GULFPORT ENERGY CORP - Quarter Report: 2021 March (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


☒			QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2021


☐			TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number 001-19514

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)

Securities registered pursuant to Section 12(b) of the Act:

None(1)

(1) On November 27, 2020, our common stock was suspended from trading on the NASDAQ Stock Market LLC ("NASDAQ"). On November 30, 2020, our common stock began trading on the OTC Pink Marketplace maintained by the OTC Markets Group, Inc. under the symbol “GPORQ". On February 2, 2021, NASDAQ filed a Form 25 delisting our common stock from trading on NASDAQ, which delisting became effective 10 days after the filing of the Form 25. In accordance with Rule 12d2-2 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), the de-registration of our common stock under section 12(b) of the Exchange Act became effective on February 12, 2021.

Securities registered pursuant to Section 12(g) of the Act:

Common Stock

(Title of Class)

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 every Interactive Data File required to be submitted 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 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 ¨ Accelerated filer ý 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 April 30, 2021, 160,892,447 shares of the registrant’s common stock were outstanding.

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GULFPORT ENERGY CORPORATION

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		Page
PART I FINANCIAL INFORMATION

Item 1.	Consolidated Financial Statements (Unaudited):	3

	Consolidated Balance Sheets at March 31, 2021 and December 31, 2020	3

	Consolidated Statements of Operations for the Three Months Ended March 31, 2021 and 2020	4

	Consolidated Statements of Comprehensive Income (Loss) for the Three Months Ended March 31, 2021 and 2020	5

	Consolidated Statements of Stockholders’ (Deficit) Equity for the Three Months Ended March 31, 2021 and 2020	6

	Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2021 and 2020	7

	Notes to Consolidated Financial Statements	8

Item 2.	Management’s Discussion and Analysis of Financial Conditions and Results of Operations	31

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	47

Item 4.	Controls and Procedures	49

PART II OTHER INFORMATION

Item 1.	Legal Proceedings	50

Item 1A.	Risk Factors	50

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	50

Item 3.	Defaults Upon Senior Securities	50

Item 4.	Mine Safety Disclosures	50

Item 5.	Other Information	51

Item 6.	Exhibits	52

Signatures		54

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DEFINITIONS


Unless the context otherwise indicates, references to “us,” “we,” “our,” “ours,” “Gulfport,” the “Company” and “Registrant” refer to Gulfport Energy Corporation and its consolidated subsidiaries. All monetary values, other than per unit and per share amounts, are stated in thousands of U.S. dollars unless otherwise specified. In addition, the following are other abbreviations and definitions of certain terms used within this Quarterly Report on Form 10-Q:





2023 Notes. 6.625% Senior Notes due 2023.
2024 Notes. 6.000% Senior Notes due 2024.
2025 Notes. 6.375% Senior Notes due 2025.
2026 Notes. 6.375% Senior Notes due 2026.
ASC. Accounting Standards Codification.
ASU. Accounting Standards Update.
Bankruptcy Code. Chapter 11 of Title 11 of the United States Code.
Bankruptcy Court. The United States Bankruptcy Court for the Southern District of Texas.

Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume, used herein in reference to crude oil or other liquid hydrocarbons.


Btu. British thermal unit, which represents the amount of energy needed to heat one pound of water by one degree Fahrenheit and can be used to describe the energy content of fuels.
Building Loan. Loan agreement for our corporate headquarters scheduled to mature in June 2025.
Chapter 11 Cases. Voluntary petitions filed on November 13, 2020 by Gulfport Energy Corporation, Gator Marine, Inc., Gator Marine Ivanhoe, Inc., Grizzly Holdings, Inc., Gulfport Appalachia, LLC, Gulfport Midcon, LLC, Gulfport Midstream Holdings, LLC, Jaguar Resources LLC, Mule Sky LLC, Puma Resources, Inc. and Westhawk Minerals LLC.
Completion. The process of treating a drilled well followed by the installation of permanent equipment for the production of natural gas, oil and NGL.

DD&A. Depreciation, depletion and amortization.
Debtors. Collectively, Gulfport Energy Corporation, Gator Marine, Inc., Gator Marine Ivanhoe, Inc., Grizzly Holdings, Inc., Gulfport Appalachia, LLC, Gulfport Midcon, LLC, Gulfport Midstream Holdings, LLC, Jaguar Resources LLC, Mule Sky LLC, Puma Resources, Inc. and Westhawk Minerals LLC.


DIP Credit Facility. Senior secured superpriority debtor-in-possession revolving credit facility in an aggregate principal amount of $262.5 million.


Grizzly. Grizzly Oil Sands ULC.
Grizzly Holdings. Grizzly Holdings Inc.
Gross Acres or Gross Wells. Refers to the total acres or wells in which a working interest is owned.
Guarantors. All existing consolidated subsidiaries that guarantee the Company's revolving credit facility or certain other debt.


LIBOR. London Interbank Offered Rate.
LOE. Lease operating expenses.
MBbl. One thousand barrels of crude oil, condensate or natural gas liquids.
Mcf. One thousand cubic feet of natural gas.
Mcfe. One thousand cubic feet of natural gas equivalent.

MMBtu. One million British thermal units.
MMcf. One million cubic feet of natural gas.
MMcfe. One million cubic feet of natural gas equivalent.
Natural Gas Liquids (NGL). Hydrocarbons in natural gas that are separated from the gas as liquids through the process of absorption, condensation, adsorption or other methods in gas processing or cycling plants. Natural gas liquids primarily include ethane, propane, butane, isobutene, pentane, hexane and natural gasoline.
Net Acres or Net Wells. Refers to the sum of the fractional working interests owned in gross acres or gross wells.

NYMEX. New York Mercantile Exchange.

Petition Date. November 13, 2020.
Plan. The Amended Joint Chapter 11 Plan of Reorganization of Gulfport Energy Corporation and Its Debtor Subsidiaries.

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Pre-Petition Revolving Credit Facility. 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 with a maximum facility amount of $580 million.






Restructuring. Restructuring contemplated under the Restructuring Support Agreement including equitizing a significant portion of our pre-petition indebtedness and rejecting or renegotiating certain contracts.

