Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



ý	QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended September 30, 2017 OR



¨	TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF SECURITIES EXCHANGE ACT OF 1934
	For the transition period from to

Commission File Number 000-19514

Gulfport Energy Corporation

(Exact Name of Registrant As Specified in Its Charter)



Delaware		73-1521290
(State or Other Jurisdiction of Incorporation or Organization)		(IRS Employer Identification Number)
3001 Quail Springs Parkway Oklahoma City, Oklahoma		73134
(Address of Principal Executive Offices)		(Zip Code)

(405) 252-4600

(Registrant 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 ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or such shorter period that the registrant was required to submit and post such files). Yes ý 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 definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

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

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 ý

As of October 27, 2017, 183,081,776 shares of the registrant’s common stock were outstanding.

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GULFPORT ENERGY CORPORATION

TABLE OF CONTENTS



		Page
PART I FINANCIAL INFORMATION

Item 1.	Consolidated Financial Statements (unaudited):	2

	Consolidated Balance Sheets at September 30, 2017 and December 31, 2016	2

	Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2017 and 2016	3

	Consolidated Statements of Comprehensive Income (Loss) for the Three and Nine Months Ended September 30, 2017 and 2016	4

	Consolidated Statements of Stockholders’ Equity for the Nine Months Ended September 30, 2017 and 2016	5

	Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2017 and 2016	6

	Notes to Consolidated Financial Statements	7

Item 2.	Management’s Discussion and Analysis of Financial Conditions and Results of Operations	37

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	54

Item 4.	Controls and Procedures	56

PART II OTHER INFORMATION

Item 1.	Legal Proceedings	58

Item 1A.	Risk Factors	58

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	58

Item 3.	Defaults Upon Senior Securities	59

Item 4.	Mine Safety Disclosures	59

Item 5.	Other Information	59

Item 6.	Exhibits	59

Signatures		61

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GULFPORT ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(Unaudited)



	September 30, 2017			December 31, 2016
	(In thousands, except share data)
Assets
Current assets:
Cash and cash equivalents	$	125,271		$	1,275,875
Restricted cash	—			185,000
Accounts receivable—oil and natural gas	180,106			136,761
Accounts receivable—related parties	362			16
Prepaid expenses and other current assets	5,666			3,135
Short-term derivative instruments	35,332			3,488
Total current assets	346,737			1,604,275
Property and equipment:
Oil and natural gas properties, full-cost accounting, $2,956,732 and $1,580,305 excluded from amortization in 2017 and 2016, respectively	8,867,239			6,071,920
Other property and equipment	84,225			68,986
Accumulated depletion, depreciation, amortization and impairment	(4,043,879		)	(3,789,780		)
Property and equipment, net	4,907,585			2,351,126
Other assets:
Equity investments	279,282			243,920
Long-term derivative instruments	6,409			5,696
Deferred tax asset	4,692			4,692
Inventories	13,908			4,504
Other assets	18,985			8,932
Total other assets	323,276			267,744
Total assets	$	5,577,598		$	4,223,145
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable and accrued liabilities	$	582,928		$	265,124
Asset retirement obligation—current	195			195
Short-term derivative instruments	29,130			119,219
Current maturities of long-term debt	570			276
Total current liabilities	612,823			384,814
Long-term derivative instrument	19,712			26,759
Asset retirement obligation—long-term	44,266			34,081
Long-term debt, net of current maturities	1,958,136			1,593,599
Total liabilities	2,634,937			2,039,253
Commitments and contingencies (Note 9)
Preferred stock, $.01 par value; 5,000,000 authorized, 30,000 authorized as redeemable 12% cumulative preferred stock, Series A; 0 issued and outstanding	—			—
Stockholders’ equity:
Common stock - $.01 par value, 200,000,000 authorized, 183,081,776 issued and outstanding at September 30, 2017 and 158,829,816 at December 31, 2016	1,831			1,588
Paid-in capital	4,413,623			3,946,442
Accumulated other comprehensive loss	(40,339		)	(53,058		)
Retained deficit	(1,432,454		)	(1,711,080		)
Total stockholders’ equity	2,942,661			2,183,892
Total liabilities and stockholders’ equity	$	5,577,598		$	4,223,145

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)



	Three months ended September 30,						Nine months ended September 30,
	2017			2016			2017			2016
	(In thousands, except share data)
Revenues:
Natural gas sales	$	223,340		$	122,018		$	606,544		$	271,873
Oil and condensate sales	31,459			21,799			85,338			60,799
Natural gas liquid sales	33,559			14,594			88,985			34,198
Net (loss) gain on natural gas, oil, and NGL derivatives	(22,860		)	35,281			141,588			(44,376		)
	265,498			193,692			922,455			322,494
Costs and expenses:
Lease operating expenses	20,020			17,471			60,044			48,789
Production taxes	5,419			3,525			14,464			9,492
Midstream gathering and processing	69,372			45,475			176,258			122,476
Depreciation, depletion and amortization	106,650			62,285			254,887			183,414
Impairment of oil and natural gas properties	—			212,194			—			601,806
General and administrative	13,065			10,467			37,922			32,941
Accretion expense	456			269			1,148			777
Acquisition expense	33			—			2,391			—
	215,015			351,686			547,114			999,695
INCOME (LOSS) FROM OPERATIONS	50,483			(157,994		)	375,341			(677,201		)
OTHER (INCOME) EXPENSE:
Interest expense	27,130			12,787			74,797			44,892
Interest income	(37		)	(337		)	(927		)	(822		)
Insurance proceeds	—			(3,750		)	—			(3,750		)
Loss (income) from equity method investments, net	2,737			(5,997		)	20,945			25,576
Other income	(345		)	6			(863		)	(3		)
	29,485			2,709			93,952			65,893
INCOME (LOSS) BEFORE INCOME TAXES	20,998			(160,703		)	281,389			(743,094		)
INCOME TAX EXPENSE (BENEFIT)	2,763			(3,407		)	2,763			(3,755		)
NET INCOME (LOSS)	$	18,235		$	(157,296	)	$	278,626		$	(739,339	)
NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	0.10		$	(1.25	)	$	1.56		$	(6.12	)
Diluted	$	0.10		$	(1.25	)	$	1.56		$	(6.12	)
Weighted average common shares outstanding—Basic	182,957,416			125,408,866			178,736,569			120,771,046
Weighted average common shares outstanding—Diluted	183,008,436			125,408,866			179,130,570			120,771,046

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)



	Three months ended September 30,					Nine months ended September 30,
	2017		2016			2017		2016
	(In thousands)
Net income (loss)	$	18,235	$	(157,296	)	$	278,626	$	(739,339	)
Foreign currency translation adjustment (1)	6,832		(4,013		)	12,719		4,361
Other comprehensive income (loss)	6,832		(4,013		)	12,719		4,361
Comprehensive income (loss)	$	25,067	$	(161,309	)	$	291,345	$	(734,978	)

(1) Net of $2.8 million in taxes for each of the three and nine months ended September 30, 2016.

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Unaudited)



				Paid-in Capital			Accumulated Other Comprehensive Income (loss)			Retained Deficit			Total Stockholders’ Equity
	Common Stock
	Shares	Amount
	(In thousands, except share data)
Balance at January 1, 2017	158,829,816	$	1,588	$	3,946,442		$	(53,058	)	$	(1,711,080	)	$	2,183,892
Net income	—	—		—			—			278,626			278,626
Other Comprehensive Income							12,719			—			12,719
Stock Compensation	—	—		7,988			—			—			7,988
Issuance of Common Stock for the Vitruvian Acquisition, net of related expenses	23,852,117	239		459,197			—			—			459,436
Issuance of Restricted Stock	399,843	4		(4		)	—			—			—
Balance at September 30, 2017	183,081,776	$	1,831	$	4,413,623		$	(40,339	)	$	(1,432,454	)	$	2,942,661

Balance at January 1, 2016	108,322,250	$	1,082	$	2,824,303		$	(55,177	)	$	(731,371	)	$	2,038,837
Net loss	—	—		—			—			(739,339		)	(739,339		)
Other Comprehensive Income	—	—		—			4,361			—			4,361
Stock Compensation	—	—		9,550			—			—			9,550
Issuance of Common Stock in public offerings, net of related expenses	16,905,000	169		411,542			—			—			411,711
Issuance of Restricted Stock	226,283	2		(2		)	—			—			—
Balance at September 30, 2016	125,453,533	$	1,253	$	3,245,393		$	(50,816	)	$	(1,470,710	)	$	1,725,120

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)



