activities of approximately $42 million for the six months ended June 30, 2016.



	Successor			Predecessor
	Seven Months Ended September 30, 2017			Two Months Ended February 28, 2017			Nine Months Ended September 30, 2016
(in thousands)
Proceeds from borrowings:
Successor Credit Facility	$	190,000		$	—		$	—
Predecessor Credit Facility	—			—			978,500
	$	190,000		$	—		$	978,500
Repayments of debt:
Successor Credit Facility	$	(790,000	)	$	—		$	—
Successor Term Loan	(300,000		)	—			—
Predecessor Credit Facility	—			(1,038,986		)	(814,299		)
Predecessor Term Loan	—			—			(98,911		)
	$	(1,090,000	)	$	(1,038,986	)	$	(913,210	)

On February 28, 2017, the Company canceled its obligations under the Predecessor Credit Facility and entered into the Successor Credit Facility (see Note 6)7), which was a net transaction and is reflected as such on the condensed consolidated statement of cash flows. During the six months ended June 30, 2016, the Company borrowed approximately $979 million under the Predecessor Credit Facility, including approximately $919 million in February 2016 which represented the remaining undrawn amount that was available. In addition, during the six months ended June 30, 2016, the Company repaid approximately $913 million under the Predecessor Credit Facility.

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

Successor Predecessor
Four Months Ended June 30, 2017 Two Months Ended February 28, 2017 Six Months Ended June 30, 2016
(in thousands)
Proceeds from borrowings:
Successor Credit Facility $ 160,000
$ —
$ —
Predecessor Credit Facility —
—
978,500
$ 160,000
$ —
$ 978,500
Repayments of debt:
Successor Credit Facility $ (576,570 ) $ —
$ —
Successor Term Loan (300,000 ) —
—
Predecessor Credit Facility —
(1,038,986 ) (814,299 )
Predecessor Term Loan —
—
(98,911 )
$ (876,570 ) $ (1,038,986 ) $ (913,210 )

In addition, in February 2017, the Company made a $30 million payment to holders of claims under the Second Lien ~~Notes. The Company~~Notes, and also issued 41,359,806 shares of Class A common stock to participants in the rights offerings extended by the Company to certain holders of claims arising under the Second Lien Notes and the Unsecured Notes for net proceeds of approximately $514 million.

~~Table of Contents~~


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

Debt

The following summarizes the Company’s outstanding debt:

Successor Predecessor
June 30, 2017 December 31, 2016
(in thousands, except percentages)
Successor revolving loan $ 183,430
$ —
Predecessor credit facility —
1,654,745
Predecessor term loan —
284,241
6.50% senior notes due May 2019 —
562,234
6.25% senior notes due November 2019 —
581,402
8.625% senior notes due April 2020 —
718,596
12.00% senior secured second lien notes due December 2020 —
1,000,000
7.75% senior notes due February 2021 —
779,474
6.50% senior notes due September 2021 —
381,423
Net unamortized deferred financing fees —
(1,257 )
Total debt, net 183,430
5,960,858
Less current portion, net ⁽¹⁾
—
(1,937,729 )
Less liabilities subject to compromise ⁽²⁾
—
(4,023,129 )
Long-term debt $ 183,430
$ —



	Successor		Predecessor
	September 30, 2017		December 31, 2016
(in thousands, except percentages)
Revolving credit facility	$	—	$	—
Predecessor credit facility	—		1,654,745
Predecessor term loan	—		284,241
6.50% senior notes due May 2019	—		562,234
6.25% senior notes due November 2019	—		581,402
8.625% senior notes due April 2020	—		718,596
12.00% senior secured second lien notes due December 2020	—		1,000,000
7.75% senior notes due February 2021	—		779,474
6.50% senior notes due September 2021	—		381,423
Net unamortized deferred financing fees	—		(1,257		)
Total debt, net	—		5,960,858
Less current portion, net ⁽¹⁾	—		(1,937,729		)
Less liabilities subject to compromise ⁽²⁾	—		(4,023,129		)
Long-term debt	$	—	$	—


⁽¹⁾	Due to covenant violations, the Predecessor’s credit facility and term loan were classified as current at December 31, 2016.


⁽²⁾	The Predecessor’s senior notes and Second Lien Notes were classified as liabilities subject to compromise at December 31, 2016. On the Effective Date, pursuant to the terms of the Plan, all outstanding amounts under these debt instruments were canceled.