RSA. Restructuring Support Agreement.
SCOOP. Refers to the South Central Oklahoma Oil Province, a term used to describe a defined area that encompasses many of the top hydrocarbon producing counties in Oklahoma within the Anadarko basin. The SCOOP play mainly targets the Devonian to Mississippian aged Woodford, Sycamore and Springer formations. Our acreage is primarily in Garvin, Grady and Stephens Counties.
SEC. The United States Securities and Exchange Commission.

Senior Notes. Collectively, the 2023 Notes, 2024 Notes, 2025 Notes and 2026 Notes.


Undeveloped Acreage. Lease or mineral acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of crude oil and/or natural gas.

Utica. Refers to the hydrocarbon bearing rock formation located in the Appalachian Basin of the United States and Canada. Our acreage is located primarily in Belmont, Harrison, Jefferson and Monroe Counties in Eastern Ohio.
Working Interest (WI). The operating interest which gives the owner the right to drill, produce and conduct operating activities on the property and a share of production.
WTI. Refers to West Texas Intermediate.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

(DEBTOR-IN-POSSESSION)


	March 31, 2021		December 31, 2020
	(Unaudited)
	(In thousands, except share data)
Assets
Current assets:
Cash and cash equivalents	$	179,701	$	89,861


Accounts receivable—oil and natural gas sales	133,996		119,879
Accounts receivable—joint interest and other	12,904		12,200

Prepaid expenses and other current assets	134,509		160,664
Short-term derivative instruments	12,422		27,146
Total current assets	473,532		409,750
Property and equipment:
Oil and natural gas properties, full-cost accounting, $1,413,774 and $1,457,043 excluded from amortization in 2021 and 2020, respectively	10,895,625		10,816,909
Other property and equipment	88,835		88,538
Accumulated depletion, depreciation, amortization and impairment	(8,874,899)		(8,819,178)
Property and equipment, net	2,109,561		2,086,269
Other assets:
Equity investments	27,044		24,816
Long-term derivative instruments	652		322


Operating lease assets	314		342

Other assets	16,545		18,372
Total other assets	44,555		43,852
Total assets	$	2,627,648	$	2,539,871
Liabilities and Stockholders’ Deficit
Current liabilities:
Accounts payable and accrued liabilities	$	310,172	$	244,903

Short-term derivative instruments	20,687		11,641


Current maturities of long-term debt	279,807		253,743
Total current liabilities	610,666		510,287
Non-current liabilities:
Long-term derivative instruments	43,267		36,604






Total non-current liabilities	43,267		36,604
Liabilities subject to compromise	2,261,453		2,293,480
Total liabilities	$	2,915,386	$	2,840,371
Commitments and contingencies (Note 8)
Preferred stock - $0.01 par value; 5.0 million shares authorized (30 thousand authorized as redeemable 12% cumulative preferred stock, Series A), and none issued and outstanding	—		—
Stockholders’ deficit:
Common stock - $0.01 par value, 200.0 million shares authorized, 160.9 million issued and outstanding at March 31, 2021 and 160.8 million at December 31, 2020	1,609		1,607
Paid-in capital	4,215,162		4,213,752
Accumulated other comprehensive loss	(40,430)		(43,000)
Accumulated deficit	(4,464,079)		(4,472,859)
Total stockholders’ deficit	$	(287,738)	$	(300,500)
Total liabilities and stockholders’ deficit	$	2,627,648	$	2,539,871

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS

(DEBTOR-IN-POSSESSION)

(Unaudited)


	Three months ended March 31,
	2021		2020
	(In thousands)
REVENUES:
Natural gas sales	$	235,321	$	161,008
Oil and condensate sales	18,239		23,151
Natural gas liquid sales	23,776		16,913
Net (loss) gain on natural gas, oil and NGL derivatives	(29,978)		98,266
Total Revenues	247,358		299,338
OPERATING EXPENSES:
Lease operating expenses	12,653		14,695
Taxes other than income	8,704		6,637
Transportation, gathering, processing and compression	105,867		110,357
Depreciation, depletion and amortization	41,147		78,028
Impairment of oil and natural gas properties	—		553,345
Impairment of other property and equipment	14,568		—
General and administrative expenses	12,757		15,622

Accretion expense	805		741

Total Operating Expenses	196,501		779,425
INCOME (LOSS) FROM OPERATIONS	50,857		(480,087)
OTHER EXPENSE (INCOME):
Interest expense	3,261		32,990
Interest income	(143)		(152)
Gain on debt extinguishment	—		(15,322)

Loss from equity method investments, net	342		10,789
Reorganization items, net	38,721		—
Other expense	(104)		1,856
Total Other Expense	42,077		30,161
INCOME (LOSS) BEFORE INCOME TAXES	8,780		(510,248)
Income Tax Expense	—		7,290
NET INCOME (LOSS)	$	8,780	$	(517,538)
NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	0.05	$	(3.24)
Diluted	$	0.05	$	(3.24)
Weighted average common shares outstanding—Basic	160,813		159,760
Weighted average common shares outstanding—Diluted	160,813		159,760

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(DEBTOR-IN-POSSESSION)

(Unaudited)


	Three months ended March 31,
	2021		2020
	(In thousands)
Net income (loss)	$	8,780	$	(517,538)
Foreign currency translation adjustment	2,570		(15,030)

Other comprehensive income (loss)	2,570		(15,030)
Comprehensive income (loss)	$	11,350	$	(532,568)

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ (DEFICIT) EQUITY

(DEBTOR-IN-POSSESSION)

(Unaudited)


				Paid-in Capital		Accumulated Other Comprehensive (Loss) Income		Accumulated Deficit		Total Stockholders’ Deficit
	Common Stock
	Shares	Amount
	(In thousands)












Balance at January 1, 2021	160,762	$	1,607	$	4,213,752	$	(43,000)	$	(4,472,859)	$	(300,500)
Net Income	—	—		—		—		8,780		8,780
Other Comprehensive Income	—	—		—		2,570		—		2,570
Stock Compensation	—	—		1,419		—		—		1,419
Shares Repurchased	(86)	(1)		(7)		—		—		(8)
Issuance of Restricted Stock	203	3		(2)		—		—		1
Balance at March 31, 2021	160,878	$	1,609	$	4,215,162	$	(40,430)	$	(4,464,079)	$	(287,738)