	Nine months ended September 30,
	2017			2016
	(In thousands)
Cash flows from operating activities:
Net income (loss)	$	278,626		$	(739,339	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Accretion of discount—Asset Retirement Obligation	1,148			777
Depletion, depreciation and amortization	254,887			183,414
Impairment of oil and natural gas properties	—			601,806
Stock-based compensation expense	4,793			5,730
Loss from equity investments	21,495			25,988
Change in fair value of derivative instruments	(129,692		)	184,013
Deferred income tax expense (benefit)	—			17,211
Amortization of loan commitment fees	3,548			2,912
Amortization of note discount and premium	—			(1,716		)
Changes in operating assets and liabilities:
Increase in accounts receivable	(43,345		)	(55,916		)
Increase in accounts receivable—related party	(346		)	(80		)
Increase in prepaid expenses	(2,531		)	(6,835		)
Increase in other assets	(5,665		)	—
Increase in accounts payable, accrued liabilities and other	111,335			28,265
Settlement of asset retirement obligation	(2,520		)	(955		)
Net cash provided by operating activities	491,733			245,275
Cash flows from investing activities:
Deductions to cash held in escrow	—			8
Additions to other property and equipment	(16,288		)	(20,131		)
Acquisition of oil and natural gas properties	(1,339,456		)	—
Additions to oil and natural gas properties	(789,743		)	(441,128		)
Proceeds from sale of oil and natural gas properties	4,079			41,534
Proceeds from sale of other property and equipment	658			—
Funding of restricted cash	185,000			—
Contributions to equity method investments	(44,844		)	(18,510		)
Distributions from equity method investments	4,114			14,220
Insurance proceeds	—			3,750
Net cash used in investing activities	(1,996,480		)	(420,257		)
Cash flows from financing activities:
Principal payments on borrowings	(183		)	(1,685		)
Borrowings on line of credit	365,000			—
Borrowings on term loan	2,951			16,499
Debt issuance costs and loan commitment fees	(8,261		)	(241		)
Proceeds from issuance of common stock, net of offering costs	(5,364		)	411,711
Net cash provided by financing activities	354,143			426,284
Net (decrease) increase in cash and cash equivalents	(1,150,604		)	251,302
Cash and cash equivalents at beginning of period	1,275,875			112,974
Cash and cash equivalents at end of period	$	125,271		$	364,276
Supplemental disclosure of cash flow information:
Interest payments	$	50,826		$	35,193
Income tax payments	$	—		$	—
Supplemental disclosure of non-cash transactions:
Capitalized stock based compensation	$	3,195		$	3,820
Asset retirement obligation capitalized	$	11,557		$	6,726
Interest capitalized	$	8,753		$	8,920
Foreign currency translation gain on equity method investments	$	12,719		$	7,137

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

These consolidated financial statements have been prepared by Gulfport Energy Corporation (the “Company” or “Gulfport”) without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), and reflect all adjustments which, in the opinion of management, are necessary for a fair presentation of the results for the interim periods, on a basis consistent with the annual audited consolidated financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with the consolidated financial statements and the summary of significant accounting policies and notes thereto included in the Company’s most recent annual report on Form 10-K. Results for the three and nine month periods ended September 30, 2017 are not necessarily indicative of the results expected for the full year.


1.	ACQUISITIONS

Vitruvian Acquisition

In December 2016, the Company, through its wholly-owned subsidiary Gulfport MidCon LLC (“Gulfport MidCon”) (formerly known as SCOOP Acquisition Company, LLC), entered into an agreement to acquire certain assets of Vitruvian II Woodford, LLC (“Vitruvian”), an unrelated third-party seller (the “Vitruvian Acquisition”). The assets included in the Vitruvian Acquisition include 46,400 net surface acres located in Grady, Stephens and Garvin Counties, Oklahoma. On February 17, 2017, the Company completed the Vitruvian Acquisition for a total initial purchase price of approximately $1.85 billion, consisting of $1.35 billion in cash, subject to certain adjustments, and approximately 23.9 million shares of the Company’s common stock (of which approximately 5.2 million shares were placed in an indemnity escrow). The cash portion of the purchase price was funded with the net proceeds from the December 2016 common stock and senior note offerings and cash on hand. Acquisition costs of $0.03 million and $2.4 million were incurred during the three and nine months ended September 30, 2017, respectively, related to the Vitruvian Acquisition.

Allocation of Purchase Price

The Vitruvian Acquisition qualified as a business combination for accounting purposes and, as such, the Company estimated the fair value of the acquired properties as of the February 17, 2017 acquisition date. The fair value of the assets acquired and liabilities assumed was estimated using assumptions that represent Level 3 inputs. See Note 11 for additional discussion of the measurement inputs.

The Company estimated that the consideration paid in the Vitruvian Acquisition for these properties approximated the fair value that would be paid by a typical market participant. As a result, no goodwill or bargain purchase gain was recognized in conjunction with the purchase.

The following table summarizes the consideration paid in the Vitruvian Acquisition to acquire the properties and the fair value amount of the assets acquired as of February 17, 2017. Both the consideration paid and the fair value assigned to the assets is preliminary and subject to adjustment.

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	(In thousands)
Consideration:
Cash, net of purchase price adjustments	$	1,354,093
Fair value of Gulfport’s common stock issued	464,639
Total Consideration	$	1,818,732

Estimated Fair value of identifiable assets acquired and liabilities assumed:
Oil and natural gas properties
Proved properties	$	362,264
Unproved properties	1,462,957
Asset retirement obligations	(6,489		)
Total fair value of net identifiable assets acquired	$	1,818,732

The equity consideration included in the initial purchase price was based on an equity offering price of $20.96 on December 15, 2016. The decrease in the price of Gulfport’s common stock from $20.96 on December 15, 2016 to $19.48 on February 17, 2017 resulted in a decrease to the fair value of the total consideration paid as compared to the initial purchase price of approximately $35.3 million, which resulted in a closing date fair value lower than the initial purchase price.

Post-Acquisition Operating Results

For the three months ended September 30, 2017 and the period from the acquisition date of February 17, 2017 to September 30, 2017, the assets acquired in the Vitruvian Acquisition have contributed the following amounts of revenue to the Company’s consolidated statements of operations. The amount of net income contributed by the assets acquired is not presented below as it is impracticable to calculate due to the Company integrating the acquired assets into its overall operations using the full cost method of accounting.



			Period from
			February 17, 2017
	Three months ended		to
	September 30, 2017		September 30, 2017
	(In thousands)
Revenue	$	60,940	$	137,706

Pro Forma Information (Unaudited)

The following unaudited pro forma combined financial information presents the Company’s results as though the Vitruvian Acquisition had been completed at January 1, 2016. The pro forma combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the Vitruvian Acquisition taken place on January 1, 2016; furthermore, the financial information is not intended to be a projection of future results.



	Three months ended September 30,					Nine months ended September 30,
	2017		2016			2017		2016
	(In thousands, except share data)
Pro forma revenue	$	265,498	$	250,258		$	958,354	$	425,958
Pro forma net income (loss)	$	18,235	$	(200,005	)	$	300,052	$	(935,219	)
Pro forma earnings (loss) per share (basic)	$	0.10	$	(1.34	)	$	1.68	$	(6.47	)
Pro forma earnings (loss) per share (diluted)	$	0.10	$	(1.34	)	$	1.68	$	(6.47	)

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2.	PROPERTY AND EQUIPMENT

The major categories of property and equipment and related accumulated depletion, depreciation, amortization and impairment as of September 30, 2017 and December 31, 2016 are as follows:



	September 30, 2017			December 31, 2016
	(In thousands)
Oil and natural gas properties	$	8,867,239		$	6,071,920
Office furniture and fixtures	34,875			21,204
Building	44,530			42,530
Land	4,820			5,252
Total property and equipment	8,951,464			6,140,906
Accumulated depletion, depreciation, amortization and impairment	(4,043,879		)	(3,789,780		)
Property and equipment, net	$	4,907,585		$	2,351,126

Under the full cost method of accounting, the Company is required to perform a ceiling test each quarter. The test determines a limit, or ceiling, on the book value of the oil and natural gas properties. At September 30, 2017, the calculated ceiling was greater than the net book value of the Company’s oil and natural gas properties, thus no ceiling test impairment was required for the nine months ended September 30, 2017. An impairment of $212.2 million and $601.8 million was required for oil and natural gas properties for the three and nine months ended September 30, 2016, respectively.

Included in oil and natural gas properties at September 30, 2017 is the cumulative capitalization of $155.5 million in general and administrative costs incurred and capitalized to the full cost pool. General and administrative costs capitalized to the full cost pool represent management’s estimate of costs incurred directly related to exploration and development activities such as geological and other administrative costs associated with overseeing the exploration and development activities. All general and administrative costs not directly associated with exploration and development activities were charged to expense as they were incurred. Capitalized general and administrative costs were approximately $8.9 million and $25.6 million for the three and nine months ended September 30, 2017, respectively, and $7.2 million and $22.2 million for the three and nine months ended September 30, 2016, respectively.

The following table summarizes the Company’s non-producing properties excluded from amortization by area at September 30, 2017:



	September 30, 2017
	(In thousands)
Utica	$	1,517,555
MidContinent	1,435,992
Niobrara	2,182
Southern Louisiana	536
Bakken	99
Other	368
	$	2,956,732

At December 31, 2016, approximately $1.6 billion of non-producing leasehold costs was not subject to amortization.