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

As of ~~July~~October 31, 2017, there were no borrowings outstanding under the Revolving Credit Facility and there was approximately $461 million of available borrowing capacity (which includes a $39 million reduction for outstanding letters of credit).

In connection with the entry into the Revolving Credit Facility in August 2017, the Successor Credit ~~Facility. Pursuant~~Facility was terminated and repaid in full. On the Effective Date, pursuant to the terms of the Plan, ~~on the Effective Date,~~ all outstanding obligations under the Predecessor’s credit facility, Second Lien Notes and senior notes were canceled.

For additional information related to the Company’s outstanding debt, see Note 6.7.

Share Repurchase Program

Counterparty Credit Risk

The Company accounts for its commodity derivatives at fair value. The Company’s counterparties are participants in the ~~Successor~~Revolving Credit Facility or were participants in the Successor Credit Facility or Predecessor Credit Facility. The ~~Successor~~Revolving Credit Facility is secured by certain of the Company’s and its subsidiaries’ oil, natural gas and NGL reserves and personal property; therefore, the Company is not required to post any collateral. The Company does not receive collateral from its counterparties. 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.

~~Table of Contents~~


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

Dividends/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.

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

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 March 31, 2017, Quarterly Report on Form 10-Q. During the ~~three~~six months ended ~~June~~September 30, 2017, the Company ~~made approximately $650 million~~repaid in ~~net repayments~~full the Successor Credit Facility and entered into the Revolving Credit Facility (see Note 7). As of September 30, 2017, there were no borrowings outstanding under the ~~Successor Credit Facility. See Note 6 for additional information about the Successor~~Revolving Credit Facility. There have been no other significant changes to the Company’s contractual obligations since March 31, 2017.

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 and disposition strategy;

financial strategy;

new capital structure and the adoption of fresh start accounting;

uncertainty of the Company’s ability to improve its financial results and profitability following emergence from bankruptcy and other risks and uncertainties related to the Company’s emergence from bankruptcy;

~~Table of Contents~~


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

inability to maintain relationships with suppliers, customers, employees and other third parties following emergence from bankruptcy;

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 following emergence from bankruptcy;

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

ability to comply with covenants under the ~~Successor~~Revolving Credit Facility;

effects of legal proceedings;

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;

plans, objectives, expectations and intentions; and

taxes.

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

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 the Annual Report on Form 10-K for the year ended December 31, 2016, 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.


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 2016 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. The Company does not enter into derivative contracts for trading purposes. 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, the Company’s overall risk profile, including leverage and size and scale considerations, as well as any requirements for or restrictions on levels of hedging contained in any credit facility or other debt instrument applicable at the time. In addition, when commodity prices are depressed and forward commodity price curves are flat or in backwardation, the Company may determine that the benefit of hedging its anticipated production at these levels is outweighed by its resultant inability to obtain higher revenues for its production if commodity prices recover during the duration of the contracts. As a result, the appropriate percentage of production volumes to be hedged may change over time.

At September 30, 2017, the fair value of fixed price swaps and collars was a net asset of approximately $7 million. A 10% increase in the index oil and natural gas prices above the September 30, 2017, prices would result in a net liability of approximately $41 million, which represents a decrease in the fair value of approximately $48 million; conversely, a 10% decrease in the index oil and natural gas prices below the September 30, 2017, prices would result in a net asset of approximately $54 million, which represents an increase in the fair value of approximately $47 million.

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

~~Commodity Price Risk~~

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. The Company does not enter into derivative contracts for trading purposes. 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, the Company’s overall risk profile, including leverage and size and scale considerations, as well as any requirements for or restrictions on levels of hedging contained in any credit facility or other debt instrument applicable at the time. In addition, when commodity prices are depressed and forward commodity price curves are flat or in backwardation, the Company may determine that the benefit of hedging its anticipated production at these levels is outweighed by its resultant inability to obtain higher revenues for its production if commodity prices recover during the duration of the contracts. As a result, the appropriate percentage of production volumes to be hedged may change over time.

At June 30, 2017, the fair value of fixed price swaps and collars was a net asset of approximately $33 million. A 10% increase in the index oil and natural gas prices above the June 30, 2017, prices would result in a net liability of approximately $30 million, which represents a decrease in the fair value of approximately $63 million; conversely, a 10% decrease in the index oil and natural gas prices below the June 30, 2017, prices would result in a net asset of approximately $95 million, which represents an increase in the fair value of approximately $62 million.