				Paid-in Capital		Accumulated Other Comprehensive Loss		Accumulated Deficit		Total Stockholders’ Equity
	Common Stock
	Shares	Amount
	(In thousands)
Balance at January 1, 2020	159,711	$	1,597	$	4,207,554	$	(46,833)	$	(2,847,726)	$	1,314,592
Net Loss	—	—		—		—		(517,538)		(517,538)
Other Comprehensive Income	—	—		—		(15,030)		—		(15,030)
Stock Compensation	—	—		2,104		—		—		2,104
Shares Repurchased	(80)	(1)		(78)		—		—		(79)
Issuance of Restricted Stock	211	2		(2)		—		—		—
Balance at March 31, 2020	159,842	$	1,598	$	4,209,578	$	(61,863)	$	(3,365,264)	$	784,049

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(DEBTOR-IN-POSSESSION)

(Unaudited)


	Three months ended March 31,
	2021		2020
	(In thousands)
Cash flows from operating activities:
Net income (loss)	$	8,780	$	(517,538)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation and amortization	41,147		78,028
Impairment of oil and natural gas properties	—		553,345
Impairment of other property and equipment	14,568		—
Loss from equity investments	342		10,789
Gain on debt extinguishment	—		(15,322)
Net loss (gain) on derivative instruments	29,978		(98,266)
Net cash receipts on settled derivative instruments	125		70,733

Deferred income tax expense	—		7,290
Other, net	1,574		3,223
Changes in operating assets and liabilities, net	26,661		38,556
Net cash provided by operating activities	123,175		130,838
Cash flows from investing activities:
Additions to oil and natural gas properties	(56,895)		(113,744)
Proceeds from sale of oil and natural gas properties	15		44,383
Other, net	(296)		(448)
Net cash used in investing activities	(57,176)		(69,809)
Cash flows from financing activities:
Principal payments on pre-petition revolving credit facility	(2,202)		(180,000)
Borrowings on pre-petition revolving credit facility	26,050		125,000


Repurchase of senior notes	—		(10,204)

Other, net	(7)		(252)
Net cash provided by (used in) financing activities	23,841		(65,456)
Net increase (decrease) in cash, cash equivalents and restricted cash	89,840		(4,427)
Cash, cash equivalents and restricted cash at beginning of period	89,861		6,060
Cash, cash equivalents and restricted cash at end of period	$	179,701	$	1,633

See accompanying notes to consolidated financial statements.

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GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(DEBTOR-IN-POSSESSION)

(Unaudited)

1.BASIS OF PRESENTATION AND LIQUIDITY, MANAGEMENT'S PLANS AND GOING CONCERN

Basis of Presentation

The accompanying unaudited consolidated financial statements have been prepared by Gulfport Energy Corporation (the “Company” or “Gulfport”) pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), and reflect all adjustments that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods reported in all material respects, 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 ("GAAP") 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.

The consolidated financial statements should be read in conjunction with the consolidated financial statements and the summary of significant accounting policies and notes included in the Company’s most recent annual report on Form 10-K. Results for the three months ended March 31, 2021 are not necessarily indicative of the results expected for the full year.

Voluntary Reorganization Under Chapter 11 of the Bankruptcy Code

On November 13, 2020, Gulfport Energy Corporation, Gator Marine, Inc., Gator Marine Ivanhoe, Inc., Grizzly Holdings, Inc., Gulfport Appalachia, LLC, Gulfport Midcon, LLC, Gulfport Midstream Holdings, LLC, Jaguar Resources LLC, Mule Sky LLC, Puma Resources, Inc. and Westhawk Minerals LLC filed voluntary petitions of relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the Southern District of Texas. The Chapter 11 Cases are being administered jointly under the caption In re Gulfport Energy Corporation, et al., Case No. 20-35562 (DRJ). The debtors continue to operate their businesses as "debtors-in-possession" under the jurisdiction of the Bankruptcy Court, in accordance with the applicable provisions of the Bankruptcy Code and the orders of the Bankruptcy Court.

The commencement of a voluntary proceeding in bankruptcy constituted an event of default that accelerated the Company's obligations under the Company's Pre-Petition Revolving Credit Facility and the indentures governing the Company's senior notes, resulting in the principal and interest due thereunder becoming immediately due and payable. Subject to certain specific exceptions under the Bankruptcy Code, the filing of the Chapter 11 Cases automatically stayed all judicial or administrative actions against the Company and efforts by creditors to collect on or otherwise exercise rights or remedies with respect to pre-petition claims. Absent an order from the Bankruptcy Court, substantially all of the Debtors’ pre-petition liabilities are subject to settlement under the Bankruptcy Code.

The Company has applied FASB ASC Topic 852 - Reorganizations ("ASC 852") in preparing the consolidated financial statements, which specifies the accounting and financial reporting requirements for entities reorganizing through Chapter 11 bankruptcy proceedings. These requirements include distinguishing transactions associated with the reorganization separate from activities related to the ongoing operations of the business. Accordingly, pre-petition liabilities that may be impacted by the Chapter 11 proceedings have been classified as liabilities subject to compromise on the consolidated balance sheets as of March 31, 2021 and December 31, 2020. Additionally, certain expenses, realized gains and losses and provisions for losses that are realized or incurred during the Chapter 11 Cases are recorded as reorganization items, net in the consolidated statements of operations for the three months ended March 31, 2021. Refer to Note 2 for more information on the events of the bankruptcy proceedings as well as the accounting and reporting impacts of the reorganization.

Ability to Continue as a Going Concern

The accompanying unaudited consolidated financial statements are prepared in accordance with generally accepted accounting principles applicable to a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business.

As discussed above, the filing of the Chapter 11 Cases constituted an event of default under the Company’s Pre-Petition Revolving Credit Facility and the indentures governing the Company's senior notes (the "Default"), resulting in the principal

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and interest due thereunder becoming immediately due and payable. The Company does not have sufficient cash on hand or available liquidity to repay these amounts due. These conditions and events raise substantial doubt about the Company’s ability to continue as a going concern.