The Company evaluates the costs excluded from its amortization calculation at least annually. Subject to industry conditions and the level of the Company’s activities, the inclusion of most of the above referenced costs into the Company’s amortization calculation typically occurs within three to five years. However, the majority of the Company’s non-producing leases have five-year extension terms which could extend this time frame beyond five years.

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A reconciliation of the Company’s asset retirement obligation for the nine months ended September 30, 2017 and 2016 is as follows:



	September 30, 2017			September 30, 2016
	(In thousands)
Asset retirement obligation, beginning of period	$	34,276		$	26,437
Liabilities incurred	11,557			6,726
Liabilities settled	(2,520		)	(955		)
Accretion expense	1,148			777
Asset retirement obligation as of end of period	44,461			32,985
Less current portion	195			75
Asset retirement obligation, long-term	$	44,266		$	32,910


3.	EQUITY INVESTMENTS

Investments accounted for by the equity method consist of the following as of September 30, 2017 and December 31, 2016:



			Carrying value				(Income) loss from equity method investments
	Approximate ownership %		September 30, 2017		December 31, 2016		Three months ended September 30,						Nine months ended September 30,
	Approximate ownership %		September 30, 2017		December 31, 2016		2017			2016			2017			2016
			(In thousands)
Investment in Tatex Thailand II, LLC	23.5	%	$	—	$	—	$	(95	)	$	(253	)	$	(549	)	$	(412	)
Investment in Tatex Thailand III, LLC	17.9	%	—		—		—			—			—			—
Investment in Grizzly Oil Sands ULC	24.9999	%	58,674		45,213		296			363			869			24,811
Investment in Timber Wolf Terminals LLC	50.0	%	983		991		4			3			8			7
Investment in Windsor Midstream LLC	22.5	%	31		25,749		(2		)	(9,014		)	25,232			(12,062		)
Investment in Stingray Cementing LLC⁽¹⁾	—	%	—		1,920		—			79			205			187
Investment in Blackhawk Midstream LLC	48.5	%	—		—		—			—			—			—
Investment in Stingray Energy Services LLC⁽¹⁾	—	%	—		4,215		—			294			282			935
Investment in Sturgeon Acquisitions LLC⁽¹⁾	—	%	—		20,526		—			112			(71		)	623
Investment in Mammoth Energy Services, Inc.⁽¹⁾	25.1	%	149,219		111,717		2,407			2,518			(7,616		)	11,527
Investment in Strike Force Midstream LLC	25.0	%	70,375		33,589		127			(99		)	2,585			(40		)
			$	279,282	$	243,920	$	2,737		$	(5,997	)	$	20,945		$	25,576




(1)	On June 5, 2017, Mammoth Energy Services, Inc. acquired Stingray Cementing LLC, Stingray Energy Services LLC and Sturgeon Acquisitions LLC. See below under Mammoth Energy Partners LP/Mammoth Energy Services, Inc. for information regarding these transactions.

The tables below summarize financial information for the Company’s equity investments as of September 30, 2017 and December 31, 2016.

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Summarized balance sheet information:



	September 30, 2017		December 31, 2016
	September 30, 2017		December 31, 2016
	(In thousands)
Current assets	$	201,557	$	148,733
Noncurrent assets	$	1,494,770	$	1,305,407
Current liabilities	$	130,178	$	57,173
Noncurrent liabilities	$	164,759	$	67,680

Summarized results of operations:



	Three months ended September 30,				Nine months ended September 30,
	2017		2016		2017			2016
	(In thousands)
Gross revenue	$	160,950	$	76,627	$	357,901		$	206,666
Net income (loss)	$	2,101	$	35,212	$	(109,651	)	$	9,344

Tatex Thailand II, LLC

The Company has an indirect ownership interest in Tatex Thailand II, LLC (“Tatex II”). Tatex II holds an 8.5% interest in APICO, LLC (“APICO”), an international oil and gas exploration company. APICO has a reserve base located in Southeast Asia through its ownership of concessions covering approximately 180,000 acres which includes the Phu Horm Field. The Company received $0.5 million and $0.4 million in distributions from Tatex II during the nine months ended September 30, 2017 and 2016, respectively.

Tatex Thailand III, LLC

The Company has an ownership interest in Tatex Thailand III, LLC (“Tatex III”). Tatex III previously owned a concession covering approximately 245,000 acres in Southeast Asia. As of December 31, 2014, the Company reviewed its investment in Tatex III and, together with Tatex III, made the decision to allow the concession to expire in January 2015. As such, the Company fully impaired the asset as of December 31, 2014.

Grizzly Oil Sands ULC

The Company, through its wholly owned subsidiary Grizzly Holdings Inc. (“Grizzly Holdings”), owns an interest in Grizzly Oil Sands ULC (“Grizzly”), a Canadian unlimited liability company. The remaining interest in Grizzly is owned by Grizzly Oil Sands Inc. (“Oil Sands”). As of September 30, 2017, Grizzly had approximately 830,000 acres under lease in the Athabasca and Peace River oil sands regions of Alberta, Canada. Initiation of steam injection at its first project, Algar Lake Phase 1, commenced in January 2014 and first bitumen production was achieved during the second quarter of 2014. In April 2015, Grizzly determined to cease bitumen production at its Algar Lake facility due to the level of commodity prices. Grizzly continues to monitor market conditions as it assesses future plans for the facility. The Company reviewed its investment in Grizzly at March 31, 2016 for impairment based on FASB ASC 323 due to certain qualitative factors and as such, engaged an independent third party to assist management in determining fair value calculations of its investment. As a result of the calculated fair values and other qualitative factors, the Company concluded that an other than temporary impairment was required under FASB ASC 323, resulting in an impairment loss of $23.1 million for the three months ended March 31, 2016, which is included in loss from equity method investments, net in the consolidated statements of operations. As of and during the nine months ended September 30, 2017, commodity prices had increased as compared to the quarter ended March 31, 2016, and there were no impairment indicators that required further evaluation for impairment. If commodity prices decline in the future however, further impairment of the investment in Grizzly may be necessary. During the nine months ended September 30, 2017, Gulfport paid $1.8 million in cash calls. Grizzly’s functional currency is the Canadian dollar. The Company’s investment in Grizzly was increased by $6.7 million and $12.5 million as a result of a foreign currency translation gain for the three and nine months ended September 30, 2017, respectively. The Company's investment in Grizzly was decreased by $1.4 million as a result of a foreign currency translation loss and increased by $8.3 million as a result of a foreign currency translation gain for the three and nine months ended September 30, 2016, respectively.

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Timber Wolf Terminals LLC

During 2012, the Company invested in Timber Wolf Terminals LLC (“Timber Wolf”). Timber Wolf was formed to operate a crude/condensate terminal and a sand transloading facility in Ohio.

Windsor Midstream LLC

At September 30, 2017, the Company held a 22.5% interest in Windsor Midstream LLC (“Midstream”), an entity controlled and managed by an unrelated third party. Midstream previously owned a 28.4% interest in Coronado Midstream LLC (“Coronado”), a gas processing plant in West Texas. In March 2015, Coronado was sold to EnLink Midstream Partners, LP (“EnLink”). As a result of the sale of Coronado to EnLink, Midstream received common units of EnLink, which were subsequently sold by Midstream. During the nine months ended September 30, 2017, the Company noted that Midstream had not recorded certain activity and fair value treatment of Midstream's investment in EnLink common units in a timely manner. The corresponding effect of this treatment was immaterial to the Company's previously issued financial statements and the recording of the correction in the current periods' financial statements was not material to the Company's estimated net income for the current full fiscal year. For the nine months ended September 30, 2017, approximately $23.4 million of the loss from equity method investments, net was related to the out-of-period activity associated with the accounting for Midstream's investment in EnLink common units. The Company received $0.5 million and $14.2 million in distributions from Midstream during the nine months ended September 30, 2017 and 2016, respectively.

Stingray Cementing LLC

During 2012, the Company invested in Stingray Cementing LLC (“Stingray Cementing”). Stingray Cementing provides well cementing services. The (income) loss from equity method investments presented in the table above reflects any intercompany profit eliminations. On June 5, 2017, Mammoth Energy Services, Inc. (“Mammoth Energy”) acquired Stingray Cementing. See below under Mammoth Energy Partners LP/Mammoth Energy Services, Inc. for information regarding this transaction.

Blackhawk Midstream LLC

During 2012, the Company invested in Blackhawk Midstream LLC (“Blackhawk”). Blackhawk coordinated gathering, compression, processing and marketing activities for the Company in connection with the development of its Utica Shale acreage. Blackhawk does not have any current activities.

Stingray Energy Services LLC

During 2013, the Company invested in Stingray Energy Services LLC (“Stingray Energy”). Stingray Energy provides rental tools for land-based oil and natural gas drilling, completion and workover activities as well as the transfer of fresh water to wellsites. The (income) loss from equity method investments presented in the table above reflects any intercompany profit eliminations. On June 5, 2017, Mammoth Energy acquired Stingray Energy. See below under Mammoth Energy Partners LP/Mammoth Energy Services, Inc. for information regarding this transaction.