At December 31, 2016, the fair value of fixed price swaps and collars was a net liability of approximately $85 million. A 10% increase in the index oil and natural gas prices above the December 31, 2016, prices would result in a net liability of approximately $183 million, which represents a decrease in the fair value of approximately $98 million; conversely, a 10% decrease in the index oil and natural gas prices below the December 31, 2016, prices would result in a net asset of approximately $13 million, which represents an increase in the fair value of approximately $98 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. Additionally, the Company cannot be assured that its counterparties will be able to perform under its derivative contracts. If a counterparty fails to perform and the derivative arrangement is terminated, the Company’s cash flows could be impacted.

Interest Rate Risk

At ~~June~~September 30, 2017, the Company had no debt outstanding under the ~~Successor~~Revolving Credit Facility of approximately $183 million which incurred interest at floating rates. A 1% increase in the respective market rates would result in an estimated $2 million increase in annual interest expense.

Facility. At December 31, 2016, the Company had debt outstanding under the Predecessor Credit Facility of approximately $1.9 billion which incurred interest at floating rates. A 1% increase in the respective market rates would result in an estimated $19 million increase in annual interest expense.

~~Table of Contents~~

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 not effective as of September 30, 2017, because of a material weakness related to the Company’s controls over application of fresh start accounting in the first quarter of 2017, as discussed below.

Description of Material Weakness

Upon emergence from bankruptcy on February 28, 2017, the Company adopted fresh start accounting. The Company involved third party individuals to assist in the accounting and disclosure of the complex non-routine transaction. As part of fresh start accounting in February 2017, the reorganization value derived from the enterprise value as disclosed in the plan of reorganization was allocated using a residual method to the Company’s assets and liabilities based on their fair values measured in accordance with ASC 805 “Business Combinations.” The Company recorded its proved oil and natural gas properties at fair value as of the Effective Date and no value was assigned to the unproved properties. During the third quarter of 2017, the Company concluded that a relative fair value method should have been used and a portion of the value should have been attributed to its unproved properties, and because of this, the Company re-allocated value from its proved properties to its unproved properties.

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Item 4. Controls and Procedures - Continued

The Company did not have adequately designed controls over the application of GAAP used to measure the carrying value of the underlying assets and liabilities in fresh start accounting, the involvement of individuals with the requisite knowledge, expertise and industry-specific experience to account for and disclose complex non-routine transactions, and the review and supervision of such accounting.

A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the annual or interim financial statements will not be prevented or detected on a timely basis.

These control deficiencies resulted in immaterial misstatements in the carrying amount of oil and natural gas properties, accumulated depletion and amortization, depreciation, depletion and amortization expense, gains on sale of assets, and discontinued operations to the Company’s condensed consolidated financial statements for the quarters ended March 31, June 30 ~~2017.~~and September 30, 2017, as described in Note 1. These control deficiencies create a reasonable possibility that a material misstatement to the Company’s annual or interim consolidated financial statements will not be prevented or detected on a timely basis by the Company’s internal controls. Accordingly, the Company’s management determined that these control deficiencies represent a material weakness.

Notwithstanding the material weakness in the Company’s internal control over financial reporting, management concluded that the financial statements and other financial information included in this report fairly present in all material respects the financial condition, results of operations and cash flows of the Company as of, and for, the periods presented in this report.

Remediation Efforts to Address the Material Weakness

During the third quarter of 2017, the Company took actions to commence remediation of the material weakness, including performing additional reviews of the allocation of proved and unproved properties on a field-by-field basis, and revised its policy to engage parties with the requisite knowledge, expertise and industry-specific experience as needed to assist in the accounting and disclosure of complex non-routine transactions. Management will consider the qualifications of team members reviewing non-routine complex transactions to ensure they meet the qualifications required for the proposed and actual scope of work.

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~~On August 31, 2017, the Company completed the transaction in which LINN Energy and Citizen Energy II, LLC each contributed certain upstream assets located in Oklahoma to a newly formed company, Roan Resources LLC (“Roan” and the contribution, the “Roan Contribution”). The Company uses the equity method of accounting for its investment in Roan, and after the date of the Roan Contribution, the Company designed and tested additional controls over the financial reporting process for this investment.

Other than the additional controls related to the remediation of the material weakness and the equity method investment, there were no changes in the Company’s internal control over financial reporting during the ~~second~~third quarter of 2017 that materially affected, or were reasonably likely to materially affect, the Company’s internal control over financial reporting.