As part of the Chapter 11 Cases, the Company submitted the Plan to the Bankruptcy Court. The Company’s operations and its ability to develop and execute its business plan are subject to a high degree of risk and uncertainty associated with the Chapter 11 Cases. As discussed in Note 14, an order was entered by the Bankruptcy Court confirming the Company's Plan on April 28, 2021 and it expects to emerge from bankruptcy in May 2021. However, there can be no assurance that the Company will consummate the confirmed Plan, and as a result, the Company has concluded that management’s plans do not alleviate substantial doubt about the Company’s ability to continue as a going concern.

While operating as a debtor-in-possession, the Company may settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business, for amounts other than those reflected in the accompanying consolidated financial statements. Further, the Plan or other bankruptcy proceedings could materially change the amounts and classifications of assets and liabilities reported in the consolidated financial statements, including liabilities subject to compromise which will be resolved in connection with the Chapter 11 Cases. The accompanying unaudited consolidated financial statements do not include any adjustments related to the recoverability and classification of assets or the amounts and classification of liabilities or any other adjustments that might be necessary should the Company be unable to continue as a going concern or as a consequence of the Chapter 11 Cases.

Impact on Previously Reported Results

During the third quarter of 2020, the Company identified that certain firm transportation costs incurred in prior periods were misclassified as deducts to "natural gas sales" while they should have been included in "transportation, gathering, processing and compression" on its consolidated statements of operations. The Company assessed the materiality of this presentation on prior periods’ consolidated financial statements in accordance with the SEC Staff Accounting Bulletin No. 99, “Materiality”, codified in ASC Topic 250, “Accounting Changes and Error Corrections”. Based on this assessment, the Company concluded that the correction is not material to any previously issued financial statements. The correction had no impact on its consolidated balance sheets, consolidated statements of comprehensive income, consolidated statements of stockholders' equity or consolidated statements of cash flows. Additionally, the error had no impact on net loss or net loss per share. The Company will conform presentation of previously reported consolidated statements of operations in future filings. The following tables present the effect of the correction on all affected line items of our previously issued consolidated financial statements of operations for the three months ended March 31, 2020.


	Three months ended March 31, 2020
	As Reported		Adjustments		As Revised
	(In thousands)
Natural gas sales	$	108,547	$	52,461	$	161,008
Total Revenues	$	246,877	$	52,461	$	299,338
Transportation, gathering, processing and compression	$	57,896	$	52,461	$	110,357
Total Operating Expenses	$	726,964	$	52,461	$	779,425

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Supplemental Cash Flow and Non-Cash Information


	Three months ended March 31,
	2021		2020
Supplemental disclosure of cash flow information:	(In thousands)
Cash paid for reorganization items, net	$	21,367	$	—
Interest payments	$	4,763	$	14,034
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable - oil and natural gas sales	$	(14,117)	$	47,111
(Increase) decrease in accounts receivable - joint interest and other	(478)		6,001
Increase (decrease) in accounts payable and accrued liabilities	15,555		(7,637)
(Increase) decrease in prepaid expenses	26,356		(6,920)
(Increase) decrease in other assets	(655)		1
Total changes in operating assets and liabilities	$	26,661	$	38,556
Supplemental disclosure of non-cash transactions:
Capitalized stock-based compensation	$	630	$	934
Asset retirement obligation capitalized	$	483	$	381
Asset retirement obligation removed due to divestiture	$	—	$	(2,033)
Interest capitalized	$	—	$	187
Fair value of contingent consideration asset on date of divestiture	$	—	$	23,090
Foreign currency translation gain (loss) on equity method investments	$	2,570	$	(15,030)

2.CHAPTER 11 PROCEEDINGS

Restructuring Support Agreement

On November 13, 2020, the Debtors commenced the Chapter 11 Cases as described in Note 1 above. To ensure ordinary course operations, the Debtors have obtained approval from the Bankruptcy Court for certain first- and second-day motions, including motions to obtain customary relief intended to continue ordinary course operations after the Petition Date. In addition, the Debtors have received authority to use cash collateral of the lenders under the DIP Credit Facility.

On November 13, 2020, the Debtors entered into a restructuring support agreement with (i) over 95% of the lenders (the “Consenting RBL Lenders”) party to the Pre-Petition Revolving Credit Facility, dated as of December 27, 2013, by and among the Company, as borrower, each of the lenders party thereto, the Bank of Nova Scotia, as administrative agent and issuing bank, the joint lead arrangers and joint bookrunners, the co-syndication agents, and the co-documentation agents and (ii) certain holders (the “Consenting Noteholders,” and, together with the Consenting RBL Lenders, the “Consenting Stakeholders”) holding over two-thirds of the Company’s (a) 6.625% senior notes due 2023, issued under that certain Indenture, dated as of April 21, 2015, (b) 6.000% senior notes due 2024, issued under that certain Indenture, dated as of October 14, 2016, (c) 6.375% senior notes due 2025, issued under that certain Indenture, dated as of December 21, 2016, and (d) 6.375% senior notes due 2026, issued under that certain Indenture, dated as of October 11, 2017 (collectively, the “Unsecured Notes”), each by and among the Company, the subsidiary guarantors party thereto, and UMB Bank, N.A. as successor trustee.

The RSA outlines the key elements and actions the Company plans to take as part of Chapter 11 process, including equitizing a significant portion of its prepetition indebtedness and rejecting or renegotiating certain contracts which will result in a materially improved balance sheet and cost structure. The RSA contains certain covenants on the part of each of Gulfport and the Consenting Stakeholders, including commitments by the Consenting Stakeholders to vote in favor of the Plan and commitments of Gulfport and the Consenting Stakeholders to negotiate in good faith to finalize the documents and agreements governing the Restructuring. The RSA also places certain conditions on the obligations of the parties and provides that the RSA may be terminated upon the occurrence of certain events, including, without limitation, the failure to achieve certain milestones and certain breaches by the parties under the RSA. One such condition is the requirement of the Company to obtain certain levels of savings on certain midstream obligations (as set forth in the RSA) through rejection of such contracts and/or renegotiation of their terms.