Sturgeon Acquisitions LLC

During 2014, the Company invested $20.7 million and received an ownership interest of 25% in Sturgeon Acquisitions LLC (“Sturgeon”). Sturgeon owns and operates sand mines that produce hydraulic fracturing grade sand. On June 5, 2017, Mammoth Energy acquired Sturgeon. See below under Mammoth Energy Partners LP/Mammoth Energy Services, Inc. for information regarding this transaction.

Mammoth Energy Partners LP/Mammoth Energy Services, Inc.

In the fourth quarter of 2014, the Company contributed its investments in four entities to Mammoth Energy Partners LP (“Mammoth”) for a 30.5% interest in this entity. Mammoth originally intended to pursue its initial public offering in 2014 or 2015; however, due to low commodity prices, the offering was postponed. In October 2016, Mammoth converted from a limited partnership into a limited liability company named Mammoth Energy Partners LLC (“Mammoth LLC”) and the Company and the other members of Mammoth LLC contributed their interests in Mammoth LLC to Mammoth Energy. The Company received 9,150,000 shares of Mammoth Energy common stock in return for its contribution. Following the contribution, Mammoth Energy completed its initial public offering (the “IPO”) of 7,750,000 shares of its common stock at a

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public offering price of $15.00 per share, of which 7,500,000 shares were sold by Mammoth Energy, and 250,000 shares were sold by certain selling stockholders, including 76,250 shares sold by the Company for which it received net proceeds of $1.1 million.

On June 5, 2017, the Company contributed all of its membership interests in Sturgeon (which owns Taylor Frac, LLC, Taylor Real Estate Investments, LLC and South River Road, LLC), Stingray Energy and Stingray Cementing to Mammoth Energy in exchange for approximately 2.0 million shares of Mammoth Energy common stock. As of September 30, 2017, the Company held approximately 25.1% of Mammoth Energy’s outstanding common stock. The Company accounted for the transactions as a sale of financial assets under FASB ASC 860. The Company valued the shares of Mammoth Energy common stock it received in the transactions at $18.50 per share, which was the closing price of Mammoth Energy common stock on June 5, 2017. The Company recognized a gain of $12.5 million from the transactions, which is included in loss from equity method investments, net in the accompanying consolidated statements of operations.

The Company’s investment in Mammoth Energy was increased by a $0.16 million and $0.2 million foreign currency gain resulting from Mammoth Energy’s foreign subsidiary for the three and nine months ended September 30, 2017, respectively. The Company's investment in Mammoth Energy was increased by a $0.2 million foreign currency gain and decreased by a $1.1 million foreign currency loss resulting from Mammoth Energy's foreign subsidiary for the three and nine months ended September 30, 2016, respectively. The (income) loss from equity method investments presented in the table above reflects any intercompany profit eliminations.

Strike Force Midstream LLC

In February 2016, the Company, through its wholly owned subsidiary Gulfport Midstream Holdings, LLC (“Midstream Holdings”), entered into an agreement with Rice Midstream Holdings LLC (“Rice”), a subsidiary of Rice Energy Inc., to develop natural gas gathering assets in eastern Belmont County and Monroe County, Ohio (the “dedicated areas”). The Company contributed certain gathering assets for a 25% interest in the newly formed entity called Strike Force Midstream LLC (“Strike Force”). Rice acts as operator and owns the remaining 75% interest in Strike Force. Construction of the gathering assets, which is ongoing, is expected to provide gathering services for Gulfport operated wells and connectivity of existing dry gas gathering systems. During the nine months ended September 30, 2017, Gulfport paid $43.0 million in cash calls to Strike Force and received distributions of $3.6 million from Strike Force. During the nine months ended September 30, 2016, Gulfport paid $4.0 million in cash calls to Strike Force.

The Company accounted for its initial contribution to Strike Force at fair value under applicable codification guidance. The Company estimated the fair market value of its investment in Strike Force as of the contribution date using the discounted cash flow method under the income approach, based on an independently prepared valuation of the contributed assets. The fair market value was reduced by a discount factor for the lack of marketability due to the Company’s minority interest, resulting in a fair value of $22.5 million for the Company’s 25% interest. The fair value of the assets contributed was estimated using assumptions that represent Level 3 inputs. See “Note 11 - Fair Value Measurements” for additional discussion of the measurement inputs. The Company has elected to report its proportionate share of Strike Force’s earnings on a one-quarter lag as permitted under FASB ASC 323. The (income) loss from equity method investments presented in the table above reflects any intercompany profit eliminations.


4.	VARIABLE INTEREST ENTITIES

As of September 30, 2017, the Company held variable interests in the following variable interest entities (“VIEs”), but was not the primary beneficiary: Midstream and Timber Wolf. These entities have governing provisions that are the functional equivalent of a limited partnership and are considered VIEs because the limited partners or non-managing members lack substantive kick-out or participating rights which causes the equity owners, as a group, to lack a controlling financial interest. The Company is a limited partner or non-managing member in each of these VIEs and is not the primary beneficiary because it does not have a controlling financial interest. The general partner or managing member has power to direct the activities that most significantly impact the VIEs’ economic performance. The Company also held a variable interest in Strike Force due to the fact that it does not have sufficient equity capital at risk. The Company is not the primary beneficiary of this entity. Prior to Mammoth Energy’s IPO, Mammoth LLC was considered a variable interest entity. As a result of the Company’s contribution of its interest in Mammoth LLC to Mammoth Energy in exchange for Mammoth Energy common stock and Mammoth Energy’s IPO, the Company determined that it no longer held an interest in a variable interest entity. Prior to the contribution of Stingray Energy, Stingray Cementing and Sturgeon to Mammoth Energy, these entities were considered VIEs. As a result of the Company’s contribution of its membership interests in Stingray Energy, Stingray Cementing and Sturgeon to Mammoth Energy in exchange for Mammoth Energy common stock, the Company determined that it no longer held an interest in a variable interest entity.

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The Company accounts for its investment in these VIEs following the equity method of accounting. The carrying amounts of the Company’s equity investments are classified as other non-current assets on the accompanying consolidated balance sheets. The Company’s maximum exposure to loss as a result of its involvement with these VIEs is based on the Company’s capital contributions and the economic performance of the VIEs, and is equal to the carrying value of the Company’s investments which is the maximum loss the Company could be required to record in the consolidated statements of operations. See Note 3 for further discussion of these entities, including the carrying amounts of each investment.


5.	LONG-TERM DEBT

Long-term debt consisted of the following items as of September 30, 2017 and December 31, 2016:



	September 30, 2017			December 31, 2016
	(In thousands)
Revolving credit agreement (1)	$	365,000		$	—
7.75% senior unsecured notes due 2020 (2)	—			—
6.625% senior unsecured notes due 2023 (3)	350,000			350,000
6.000% senior unsecured notes due 2024 (4)	650,000			650,000
6.375% senior unsecured notes due 2025 (5)	600,000			600,000
Net unamortized debt issuance costs (6)	(30,111		)	(27,174		)
Construction loan (7)	23,817			21,049
Less: current maturities of long term debt	(570		)	(276		)
Debt reflected as long term	$	1,958,136		$	1,593,599

The Company capitalized approximately $2.1 million and $8.8 million in interest expense to undeveloped oil and natural gas properties during the three and nine months ended September 30, 2017, respectively. The Company capitalized approximately $4.7 million and $7.7 million in interest expense to undeveloped oil and natural gas properties during the three and nine months ended September 30, 2016, respectively. During the three and nine months ended September 30, 2016, the Company also capitalized approximately $0.5 million and $1.2 million, respectively, in interest expense related to building construction. Construction on the building was completed in December 2016 and, as such, the Company did not capitalize any interest expense related to building construction for the three and nine months ended September 30, 2017.

(1) The Company has entered into a senior secured revolving credit facility, as amended, with The Bank of Nova Scotia, as the lead arranger and administrative agent and certain lenders from time to time party thereto. The credit agreement provides for a maximum facility amount of $1.5 billion and matures on June 6, 2018. On December 13, 2016, the Company further amended its revolving credit facility to, among other things, (a) reset the maturity date to December 31, 2021, (b) adjust lenders, (c) increase the basket for unsecured debt issuances to $1.6 billion, (d) increase the interest rates by 50 basis points, (e) increase the mortgage requirement to 85% (from 80%), and (f) add deposit account control agreement language. On March 29, 2017, the Company further amended its revolving credit facility to, among other things, amend the definition of the term EBITDAX to permit pro forma treatment of acquisitions that involve the payment of consideration by Gulfport and its subsidiaries in excess of $50.0 million and of dispositions of property or series of related dispositions of properties that yields gross proceeds to Gulfport or any of its subsidiaries in excess of $50.0 million. On May 4, 2017, the revolving credit facility was further amended to increase the borrowing base from $700.0 million to $1.0 billion, adjust certain of the Company’s investment baskets and add five additional banks to the syndicate.