Table of Contents

Part II – Other Information


Item 1.	Legal Proceedings


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 shares are described in Item 1A. “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016. AsExcept 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.

We have limited control over the operations of Roan, which could adversely affect our business.

We have limited control over the operations of Roan Resources LLC (“Roan”). Although we own a 50% equity interest in Roan, we do not control its board of directors or operating committee. Because of this limited control:

Roan may take actions contrary to our strategy or objectives;

we have limited ability to influence the day to day operations of Roan or its properties, including compliance with environmental, safety and other regulations; and

we are dependent on third parties for financial reporting matters upon which our financial statements are based.

Since Roan represents a significant investment of ours, adverse developments in Roan’s business could adversely affect our business.


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

Issuer Purchases of Equity Securities

The Company’s Board of Directors has authorized the repurchase of up to ~~$200~~$400 million of the Company’s outstanding shares of Class A common stock. Purchases may be made from time to time in negotiated purchases or in the open market, including through Rule 10b5-1 prearranged stock trading plans designed to facilitate the repurchase of the ~~Company's~~Company’s shares during times

it would not otherwise be in the market due to self-imposed trading blackout periods or possible possession of material nonpublic information. The timing and amounts of any such repurchases of shares will be subject to market conditions and certain other factors, and will be in accordance with applicable securities laws and other legal requirements, including restrictions contained in the ~~Company's~~Company’s then current credit facility. The repurchase plan does not obligate the Company to acquire any specific number of shares and may be discontinued at any time.

~~Table of Contents~~

~~Item 2. Unregistered Sales of Equity Securities and Use of Proceeds - Continued~~

The following sets forth information with respect to the Company’s repurchases of its shares of Class A common stock during the ~~second~~third quarter of 2017:

Period Total Number of Shares Purchased Average Price Paid Per Share Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs ⁽¹⁾
(in thousands)

April 1 – 30 — $ —
— $ —
May 1 – 31 — $ —
— $ —
June 1 – 30 7,540 $ 30.48
7,540 $ 199,770



Period	Total Number of Shares Purchased	Average Price Paid Per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs ⁽¹⁾
					(in thousands)

July 1 – 31	833,763	$	32.43	833,763	$	172,732
August 1 – 31	2,770,661	$	34.33	2,770,661	$	77,622
September 1 – 30	995,634	$	34.72	995,634	$	43,049
Total	4,600,058	$	34.07	4,600,058

⁽¹⁾

On June 1, 2017, the Company’s Board of Directors announced that it had authorized the repurchase of up to $75 million of the Company’s outstanding shares of Class A common stock. On June 28, 2017, the Company’s Board of Directors announced that it had authorized an increase in the previously announced share repurchase program to up to a total of $200 million of the Company’s outstanding shares of Class A common stock. On October 4, 2017, the Company’s Board of Directors announced that it had authorized an additional increase in the previously announced share repurchase program to up to a total of $400 million of the Company’s outstanding shares of a Class A common stock.