Plan of Reorganization

On April 28, 2021, the Bankruptcy Court entered an order confirming the Amended Joint Chapter 11 Plan of Reorganization of Gulfport Energy Corporation and Its Debtor Subsidiaries (the "Plan"). The Company expects the effective

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date of the Plan will occur once all conditions precedent to the Plan have been satisfied (the "Effective Date"). Below is a summary of the material terms of the Plan as approved and confirmed by the Bankruptcy Court. This summary highlights only certain substantive provisions of the Plan and is not intended to be a complete description of the Plan. Capitalized terms used under this heading but not otherwise defined herein shall have the meaning given to such terms in the Plan, which has been included as an exhibit to this Form 10-Q:

•the RBL Lenders and DIP Lenders, each with The Bank of Nova Scotia as administrative agent, have agreed that the RBL Credit Facility and DIP Facility, respectively, will convert into the $580 million Exit Facility upon the Effective Date, subject to the terms and conditions set forth in the Exit Facility Documentation;

•certain members of the Ad Hoc Noteholder Group have agreed to backstop the Rights Offering of at least $50 million in exchange for New Preferred Stock;

•Holders of Allowed General Unsecured Claims against Gulfport Parent will receive their Pro Rata share of: (a) $10 million in Cash, subject to adjustment by the Unsecured Claims Distribution Trustee; (b) 100% of the Mammoth Shares; and (c) 4% of the New Common Stock of the Reorganized Debtors, subject to dilution and certain adjustments;

•Holders of Allowed Notes Claims against Gulfport Parent will waive their entitlement to a Cash recovery or any of the Mammoth Shares, and will cap their recovery at 96% of the New Common Stock of the Reorganized Debtors, which will be drawn first from the Gulfport Subsidiaries Equity Pool and then from the Gulfport Parent Equity Pool to the extent required due to dilution as a result of distributions made to General Unsecured Claims against Gulfport Subsidiaries (excluding distributions to Unsecured Surety Claims);

•Holders of Allowed Notes Claims against Gulfport Subsidiaries and Allowed General Unsecured Claims against Gulfport Subsidiaries will receive their Pro Rata share of: (a) the Gulfport Subsidiaries Equity Pool; (b) the New Unsecured Notes; and (c) the Rights Offering Subscription Rights;

•a Class of Convenience Claims consisting of (a) Allowed General Unsecured Claims of $300,000 or less or (b) Allowed General Unsecured Claims over $300,000 that the applicable Holder has irrevocably elected to have reduced to $300,000 and treated as Convenience Claims, will share in a $3,000,000 Cash distribution pool, which the Unsecured Claims Distribution Trustee may increase by an additional $2,000,000 by reducing the Gulfport Parent Cash Pool;

•an Unsecured Claims Distribution Trustee will administer a trust to make distributions to Allowed General Unsecured Claims and Allowed Convenience Claims and to exercise certain consent rights with respect to the settlement and Allowance of disputed General Unsecured Claims and Convenience Claims;

•each Intercompany Claim shall be cancelled in exchange for the distributions contemplated by the Plan to Holders of Claims against and Interests in the respective Debtor entities and shall be considered settled pursuant to Bankruptcy Rule 9019;

•each Holder of an Intercompany Interest shall receive no recovery or distribution and shall be Reinstated solely to the extent necessary to maintain the Debtors’ prepetition corporate structure for the ultimate benefit of the Holders of New Common Stock and New Preferred Stock; and

•the Existing Interests in Gulfport Parent will be cancelled, released, and extinguished, and will be of no further force or effect, without any distribution.

DIP Credit Facility

Pursuant to the RSA, the Consenting RBL Lenders have agreed to provide the Company with a senior secured superpriority debtor-in-possession revolving credit facility in an aggregate principal amount of $262.5 million consisting of (a) $105 million of new money and (b) $157.5 million to roll up a portion of the existing outstanding obligations under the Pre-Petition Revolving Credit Facility. The proceeds of the DIP Credit Facility may be used for, among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases and payment of court approved adequate protection obligations. The DIP Credit Facility was approved by the Bankruptcy Court on a final basis on December 18, 2020. See Note 5 for additional information.

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Executory Contracts

Subject to certain exceptions, under the Bankruptcy Code, the Company may assume, assign, or reject certain executory contracts and unexpired leases subject to the approval of the Bankruptcy Court and certain other conditions. Generally, the rejection of an executory contract or unexpired lease is treated as a pre-petition breach of such executory contract or unexpired lease and, subject to certain exceptions, relieves the Company from performing its future obligations under such executory contract or unexpired lease but entitles the contract counterparty or lessor to a pre-petition general unsecured claim for damages caused by such deemed breach. Counterparties to rejected contracts or leases may assert unsecured claims in the Bankruptcy Court against the Company's estate for such damages. Generally, the assumption of an executory contract or unexpired lease requires the Company to cure existing monetary defaults under such executory contract or unexpired lease and provide adequate assurance of future performance. Accordingly, any description of an executory contract or unexpired lease with the Company, including where applicable a quantification of the Company's obligations under any such executory contract or unexpired lease of the Company, is qualified by any overriding rejection rights it has under the Bankruptcy Code.

Potential Claims

The Company has filed with the Bankruptcy Court schedules and statements setting forth, among other things, the assets and liabilities of the Company and each of its subsidiaries, subject to the assumptions filed in connection therewith. These schedules and statements may be subject to further amendment or modification after filing. Certain holders of pre-petition claims that are not governmental units were required to file proofs of claim by the deadline for general claims, which was set by the Bankruptcy Court as January 26, 2021. Governmental units are required to file proof of claims by May 12, 2021, the deadline that was set by the Bankruptcy Court.

As of April 30, 2021, the Debtors have received approximately 2,700 proofs of claim for an aggregate amount of approximately $13 billion. The Company will continue to evaluate these claims throughout the Chapter 11 process and recognize or adjust amounts in future financial statements as necessary using the best information available at such time. Differences between amounts scheduled by the Company and claims by creditors will ultimately be reconciled and resolved in connection with the claims resolution process. In light of the expected number of creditors, the claims resolution process may take considerable time to complete and likely will continue after the Company emerges from bankruptcy.

Financial Statement Classification of Liabilities Subject to Compromise

The accompanying consolidated balance sheets as of March 31, 2021 and December 31, 2020 include amounts classified as liabilities subject to compromise, which represent liabilities the Company anticipates will be allowed as claims in the Chapter 11 Cases. These amounts represent the Company's current estimate of known or potential obligations to be resolved in connection with the Chapter 11 Cases, and may differ from actual future settlement amounts paid. Differences between liabilities estimated and claims filed, or to be filed, will be investigated and resolved in connection with the claims resolution process. The Company will continue to evaluate these liabilities throughout the Chapter 11 process and adjust amounts as necessary. Such adjustments may be material.