As of September 30, 2017, $365.0 million was outstanding under the revolving credit facility and the total availability for future borrowings under this facility, after giving effect to an aggregate of $237.5 million of letters of credit, was $397.5 million. The Company’s wholly-owned subsidiaries have guaranteed the obligations of the Company under the revolving credit facility.

In connection with the Company's fall redetermination under its revolving credit facility, the lead lenders have proposed to increase the Company's borrowing base from $1.0 million to $1.2 billion, with an elected commitment of $1.0 billion, and decrease the interest rate by 50 basis points, subject to the approval of the additional required banks within the syndicate.

Advances under the revolving credit facility may be in the form of either base rate loans or eurodollar loans. The interest rate for base rate loans is equal to (1) the applicable rate, which ranges from 1.00% to 2.00%, plus (2) the highest of: (a) the

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federal funds rate plus 0.50%, (b) the rate of interest in effect for such day as publicly announced from time to time by agent as its “prime rate,” and (c) the eurodollar rate for an interest period of one month plus 1.00%. The interest rate for eurodollar loans is equal to (1) the applicable rate, which ranges from 2.00% to 3.00%, plus (2) the London interbank offered rate that appears on pages LIBOR01 or LIBOR02 of the Reuters screen that displays such rate for deposits in U.S. dollars, or, if such rate is not available, the rate as administered by ICE Benchmark Administration (or any other person that takes over administration of such rate) per annum equal to the offered rate on such other page or service that displays on average London interbank offered rate as determined by ICE Benchmark Administration (or any other person that takes over administration of such rate) for deposits in U.S. dollars, or, if such rate is not available, the average quotations for three major New York money center banks of whom the agent shall inquire as the “London Interbank Offered Rate” for deposits in U.S. dollars. At September 30, 2017, amounts borrowed under the credit facility bore interest at the eurodollar rate (3.74%).

The revolving credit facility contains customary negative covenants including, but not limited to, restrictions on the Company’s and its subsidiaries’ ability to:

•incur indebtedness;

•grant liens;

•pay dividends and make other restricted payments;

•make investments;

•make fundamental changes;

•enter into swap contracts and forward sales contracts;

•dispose of assets;

•change the nature of their business; and

•enter into transactions with affiliates.

The negative covenants are subject to certain exceptions as specified in the revolving credit facility. The revolving credit facility also contains certain affirmative covenants, including, but not limited to the following financial covenants:

(i) the ratio of net funded debt to EBITDAX (net income, excluding (i) any non-cash revenue or expense associated with swap contracts resulting from ASC 815 and (ii) any cash or non-cash revenue or expense attributable to minority investments plus without duplication and, in the case of expenses, to the extent deducted from revenues in determining net income, the sum of (a) the aggregate amount of consolidated interest expense for such period, (b) the aggregate amount of income, franchise, capital or similar tax expense (other than ad valorem taxes) for such period, (c) all amounts attributable to depletion, depreciation, amortization and asset or goodwill impairment or writedown for such period, (d) all other non-cash charges, (e) exploration costs deducted in determining net income under successful efforts accounting, (f) actual cash distributions received from minority investments, (g) to the extent actually reimbursed by insurance, expenses with respect to liability on casualty events or business interruption, and (h) all reasonable transaction expenses related to dispositions and acquisitions of assets, investments and debt and equity offerings (provided that expenses related to any unsuccessful disposition will be limited to $3.0 million in the aggregate) for a twelve-month period may not be greater than 4.00 to 1.00; and

(ii) the ratio of EBITDAX to interest expense for a twelve-month period may not be less than 3.00 to 1.00.

The Company was in compliance with all covenants at September 30, 2017.

(2) On October 17, 2012, the Company issued $250.0 million in aggregate principal amount of 7.75% Senior Notes due 2020 (the “October Notes”) under an indenture among the Company, its subsidiary guarantors and Wells Fargo Bank, National Association, as the trustee (the “senior note indenture”). On December 21, 2012, the Company issued an additional $50.0 million in aggregate principal amount of 7.75% Senior Notes due 2020 (the “December Notes”) as additional securities under the senior note indenture. On August 18, 2014, the Company issued an additional $300.0 million in aggregate principal amount of 7.75% Senior Notes due 2020 (the “August Notes”). The August Notes were issued as additional securities under the senior note indenture. The October Notes, December Notes and the August Notes are collectively referred to as the “2020 Notes.”

In October 2016, the Company repurchased (in a cash tender offer) or redeemed all of the 2020 Notes, of which $600.0 million in aggregate principal amount was then outstanding, with the net proceeds from the issuance of its 6.000% Senior Notes

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due 2024 (the “2024 Notes”) discussed below and cash on hand, and the indenture governing the 2020 Notes was fully satisfied and discharged.

(3) On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of 6.625% Senior Notes due 2023 (the “2023 Notes”) to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act (the “2023 Notes Offering”). The Company received net proceeds of approximately $343.6 million after initial purchaser discounts and commissions and estimated offering expenses.

The 2023 Notes were issued under an indenture, dated as of April 21, 2015, among the Company, the subsidiary guarantors party thereto and Wells Fargo Bank, National Association, as trustee. In October 2015, the 2023 Notes were exchanged for a new issue of substantially identical debt securities registered under the Securities Act. Pursuant to the indenture relating to the 2023 Notes, interest on the 2023 Notes accrues at a rate of 6.625% per annum on the outstanding principal amount thereof, payable semi-annually on May 1 and November 1 of each year. The 2023 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company’s future unrestricted subsidiaries.

(4) On October 14, 2016, the Company issued the 2024 Notes in aggregate principal amount of $650.0 million. The 2024 Notes were issued under an indenture, dated as of October 14, 2016, among the Company, the subsidiary guarantors party thereto and the senior note indenture trustee (the “2024 Indenture”), to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act (the “2024 Notes Offering”). Under the 2024 Indenture, interest on the 2024 Notes accrues at a rate of 6.000% per annum on the outstanding principal amount thereof from October 14, 2016, payable semi-annually on April 15 and October 15 of each year, commencing on April 15, 2017. The 2024 Notes will mature on October 15, 2024. The Company received approximately $638.9 million in net proceeds from the offering of the 2024 Notes, which was used, together with cash on hand, to purchase the outstanding 2020 Notes in a concurrent cash tender offer, to pay fees and expenses thereof, and to redeem any of the 2020 Notes that remained outstanding after the completion of the tender offer.

(5) On December 21, 2016, the Company issued $600.0 million in aggregate principal amount of 6.375% Senior Notes due 2025 (the “2025 Notes”). The 2025 Notes were issued under an indenture, dated as of December 21, 2016, among the Company, the subsidiary guarantors party thereto and the senior note indenture trustee (the “2025 Indenture”), to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, and to certain non-U.S. persons in accordance with Regulation S under the Securities Act. Under the 2025 Indenture, interest on the 2025 Notes accrues at a rate of 6.375% per annum on the outstanding principal amount thereof from December 21, 2016, payable semi-annually on May 15 and November 15 of each year, commencing on May 15, 2017. The 2025 Notes will mature on May 15, 2025. The Company received approximately $584.7 million in net proceeds from the offering of the 2025 Notes, which was used, together with the net proceeds from the Company’s December 2016 common stock offering and cash on hand, to fund the cash portion of the purchase price for the Vitruvian Acquisition. See “Note 1 – Acquisitions” for additional discussion of the Vitruvian Acquisition.

(6) In accordance with ASU 2015-03, loan issuance costs related to the 2023 Notes, the 2024 Notes and the 2025 Notes (collectively the “Notes”) have been presented as a reduction to the Notes. At September 30, 2017, total unamortized debt issuance costs were $5.5 million for the 2023 Notes, $10.2 million for the 2024 Notes and $14.3 million for the 2025 Notes. In addition, loan commitment fee costs for the construction loan agreement described immediately below were $0.1 million at September 30, 2017.

(7) On June 4, 2015, the Company entered into a construction loan agreement (the “Construction Loan”) with InterBank for the construction of a new corporate headquarters in Oklahoma City, which was substantially completed in December 2016. The Construction Loan allows for maximum principal borrowings of $24.5 million and required the Company to fund 30% of the cost of the construction before any funds could be drawn, which occurred in January 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum and was payable on the last day of the month through May 31, 2017. Monthly interest and principal payments are due beginning June 30, 2017, with the final payment due June 4, 2025. At September 30, 2017, the total borrowings under the Construction Loan were approximately $23.8 million.


6.	COMMON STOCK AND CHANGES IN CAPITALIZATION

Issuance of Common Stock

On March 15, 2016, the Company issued 16,905,000 shares of its common stock in an underwritten public offering (which included 2,205,000 shares sold pursuant to an option to purchase shares sold pursuant to an option to purchase additional shares

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of the Company’s common stock granted by the Company to, and exercised in full by, the underwriters). The net proceeds from this equity offering were approximately $411.7 million, after underwriting discounts and commissions and offering expenses. The Company used the net proceeds from this offering primarily to fund a portion of its 2017 capital development plan and for general corporate purposes.