Item 3.	Defaults Upon Senior Securities

None


Item 4.	Mine Safety Disclosures

Not applicable


Item 5.	Other Information

None

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Table of Contents

~~Item 6. Exhibits~~


Item 6.	Exhibits



Exhibit Number		Description

2.1	—	Purchase and Sale Agreement, dated April 30, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC and Jonah Energy LLC (incorporated by reference to Exhibit 2.1 to Current Report on Form 8-K filed on May 4, 2017)
~~2.2~~	—	Purchase and Sale Agreement, dated May 23, 2017, by and among Linn Energy Holdings, LLC, Linn Operating, LLC, Linn Midstream, LLC and Berry Petroleum Company, LLC (incorporated by reference to Exhibit 2.1 to Current Report on Form 8-K filed on May 30, 2017)
~~2.3*†~~	—	~~Purchase and Sale Agreement, dated May 25, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC and Denbury Onshore, LLC~~
~~2.4*†~~	—	~~First Amendment, dated June 30, 2017, to Purchase and Sale Agreement, dated May 25, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC and Denbury Onshore, LLC~~
~~2.5*†~~	—	~~Purchase and Sale Agreement, dated June 1, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC, Linn Midstream, LLC and Bridge Energy LLC~~
~~2.6*†~~	—	First Amendment, dated July 10, 2017, to Purchase and Sale Agreement, dated June 1, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC, Linn Midstream, LLC and Bridge Energy LLC (incorporated by reference to Exhibit 2.6 to Quarterly Report on Form 10‑Q filed on August 3, 2017)
2.2	—	Purchase and Sale Agreement, dated October 3, 2017, by and between Linn Energy Holdings, LLC, Linn Operating, LLC and Washakie Exaro Opportunities, LLC (incorporated by reference to Exhibit 2.1 to Current Report on Form 8-K filed on October 5, 2017)
3.1	—	Amended and Restated Certificate of Incorporation of Linn Energy, Inc. (incorporated by reference to Exhibit 3.1 to Registration Statement on Form S-8 filed on February 28, 2017)
3.2	—	Bylaws of Linn Energy, Inc. (incorporated by reference to Exhibit 3.2 to Registration Statement on Form S-8 filed on February 28, 2017)
10.1*10.1	—	~~First Amendment and Consent to~~ Credit Agreement, dated as of ~~May 31, 2017, to Credit Agreement and Security Agreement dated as of February 28,~~August 4, 2017, among Linn Energy Holdco II LLC, as borrower, Linn Energy Holdco LLC, as parent, Linn Energy, Inc. as holdings, Royal Bank of Canada, as administrative agent, Citibank, N.A., ~~the subsidiary guarantors party thereto, Wells Fargo~~as syndication agent, Barclays Bank PLC, JPMorgan Chase Bank, N.A., Morgan Stanley Senior Funding, Inc. and PNC Bank National Association, as ~~administrative agent~~co-documentation agents, and the lenders party thereto (incorporated by reference to Exhibit 10.26 to Registration Statement on Form S-1/A filed on September 26, 2017)
10.2*	—	~~Engineering and Construction~~ First Amendment to Credit Agreement dated ~~June 13,~~as of September 29, 2017, ~~between Linn Midstream, LLC (now known as Blue Mountain Midstream LLC) and BCCK Engineering Incorporated~~
10.3*	—	~~Equipment Supply~~to Credit Agreement dated ~~June 13,~~as of August 4, 2017, ~~between Linn Midstream, LLC (now known as Blue Mountain Midstream LLC) and BCCK Engineering Incorporated~~
10.4*	—	~~Contribution Agreement, dated June 27, 2017, by and~~ among Linn Energy ~~Holdings, LLC, Linn Operating, LLC, Citizen Energy~~Holdco II LLC, as borrower, Linn Energy Holdco LLC, as parent, Linn Energy, Inc. as holdings, Royal Bank of Canada, as administrative agent, Citibank, N.A., as syndication agent, Barclays Bank PLC, JPMorgan Chase Bank, N.A., Morgan Stanley Senior Funding, Inc. and PNC Bank National Association, as co-documentation agents, and the lenders party thereto
10.3	—	Amended and Restated Limited Liability Company Agreement of Roan Resources LLC, dated as of August 31, 2017 (incorporated by reference to Exhibit 10.1 to Current Report on Form 8‑K filed on September 7, 2017)
31.1*	—	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer
31.2*	—	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer
32.1*	—	Section 1350 Certification of Chief Executive Officer
32.2*	—	Section 1350 Certification of Chief Financial Officer
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.


†	Pursuant to Item 601(b)(2) of Regulation S-K, the schedules and exhibits to the PSA have not been filed herewith. The registrant agrees to furnish supplementally copies of any omitted schedules and exhibits to the Securities and Exchange Commission upon request.

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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, INC.
	(Registrant)

Date: ~~August 3,~~November 14, 2017	/s/ Darren R. Schluter
	Darren R. Schluter
	Vice President and Controller
	(Duly Authorized Officer and Principal Accounting Officer)


Date: ~~August 3,~~November 14, 2017	/s/ David B. Rottino
	David B. Rottino
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)

6770



	July 1 – December 31, 2017		2018		2019
Natural gas positions:
Fixed price swaps (NYMEX Henry Hub):
Hedged volume (MMMBtu)	68,080		47,815		11,315
Average price ($/MMBtu)	$	3.17	$	3.01	$	2.97
Oil positions:
Fixed price swaps (NYMEX WTI):
Hedged volume (MBbls)	2,208		548		—
Average price ($/Bbl)	$	52.13	$	54.07	$	—
Collars (NYMEX WTI):
Hedged volume (MBbls)	—		1,825		1,825
Average floor price ($/Bbl)	$	—	$	50.00	$	50.00
Average ceiling price ($/Bbl)	$	—	$	55.50	$	55.50