Liabilities subject to compromise includes amounts related to the rejection of various executory contracts. Additional amounts may be included in liabilities subject to compromise in future periods if additional executory contracts and/or unexpired leases are rejected. The nature of many of the potential claims arising under the Company's executory contracts and unexpired leases has not been determined at this time, and therefore, such claims are not reasonably estimable at this time and may be material. Damages related to rejected contracts are accounted for after they have been approved for rejection by the Bankruptcy Court.

The following table summarizes the components of liabilities subject to compromise included on the Company's consolidated balance sheets as of March 31, 2021 and December 31, 2020:

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	March 31, 2021		December 31, 2020
	(in thousands)
Debt subject to compromise	$	2,003,004	$	2,005,219
Accounts payable and accrued liabilities	134,344		164,939
Asset retirement obligations	64,854		63,566
Accrued interest on debt subject to compromise	55,159		55,634
Other liabilities	4,092		4,122
Liabilities subject to compromise	$	2,261,453	$	2,293,480

Interest Expense

The Company has discontinued recording interest on debt instruments classified as liabilities subject to compromise as of the Petition Date. The contractual interest expense on liabilities subject to compromise not accrued in the consolidated statements of operations was approximately $28.5 million for the three months ended March 31, 2021.

Reorganization Items, Net

The Company has incurred and will continue to incur significant expenses, gains and losses associated with the reorganization, primarily the write-off of unamortized debt issuance costs, debt and equity financing fees, adjustments to allowed claims and legal and professional fees incurred subsequent to the Chapter 11 filings related to the restructuring process. The amount of these items, which are being incurred in reorganization items, net within the Company's accompanying audited consolidated statements of operations, are expected to significantly affect the Company's statements of operations. The Company has incurred adjustments for allowable claims related to its legal proceedings and executory contracts approved for rejections by the Bankruptcy Court, with additional adjustments possible in future periods.

The following table summarizes the components in reorganization items, net included in the Company's consolidated statements of operations for the three months ended March 31, 2021:


	Three months ended March 31, 2021
	(in thousands)
Legal and professional fees	$	40,783
Adjustment to allowed claims	2,088


Gain on settlement of pre-petition accounts payable	(4,150)
Reorganization items, net	$	38,721

3.PROPERTY AND EQUIPMENT

The major categories of property and equipment and related accumulated DD&A and impairment as of March 31, 2021 and December 31, 2020 are as follows:


	March 31, 2021		December 31, 2020
	(In thousands)
Oil and natural gas properties	$	10,895,625	$	10,816,909
Other depreciable property and equipment	85,827		85,530
Land	3,008		3,008
Total property and equipment	10,984,460		10,905,447
Accumulated DD&A and impairment	(8,874,899)		(8,819,178)
Property and equipment, net	$	2,109,561	$	2,086,269

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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 Company's oil and natural gas properties. At March 31, 2021, the net book value of the Company's oil and gas properties was below the calculated ceiling for the period leading up to March 31, 2021. As a result, the Company recorded no impairment of its oil and natural gas properties for the three months ended March 31, 2021. The Company recorded an impairment of its oil and natural gas properties of $553.3 million for the three months ended March 31, 2020.

Certain general and administrative costs are capitalized to the full cost pool and represent management’s estimate of costs incurred directly related to exploration and development activities. All general and administrative costs not capitalized are charged to expense as they are incurred. Capitalized general and administrative costs were approximately $5.5 million and $5.4 million for the three months ended March 31, 2021 and 2020, respectively.

The following table summarizes the Company’s unevaluated properties excluded from amortization by area at March 31, 2021:


	March 31, 2021
	(In thousands)
Utica	$	761,397
SCOOP	651,451
Other	926
	$	1,413,774

At December 31, 2020, approximately $1.5 billion of unevaluated properties were not subject to amortization.

The Company evaluates the costs excluded from its amortization calculation at least annually. Individually insignificant unevaluated properties are grouped for evaluation and periodically transferred to evaluated properties over a timeframe consistent with their expected development schedule.

Impairment of Other Property and Equipment

During the three months ended March 31, 2021, the Company recorded an impairment of $14.6 million related to its corporate headquarters as a result of changes in the expected future use.

Asset Retirement Obligation

A reconciliation of the Company’s asset retirement obligation for the three months ended March 31, 2021 and 2020 is as follows:


	March 31, 2021		March 31, 2020
	(In thousands)
Asset retirement obligation, beginning of period	$	63,566	$	60,355
Liabilities incurred	483		381

Liabilities removed due to divestitures	—		(2,033)
Accretion expense	805		741

Total asset retirement obligation as of end of period	$	64,854	$	59,444
Less: amounts reclassified to liabilities subject to compromise	$	(64,854)	$	—
Total asset retirement obligation reflected as non-current liabilities	$	—	$	59,444

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4.EQUITY INVESTMENTS

Investments accounted for by the equity method consist of the following as of March 31, 2021 and December 31, 2020:


			Carrying value				Loss from equity method investments
	Approximate ownership %		March 31, 2021		December 31, 2020		Three months ended March 31,
							2021		2020
			(In thousands)
Investment in Grizzly Oil Sands ULC	24.5	%	$	27,044	$	24,816	$	(342)	$	(143)
Investment in Mammoth Energy Services, Inc.	21.5	%	—		—		—		(10,646)

			$	27,044	$	24,816	$	(342)	$	(10,789)

The tables below summarize financial information for the Company’s equity investments as of March 31, 2021 and December 31, 2020.