On February 17, 2017, the Company completed the Vitruvian Acquisition for a total initial purchase price of approximately $1.85 billion, consisting of $1.35 billion in cash, subject to certain adjustments, and approximately 23.9 million shares of the Company’s common stock (of which approximately 5.2 million shares are subject to the indemnity escrow). See “Note 1 - Acquisitions” for additional discussion of the Vitruvian Acquisition.


7.	STOCK-BASED COMPENSATION

During the three and nine months ended September 30, 2017, the Company’s stock-based compensation cost was $2.8 million and $8.0 million, respectively, of which the Company capitalized $1.1 million and $3.2 million, respectively, relating to its exploration and development efforts. During the three and nine months ended September 30, 2016, the Company's stock-based compensation cost was $3.0 million and $9.6 million, respectively, of which the Company capitalized $1.2 million and $3.8 million, respectively, relating to its exploration and development efforts.

The following table summarizes restricted stock activity for the nine months ended September 30, 2017:



	Number of Unvested Restricted Shares		Weighted Average Grant Date Fair Value
Unvested shares as of January 1, 2017	613,056		$	32.90
Granted	870,358		15.15
Vested	(399,843	)	28.77
Forfeited	(74,024	)	30.45
Unvested shares as of September 30, 2017	1,009,547		$	19.42

Unrecognized compensation expense as of September 30, 2017 related to restricted shares was $17.2 million. The expense is expected to be recognized over a weighted average period of 1.61 years.

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8.	EARNINGS PER SHARE

Reconciliations of the components of basic and diluted net income (loss) per common share are presented in the tables below:



	Three months ended September 30,
	2017					2016
	Income		Shares	Per Share		(Loss)			Shares	Per Share
	(In thousands, except share data)
Basic:
Net income (loss)	$	18,235	182,957,416	$	0.10	$	(157,296	)	125,408,866	$	(1.25	)
Effect of dilutive securities:
Stock options and awards	—		51,020			—			—
Diluted:			—						0
Net income (loss)	$	18,235	183,008,436	$	0.10	$	(157,296	)	125,408,866	$	(1.25	)





	Nine months ended September 30,
	2017					2016
	Income		Shares	Per Share		(Loss)			Shares	Per Share
	(In thousands, except share data)
Basic:
Net income (loss)	$	278,626	178,736,569	$	1.56	$	(739,339	)	120,771,046	$	(6.12	)
Effect of dilutive securities:
Stock options and awards	—		394,001			—			—
Diluted:			—						—
Net income (loss)	$	278,626	179,130,570	$	1.56	$	(739,339	)	120,771,046	$	(6.12	)

There were 603,068 and 598,753 shares of common stock that were considered anti-dilutive for the three months and nine months ended September 30, 2016, respectively.

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9.	COMMITMENTS AND CONTINGENCIES

Plugging and Abandonment Funds

In connection with the Company’s acquisition in 1997 of the remaining 50% interest in its WCBB properties, the Company assumed the seller’s (Chevron) obligation to contribute approximately $18,000 per month through March 2004 to a plugging and abandonment trust and the obligation to plug a minimum of 20 wells per year for 20 years commencing March 11, 1997. Chevron retained a security interest in production from these properties until the Company’s abandonment obligations to Chevron have been fulfilled. Beginning in 2009, the Company could access the trust for use in plugging and abandonment charges associated with the property, although it has not yet done so. As of September 30, 2017, the plugging and abandonment trust totaled approximately $3.1 million. At September 30, 2017, the Company had plugged 551 wells at WCBB since it began its plugging program in 1997, which management believes fulfills its minimum plugging obligation.

Operating Leases

The Company leases office facilities under non-cancellable operating leases exceeding one year. Future minimum lease commitments under these leases at September 30, 2017 were as follows:



	(In thousands)
Remaining 2017	$	27
2018	54
Total	$	81

Firm Transportation Commitments

The Company had approximately 3,077,000 MMBtu per day of firm sales contracted with third parties. The table below presents these commitments at September 30, 2017 as follows:



		(MMBtu per day)
Remaining 2017		710,000
2018		561,000
2019		659,000
2020		526,000
2021		372,000
Thereafter		249,000
Total		3,077,000

The Company also had approximately $3.7 billion of firm transportation contracted with third parties. The table below presents these commitments at September 30, 2017 as follows:



	(In thousands)
Remaining 2017	$	49,052
2018	238,767
2019	243,389
2020	240,746
2021	239,786
Thereafter	2,715,005
Total	$	3,726,745

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Other Commitments

Effective October 1, 2014, the Company entered into a Sand Supply Agreement with Muskie Proppant LLC (“Muskie”), a subsidiary of Mammoth Energy, that expires on September 30, 2018. Pursuant to this agreement, as amended, the Company has agreed to purchase annual and monthly amounts of proppant sand subject to exceptions specified in the agreement at agreed pricing plus agreed costs and expenses. Failure by either Muskie or the Company to deliver or accept the minimum monthly amount results in damages calculated per ton based on the difference between the monthly obligation amount and the amount actually delivered or accepted, as applicable. The Company incurred $0.2 million and $2.1 million related to non-utilization fees during the three months and nine months ended September 30, 2016, respectively. The Company did not incur any non-utilization fees during the three and nine months ended September 30, 2017.

Effective October 1, 2014, the Company entered into an Amended and Restated Master Services Agreement for pressure pumping services with Stingray Pressure Pumping LLC (“Stingray Pressure”), a subsidiary of Mammoth Energy, that expires on September 30, 2018. Pursuant to this agreement, as amended, Stingray Pressure has agreed to provide hydraulic fracturing, stimulation and related completion and rework services to the Company and the Company has agreed to pay Stingray Pressure a monthly service fee plus the associated costs of the services provided.

Future minimum commitments under these agreements at September 30, 2017 are as follows:



	(In thousands)
Remaining 2017	$	13,110
2018	39,330
Total	$	52,440

Litigation

In two separate complaints, one filed by the State of Louisiana and the Parish of Cameron in the 38th Judicial District Court for the Parish of Cameron on February 9, 2016 and the other filed by the State of Louisiana and the District Attorney for the 15^th Judicial District of the State of Louisiana in the 15^th Judicial District Court for the Parish of Vermillion on July 29, 2016, the Company was named as a defendant, among 26 oil and gas companies, in the Cameron Parish complaint and among more than 40 oil and gas companies in the Vermillion Parish complaint, or the Complaints. The Complaints were filed under the State and Local Coastal Resources Management Act of 1978, as amended, and the rules, regulations, orders and ordinances adopted thereunder, which the Company referred to collectively as the CZM Laws, and allege that certain of the defendants’ oil and gas exploration, production and transportation operations associated with the development of the East Hackberry and West Hackberry oil and gas fields, in the case of the Cameron Parish complaint, and the Tigre Lagoon and Lac Blanc oil and gas fields, in the case of the Vermillion Parish complaint, were conducted in violation of the CZM Laws. The Complaints allege that such activities caused substantial damage to land and waterbodies located in the coastal zone of the relevant Parish, including due to defendants’ design, construction and use of waste pits and the alleged failure to properly close the waste pits and to clear, re-vegetate, detoxify and return the property affected to its original condition, as well as the defendants’ alleged discharge of waste into the coastal zone. The Complaints also allege that the defendants’ oil and gas activities have resulted in the dredging of numerous canals, which had a direct and significant impact on the state coastal waters within the relevant Parish and that the defendants, among other things, failed to design, construct and maintain these canals using the best practical techniques to prevent bank slumping, erosion and saltwater intrusion and to minimize the potential for inland movement of storm-generated surges, which activities allegedly have resulted in the erosion of marshes and the degradation of terrestrial and aquatic life therein. The Complaints also allege that the defendants failed to re-vegetate, refill, clean, detoxify and otherwise restore these canals to their original condition. In these two petitions, the plaintiffs seek damages and other appropriate relief under the CZM Laws, including the payment of costs necessary to clear, re-vegetate, detoxify and otherwise restore the affected coastal zone of the relevant Parish to its original condition, actual restoration of such coastal zone to its original condition, and the payment of reasonable attorney fees and legal expenses and pre-judgment and post judgment interest.

The Company was served with the Cameron complaint in early May 2016 and with the Vermillion complaint in early September 2016. The Louisiana Attorney General and the Louisiana Department of Natural Resources intervened in both the Cameron Parish suit and the Vermillion Parish suit. Shortly after the Complaints were filed, certain defendants removed the cases to the lawsuit to the United States District Court for the Western District of Louisiana. In both cases, the plaintiffs filed a motion to remand, and the plaintiffs agreed to an extension of time for all defendants to file responsive pleadings until the District Courts ruled on the motions to remand. In the Vermilion Parish case, the District Court entered an order on September 26, 2017 remanding the lawsuit to the 15th Judicial District Court, State of Louisiana, Parish of Vermilion. Pursuant to an

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agreement with plaintiffs’ counsel, all defendants have an extension of time through November 27, 2017 to file responsive pleadings to plaintiffs’ petitions in the Vermilion Parish lawsuit. In the Cameron Parish lawsuit, the District Court has not ruled on plaintiffs’ motion to remand. Briefing on the motion to remand has been completed; however, no hearing has been set for the motion to remand, and the District Court has not given the parties any indication regarding when a ruling should be expected. Due the procedural posture of lawsuits, the fact that responsive pleadings have not been filed and the fact that the parties have not begun discovery, the Company has not had the opportunity to evaluate the applicability of the allegations made in plaintiffs' complaints to the Company's operations and management cannot determine the amount of loss, if any, that may result.