Summarized balance sheet information:


	March 31, 2021		December 31, 2020

	(In thousands)
Current assets	$	462,478	$	483,303
Noncurrent assets	$	1,079,557	$	1,092,495
Current liabilities	$	125,359	$	132,978
Noncurrent liabilities	$	124,628	$	148,240

Summarized results of operations:


	Three months ended March 31,
	2021		2020
	(In thousands)
Gross revenue	$	66,805	$	97,383
Net loss	$	(13,606)	$	(85,031)

Grizzly Oil Sands ULC

The Company, through its wholly owned subsidiary Grizzly Holdings, owns an approximate 24.5% interest in Grizzly, a Canadian unlimited liability company. As of March 31, 2021, Grizzly had approximately 830,000 acres under lease in the Athabasca, Peace River and Cold Lake oil sands regions of Alberta, Canada. The Company reviewed its investment in Grizzly for impairment at March 31, 2021 and 2020 and determined no impairment was required. The Company has not paid any cash calls since its election to cease funding further capital calls in 2019. Grizzly’s functional currency is the Canadian dollar. The Company’s investment in Grizzly increased by $2.6 million as a result of a foreign currency translation gain and decreased by $14.7 million as a result of a foreign currency translation loss for the three months ended March 31, 2021 and 2020, respectively.

Mammoth Energy Services, Inc.

At March 31, 2021, the Company owned 9,829,548 shares, or approximately 21.5%, of the outstanding common stock of Mammoth Energy Services, Inc. ("Mammoth Energy"). The approximate fair value of the Company's investment in Mammoth Energy at March 31, 2021 was $52.3 million based on the quoted market price of Mammoth Energy's common stock.

At March 31, 2020, the Company's share of net loss of Mammoth was in excess of the carrying value of its investment. As such, the Company's investment value was reduced to zero at March 31, 2020. During the first quarter of 2021, the Company's

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share of net loss of Mammoth continued to be in excess of the carrying value of its investment and, therefore, the Company's investment value remained at zero at March 31, 2021.

The Company received no distributions from Mammoth Energy during the three months ended March 31, 2021 and 2020, respectively. The loss from equity method investments presented in the table above reflects any intercompany profit eliminations.

5.LONG-TERM DEBT

Long-term debt consisted of the following items as of March 31, 2021 and December 31, 2020:


	March 31, 2021		December 31, 2020
	(In thousands)
DIP credit facility	$	157,500	$	157,500
Pre-petition revolving credit facility	316,759		292,910
6.625% senior unsecured notes due 2023	324,583		324,583
6.000% senior unsecured notes due 2024	579,568		579,568
6.375% senior unsecured notes due 2025	507,870		507,870
6.375% senior unsecured notes due 2026	374,617		374,617
Building loan	21,914		21,914
Total Debt	2,282,811		2,258,962
Less: current maturities of long-term debt	(279,807)		(253,743)
Less: amounts reclassified to liabilities subject to compromise	(2,003,004)		(2,005,219)
Total Debt reflected as long term	$	—	$	—

Chapter 11 Proceedings

Filing of the Chapter 11 Cases constituted an event of default with respect to certain of our secured and unsecured debt obligations. As a result of the Chapter 11 Cases, the principal and interest due under these debt instruments became immediately due and payable. However, Section 362 of the Bankruptcy Code stays the creditors from taking any action as a result of the default.

The principal amounts from the Senior Notes, Building Loan and Pre-Petition Revolving Credit Facility, other than letters of credit drawn on the Pre-Petition Revolving Credit Facility after the Petition Date, have been classified as liabilities subject to compromise on the accompanying consolidated balance sheets as of March 31, 2021 and December 31, 2020.

Debtor-in-Possession Credit Agreement

Pursuant to the RSA, the Consenting RBL Lenders have agreed to provide the Company with a senior secured superpriority debtor-in-possession revolving credit facility in an aggregate principal amount of $262.5 million consisting of (a) $105 million of new money and (b) $157.5 million to roll up a portion of the existing outstanding obligations under the Pre-Petition Revolving Credit Facility. The terms and conditions of the DIP Credit Facility are set forth in that certain form of credit agreement governing the DIP Credit Facility. The proceeds of the DIP Credit Facility may be used for, among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases and payment of court approved adequate protection obligations. The DIP Credit Facility was approved by the Bankruptcy Court on a final basis on December 18, 2020. As of March 31, 2021, $157.5 million was outstanding under the DIP Credit Facility and the total availability for future borrowings under this facility, after giving effect to an aggregate of $28.5 million letters of credit, was $76.5 million.

Borrowings under the DIP Credit Facility will mature, and the lending commitments thereunder will terminate, upon the earliest to occur of: (a) August 30, 2021; (b) three (3) business days after the Petition Date, if the Interim Order and Hedging Order have not been entered prior to the expiration of such period; (c) thirty five (35) days (or a later date consented to by the Administrative Agent and the Majority Lenders in their sole discretion) after the entry of the Interim Order, if the Bankruptcy Court has not entered the Final Order on or prior to such date; (d) the effective date of an Approved Plan of Reorganization, (e)

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the consummation of a sale of all or substantially all of the equity and/or assets of the Debtors and budgeted and necessary expenses of the estates; (f) the date of the payment in full, in cash, of all Obligations (and the termination of all Commitments in accordance with the terms hereof); and (g) the date of termination of all Commitments and/or the acceleration of all of the Obligations under the Agreement and the other Loan Documents following the occurrence and during the continuance of an Event of Default.

Borrowings under the DIP Credit Facility bear interest at a eurodollar rate or base rate, at our election, plus an applicable margin of 4.50% per annum for eurodollar loans and 3.50% per annum for base rate loans. At March 31, 2021, amounts borrowed under the DIP credit facility bore interest at a weighted average rate of 5.50%. In addition to paying interest on outstanding principal and letters of credit posted under the DIP Credit Facility, we are required to pay a commitment fee of 0.50% per annum to the lenders of the DIP Credit Facility in respect of the unutilized DIP commitments thereunder and a letter of credit fee equal to 0.20% per annum.

The DIP Credit Facility includes negative covenants that, subject to significant exceptions, limit the Company's ability and the ability of its restricted subsidiaries to, among other things, (i) create liens on assets, property revenues, (ii) make investments, (iii) incur additional indebtedness, (iv) engage in mergers, consolidations, liquidations and dissolutions, (v) sell assets, (vi) pay dividends and distributions or repurchase capital stock, (vii) cease for any reason to be the operator of its properties, (viii) enter into letters of credit without prior written consent, (ix) enter into certain commodity hedging contracts except commodity hedging contracts with terms approved by the Bankruptcy Court in the hedging order or certain interest rate contracts, (x) change lines of business, (xi) engage in certain transactions with affiliates and (xii) incur more than a certain amount in capital expenditures in any calendar month. The DIP Credit Facility includes certain customary representations and warranties, affirmative covenants and events of default, including but not limited to defaults on account of nonpayment, breaches of representations and warranties and covenants, certain bankruptcy-related events, certain events under ERISA, material judgments and a change in control. If an event of default occurs, the lenders under the DIP Credit Facility will be entitled to take various actions, including the acceleration of all amounts due under the DIP Credit Facility and all actions permitted to be taken under the loan documents or application of law. In addition, the DIP Credit Facility is subject to various other financial performance covenants, including compliance with certain financial metrics and adherence to a budget approved by the Company's DIP Credit Facility lenders.