In addition, due to the nature of the Company’s business, it is, from time to time, involved in routine litigation or subject to disputes or claims related to its business activities, including workers’ compensation claims and employment related disputes. In the opinion of the Company’s management, none of the pending litigation, disputes or claims against the Company, if decided adversely, will have a material adverse effect on its financial condition, cash flows or results of operations.


10.	DERIVATIVE INSTRUMENTS

Natural Gas, Oil and Natural Gas Liquids Derivative Instruments

The Company seeks to reduce its exposure to unfavorable changes in natural gas, oil and natural gas liquids prices, which are subject to significant and often volatile fluctuation, by entering into over-the-counter fixed price swaps, basis swaps and various types of option contracts. These contracts allow the Company to predict with greater certainty the effective natural gas, oil and natural gas liquids prices to be received for hedged production and benefit operating cash flows and earnings when market prices are less than the fixed prices provided in the contracts. However, the Company will not benefit from market prices that are higher than the fixed prices in the contracts for hedged production.

Fixed price swaps are settled monthly based on differences between the fixed price specified in the contract and the referenced settlement price. When the referenced settlement price is less than the price specified in the contract, the Company receives an amount from the counterparty based on the price difference multiplied by the volume. Similarly, when the referenced settlement price exceeds the price specified in the contract, the Company pays the counterparty an amount based on the price difference multiplied by the volume. The prices contained in these fixed price swaps are based on the NYMEX Henry Hub for natural gas, Argus Louisiana Light Sweet Crude for oil, the NYMEX West Texas Intermediate for oil, and Mont Belvieu for propane and pentane. Below is a summary of the Company’s open fixed price swap positions as of September 30, 2017.



	Location	Daily Volume (MMBtu/day)	Weighted Average Price
Remaining 2017	NYMEX Henry Hub	765,000	$	3.19
2018	NYMEX Henry Hub	898,000	$	3.06
2019	NYMEX Henry Hub	112,000	$	3.01



	Location	Daily Volume (Bbls/day)	Weighted Average Price
Remaining 2017	ARGUS LLS	1,500	$	53.12
2018	ARGUS LLS	1,000	$	53.91
Remaining 2017	NYMEX WTI	4,500	$	54.89
2018	NYMEX WTI	3,000	$	52.24



	Location	Daily Volume (Bbls/day)	Weighted Average Price
Remaining 2017	Mont Belvieu C3	3,000	$	26.63
2018	Mont Belvieu C3	3,500	$	28.03
Remaining 2017	Mont Belvieu C5	250	$	49.14
2018	Mont Belvieu C5	500	$	46.62

The Company sold call options and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps listed above. Each short call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these short call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volumes.



	Location	Daily Volume (MMBtu/day)	Weighted Average Price
Remaining 2017	NYMEX Henry Hub	65,000	$	3.11
2018	NYMEX Henry Hub	103,000	$	3.25
2019	NYMEX Henry Hub	135,000	$	3.07

For a portion of the combined natural gas derivative instruments containing fixed price swaps and sold call options, the counterparty has an option to extend the original terms an additional twelve months for the period January 2018 through December 2018. The option to extend the terms expires in December 2017. If extended, the Company would have additional fixed price swaps for 30,000 MMBtu per day at a weighted average price of $3.36 per MMBtu and additional short call options for 30,000 MMBtu per day at a weighted average ceiling price of $3.36 per MMBtu.

For a portion of the natural gas fixed price swaps listed above, the counterparty has an option to extend the original terms an additional twelve months for the period January 2019 through December 2019. The option to extend the terms expires in December 2018. If executed, the Company would have additional fixed price swaps for 100,000 MMBtu per day at a weighted average price of $3.05 per MMBtu.

In addition, the Company has entered into natural gas basis swap positions, which settle on the pricing index to basis differential of NGPL Mid-Continent to NYMEX Henry Hub. As of September 30, 2017, the Company had the following natural gas basis swap positions for NGPL Mid-Continent.



	Location	Daily Volume (MMBtu/day)	Hedged Differential
Remaining 2017	NGPL Mid-Continent	50,000	$	(0.26	)
2018	NGPL Mid-Continent	12,000	$	(0.26	)

Balance Sheet Presentation

The Company reports the fair value of derivative instruments on the consolidated balance sheets as derivative instruments under current assets, noncurrent assets, current liabilities and noncurrent liabilities on a gross basis. The Company determines the current and noncurrent classification based on the timing of expected future cash flows of individual trades. The following table presents the fair value of the Company’s derivative instruments on a gross basis at September 30, 2017 and December 31, 2016:



	September 30, 2017		December 31, 2016
	(In thousands)
Short-term derivative instruments - asset	$	35,332	$	3,488
Long-term derivative instruments - asset	$	6,409	$	5,696
Short-term derivative instruments - liability	$	29,130	$	119,219
Long-term derivative instruments - liability	$	19,712	$	26,759

Gains and Losses

The following table presents the gain and loss recognized in Net (loss) gain on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the three and nine months ended September 30, 2017 and 2016.



	Net (loss) gain on derivative instruments
	Three months ended September 30,					Nine months ended September 30,
	2017			2016		2017			2016
	(In thousands)
Natural gas derivatives	$	(7,077	)	$	33,167	$	135,868		$	(43,454	)
Oil derivatives	(6,571		)	1,708		12,477			362
Natural gas liquids derivatives	(9,212		)	406		(6,757		)	(1,284		)
Total	$	(22,860	)	$	35,281	$	141,588		$	(44,376	)

Offsetting of derivative assets and liabilities

As noted above, the Company records the fair value of derivative instruments on a gross basis. The following table presents the gross amounts of recognized derivative assets and liabilities in the consolidated balance sheets and the amounts that are subject to offsetting under master netting arrangements with counterparties, all at fair value.



	As of September 30, 2017
	Gross Assets (Liabilities)			Gross Amounts
	Presented in the			Subject to Master			Net
	Consolidated Balance Sheets			Netting Agreements			Amount
	(In thousands)
Derivative assets	$	41,741		$	(36,969	)	$	4,772
Derivative liabilities	$	(48,842	)	$	36,969		$	(11,873	)



	As of December 31, 2016
	Gross Assets (Liabilities)			Gross Amounts
	Presented in the			Subject to Master			Net
	Consolidated Balance Sheets			Netting Agreements			Amount
	(In thousands)
Derivative assets	$	9,184		$	(9,184	)	$	—
Derivative liabilities	$	(145,978	)	$	9,184		$	(136,794	)

Concentration of Credit Risk

By using derivative instruments that are not traded on an exchange, the Company is exposed to the credit risk of its counterparties. Credit risk is the risk of loss from counterparties not performing under the terms of the derivative instrument. When the fair value of a derivative instrument is positive, the counterparty is expected to owe the Company, which creates credit risk. To minimize the credit risk in derivative instruments, it is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. The Company’s derivative contracts are with multiple counterparties to lessen its exposure to any individual counterparty. Additionally, the Company uses master netting agreements to minimize credit risk exposure. The creditworthiness of the Company’s counterparties is subject to periodic review. None of the Company’s derivative instrument contracts contain credit-risk related contingent features. Other than as provided by the Company’s revolving credit facility, the Company is not required to provide credit support or collateral to any of its counterparties under its derivative instruments, nor are the counterparties required to provide credit support to the Company.


11.	FAIR VALUE MEASUREMENTS

The Company records certain financial and non-financial assets and liabilities on the balance sheet at fair value in accordance with FASB ASC 820, “Fair Value Measurement and Disclosures” (“FASB ASC 820”). FASB ASC 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. The statement establishes market or observable inputs as the preferred

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sources of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. The statement requires fair value measurements be classified and disclosed in one of the following categories:

Level 1 – Quoted prices in active markets for identical assets and liabilities.

Level 2 – Quoted prices in active markets for similar assets and liabilities, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations whose inputs are observable or whose significant value drivers are observable.

Level 3 – Significant inputs to the valuation model are unobservable.

Valuation techniques that maximize the use of observable inputs are favored. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. Reclassifications of fair value between Level 1, Level 2 and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter.

The following tables summarize the Company’s financial and non-financial assets and liabilities by FASB ASC 820 valuation level as of September 30, 2017 and December 31, 2016:



	September 30, 2017
	Level 1		Level 2		Level 3
	(In thousands)
Assets:
Derivative Instruments	$	—	$	41,741	$	—
Liabilities:
Derivative Instruments	$	—	$	48,842	$	—



	December 31, 2016
	Level 1		Level 2		Level 3
	(In thousands)
Assets:
Derivative Instruments	$	—	$	9,184	$	—
Liabilities:
Derivative Instruments	$	—	$	145,978	$	—

The Company estimates the fair value of all derivative instruments industry-standard models that considered various assumptions including current market and contractual prices for the underlying instruments, implied volatility, time value, nonperformance risk, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be supported by observable data.

The estimated fair values of proved oil and natural gas properties assumed in business combinations are based on a discounted cash flow model and market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk-adjusted discount rates. The estimated fair values of unevaluated oil and natural gas properties was based on geological studies, historical well performance, location and applicable mineral lease terms. Based on the unobservable nature of certain of the inputs, the estimated fair value of the oil and gas properties assumed is deemed to use Level 3 inputs. The asset retirement obligations assumed as part of the business combination were estimated using the same assumptions and methodology as described below. See Note 1 for further discussion of the Vitruvian Acquisition.

The Company estimates asset retirement obligations pursuant to the provisions of FASB ASC Topic 410, Asset Retirement and Environmental Obligations (“FASB ASC 410”). The initial measurement of asset retirement obligations at fair value is

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calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with oil and gas properties. Given the unobservable nature of the inputs, including plugging costs and reserve lives, the initial measurement of the asset retirement obligation liability is deemed to use Level 3 inputs. See Note 2 for further discussion of the Company’s asset retirement obligations. Asset retirement obligations incurred during the nine months ended September 30, 2017 were approximately $11.6 million.

The fair value of the common stock received from Mammoth Energy in connection with the Company’s contribution of all of its membership interests in Sturgeon, Stingray Energy and Stingray Cementing was estimated using Level 1 inputs, as the price per share was a quoted price in an active market for identical Mammoth Energy common shares.

Due to the unobservable nature of the inputs, the fair value of the Company’s investment in Grizzly was estimated using assumptions that represent Level 3 inputs. The Company estimated the fair value of the investment as of March 31, 2016 to be approximately $39.1 million. See Note 3 for further discussion of the Company’s investment in Grizzly.

Due to the unobservable nature of the inputs, the fair value of the Company’s initial investment in Strike Force was estimated using assumptions that represent Level 3 inputs. The Company’s estimated fair value of the investment as of the February 1, 2016 contribution date was $22.5 million. See Note 3 for further discussion of the Company’s contribution to Strike Force.


12.	FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts on the accompanying consolidated balance sheet for cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, and current debt are carried at cost, which approximates market value due to their short-term nature. Long-term debt related to the Construction Loan is carried at cost, which approximates market value based on the borrowing rates currently available to the Company with similar terms and maturities.

At September 30, 2017, the carrying value of the outstanding debt represented by the Notes was approximately $1.6 billion, including the unamortized debt issuance cost of approximately $5.5 million related to the 2023 Notes, approximately $10.2 million related to the 2024 Notes and approximately $14.3 million related to the 2025 Notes. Based on the quoted market price, the fair value of the Notes was determined to be approximately $1.6 billion at September 30, 2017.


13.	CONDENSED CONSOLIDATING FINANCIAL INFORMATION

On October 17, 2012, December 21, 2012 and August 18, 2014, the Company issued the 2020 Notes in an aggregate of $600.0 million principal amount. The 2020 Notes were subsequently exchanged for substantially identical notes in the same aggregate principal amount that were registered under the Securities Act. In October 2016, the Company repurchased (in a cash tender offer) or redeemed all of the 2020 Notes, of which $600.0 million in aggregate principal amount was then outstanding, with the net proceeds from the issuance of the 2024 Notes discussed below and cash on hand.

On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of the 2023 Notes to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act. In connection with the 2023 Notes Offering, the Company and its subsidiary guarantors entered into a registration rights agreement, dated as of April 21, 2015, pursuant to which the Company agreed to file a registration statement with respect to an offer to exchange the 2023 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the 2023 Notes was completed on October 13, 2015.

On October 14, 2016, the Company issued $650.0 million in aggregate principal amount of the 2024 Notes to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act. The net proceeds from the issuance of the 2024 Notes, together with cash on hand, were used to repurchase or redeem all of the then-outstanding 2020 Notes in October 2016.

On December 21, 2016, the Company issued $600.0 million in aggregate principal amount of the 2025 Notes to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act. The Company used the net proceeds from the issuance of the 2025 Notes, together with the net proceeds from the December 2016 underwritten offering of the Company’s common stock and cash on hand, to fund the cash portion of the purchase price for the Vitruvian Acquisition.

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In connection with the 2024 Notes and the 2025 Notes Offerings, the Company and its subsidiary guarantors entered into two registration rights agreements, pursuant to which the Company agreed to file a registration statement with respect to offers to exchange the 2024 Notes and the 2025 Notes for new issues of substantially identical debt securities registered under the Securities Act. The exchange offers for the 2024 Notes and the 2025 Notes were completed on September 13, 2017.

The 2020 Notes were, and the 2023 Notes, the 2024 Notes and the 2025 Notes are, guaranteed on a senior unsecured basis by all existing consolidated subsidiaries that guarantee the Company’s secured revolving credit facility or certain other debt (the “Guarantors”). The 2020 Notes were not, and the 2023 Notes, the 2024 Notes and the 2025 Notes are not, guaranteed by Grizzly Holdings, Inc. (the “Non-Guarantor”). The Guarantors are 100% owned by Gulfport (the “Parent”), and the guarantees are full, unconditional, joint and several. There are no significant restrictions on the ability of the Parent or the Guarantors to obtain funds from each other in the form of a dividend or loan.

The following condensed consolidating balance sheets, statements of operations, statements of comprehensive (loss) income and statements of cash flows are provided for the Parent, the Guarantors and the Non-Guarantor and include the consolidating adjustments and eliminations necessary to arrive at the information for the Company on a condensed consolidated basis. The information has been presented using the equity method of accounting for the Parent’s ownership of the Guarantors and the Non-Guarantor.

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CONDENSED CONSOLIDATING BALANCE SHEETS

(Amounts in thousands)



	September 30, 2017
	Parent			Guarantors			Non-Guarantor			Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	89,095		$	36,175		$	1		$	—		$	125,271
Accounts receivable - oil and natural gas	126,746			53,360			—			—			180,106
Accounts receivable - related parties	362			—			—			—			362
Accounts receivable - intercompany	514,187			57,927			—			(572,114		)	—
Prepaid expenses and other current assets	5,486			180			—			—			5,666
Short-term derivative instruments	35,332			—			—			—			35,332
Total current assets	771,208			147,642			1			(572,114		)	346,737
Property and equipment:
Oil and natural gas properties, full-cost accounting	6,371,324			2,496,644			—			(729		)	8,867,239
Other property and equipment	84,182			43			—			—			84,225
Accumulated depletion, depreciation, amortization and impairment	(4,043,843		)	(36		)	—			—			(4,043,879		)
Property and equipment, net	2,411,663			2,496,651			—			(729		)	4,907,585
Other assets:
Equity investments and investments in subsidiaries	2,262,011			70,375			58,674			(2,111,778		)	279,282
Long-term derivative instruments	6,409			—			—			—			6,409
Deferred tax asset	4,692			—			—			—			4,692
Inventories	9,438			4,470			—			—			13,908
Other assets	10,561			8,424			—			—			18,985
Total other assets	2,293,111			83,269			58,674			(2,111,778		)	323,276
Total assets	$	5,475,982		$	2,727,562		$	58,675		$	(2,684,621	)	$	5,577,598

Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable and accrued liabilities	$	430,195		$	152,733		$	—		$	—		$	582,928
Accounts payable - intercompany	57,927			514,060			127			(572,114		)	—
Asset retirement obligation - current	195			—			—			—			195
Derivative instruments	29,130			—			—			—			29,130
Current maturities of long-term debt	570			—			—			—			570
Total current liabilities	518,017			666,793			127			(572,114		)	612,823
Long-term derivative instrument	19,712			—			—			—			19,712
Asset retirement obligation - long-term	37,456			6,810			—			—			44,266
Long-term debt, net of current maturities	1,958,136			—			—			—			1,958,136
Total liabilities	2,533,321			673,603			127			(572,114		)	2,634,937

Stockholders’ equity:
Common stock	1,831			—			—			—			1,831
Paid-in capital	4,413,623			1,905,599			258,871			(2,164,470		)	4,413,623
Accumulated other comprehensive (loss) income	(40,339		)	—			(38,443		)	38,443			(40,339		)
Retained (deficit) earnings	(1,432,454		)	148,360			(161,880		)	13,520			(1,432,454		)
Total stockholders’ equity	2,942,661			2,053,959			58,548			(2,112,507		)	2,942,661
Total liabilities and stockholders’ equity	$	5,475,982		$	2,727,562		$	58,675		$	(2,684,621	)	$	5,577,598

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CONDENSED CONSOLIDATING BALANCE SHEETS

(Amounts in thousands)

December 31, 2016

Parent

Guarantors

Non-Guarantor

Eliminations

Consolidated

Assets

Current assets:

Cash and cash equivalents

1,273,882