Pre-Petition Revolving Credit Facility

The Company has entered into a senior secured revolving credit facility agreement, as amended, with The Bank of Nova Scotia, as the lead arranger and administrative agent and certain lenders from time to time party thereto. On October 8, 2020, the Company's borrowing base under its Pre-Petition Revolving Credit Facility was reduced from $700 million to $580 million, thereby significantly reducing the Company's available liquidity. On October 15, 2020, the Company elected to not pay interest on certain Senior Notes outstanding triggering a default under the credit agreement. There was $316.8 million of outstanding borrowings under the Pre-Petition Revolving Credit Facility as of March 31, 2021 that were not rolled up into the DIP Credit Facility. This amount of indebtedness will remain outstanding throughout the Chapter 11 Cases and will continue to accrue interest at the default interest rate on amounts drawn after the Petition Date. The Company made certain adequate protection payments of $2.2 million on its Pre-Petition Revolving Credit Facility during the three months ended March 31, 2021 which reduced the amount of outstanding borrowings under the Pre-Petition Revolving Credit Facility classified as liabilities subject to compromise as of March 31, 2021 in the accompanying consolidated balance sheets.

During the first quarter of 2021, $26.1 million was drawn on letters of credit secured by the Company's Pre-Petition Revolving Credit Facility by certain of its firm transportation contract counterparties. As these were post-petition activities, these letters of credit drawn are included in current portion of long-term debt in the accompanying consolidated balance sheets. At March 31, 2021 the Company included $99.1 million in prepaid and other current assets in the accompanying consolidated balance sheets as an offset for the drawn letters of credit. A portion of the drawn letters of credit were netted against accounts payable to the Company's firm transportation contract counterparties.

Additionally, as of March 31, 2021, the Company had an aggregate of $121.2 million of letters of credit outstanding and no availability for future borrowings under its Pre-Petition Revolving Credit Facility. This facility is secured by substantially all of the Company's assets. All of the Company's wholly-owned subsidiaries, excluding Grizzly Holdings and Mule Sky, guarantee our obligations under our revolving credit facility.

At March 31, 2021, amounts borrowed under the revolving credit facility bore interest at a weighted average rate of 3.12%.

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Capitalization of Interest

The Company did not capitalize interest expense for the three months ended March 31, 2021 and capitalized approximately $0.2 million in interest expense related to its unevaluated oil and natural gas properties during the three months ended March 31, 2020.

Fair Value of Debt

At March 31, 2021, the carrying value of the outstanding debt represented by the Notes was approximately $1.8 billion. Based on the quoted market prices (Level 1), the fair value of the Notes was determined to be approximately $1.6 billion at March 31, 2021.

6.STOCK-BASED COMPENSATION

The Company has granted restricted stock units to employees and directors pursuant to the 2019 Amended and Restated Incentive Stock Plan ("2019 Plan"), as discussed below. During the three months ended March 31, 2021, the Company’s stock-based compensation cost was $3.0 million, of which the Company capitalized $0.6 million relating to its exploration and development efforts. During the three months ended March 31, 2020, the Company’s stock-based compensation cost was $2.1 million of which the Company capitalized $0.9 million relating to its exploration and development efforts. Stock compensation costs, net of the amounts capitalized, are included in general and administrative expenses in the accompanying consolidated statements of operations.

The following table summarizes restricted stock unit activity for the three months ended March 31, 2021:


	Number of Unvested Restricted Stock Units	Weighted Average Grant Date Fair Value		Number of Unvested Performance Vesting Restricted Stock Units	Weighted Average Grant Date Fair Value
Unvested shares as of January 1, 2021	1,702,513	$	4.74	840,595	$	4.07
Granted	—	—		—	—
Vested	(202,583)	8.32		—	—
Forfeited/canceled	(19,707)	3.61		—	—
Unvested shares as of March 31, 2021	1,480,223	$	4.26	840,595	$	4.07

Restricted Stock Units

Restricted stock units awarded under the 2019 Plan generally vest over a period of one year in the case of directors and three years in the case of employees and vesting is dependent upon the recipient meeting applicable service requirements. Stock-based compensation costs are recorded ratably over the service period. The grant date fair value of restricted stock units represents the closing market price of the Company's common stock on the date of grant. Unrecognized compensation expense as of March 31, 2021 related to restricted stock units was $4.0 million. The expense is expected to be recognized over a weighted average period of 1.12 years.

Performance Vesting Restricted Stock Units

The Company has awarded performance vesting units to certain of its executive officers under the 2019 Plan. The number of shares of common stock issued pursuant to the award will be based on relative total shareholder return ("RTSR"). RTSR is an incentive measure whereby participants will earn from 0% to 200% of the target award based on the Company’s RTSR ranking compared to the RTSR of the companies in the Company’s designated peer group at the end of the performance period. Awards will be earned and vested over a performance period measured from January 1, 2019 to December 31, 2021, subject to earlier termination of the performance period in the event of a change in control. Unrecognized compensation expense as of March 31, 2021 related to performance vesting restricted shares was $1.1 million. The expense is expected to be recognized over a weighted average period of 1.04 years.

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2020 Cash Retention Incentives

On August 4, 2020, the Company's Board of Directors authorized a redesign of the incentive compensation program for the Company's workforce, including for its current named executive officers. In connection with a comprehensive review of the Company’s compensation programs and in consultation with its independent compensation consultant and legal advisors, the Board of Directors determined that significant changes were appropriate to retain and motivate the Company’s employees as a result of the ongoing uncertainty and unprecedented disruption in the oil and gas industry.

All unpaid amounts previously awarded pursuant to the 2020 Incentive Plan and all restricted stock units granted in 2020 issued to the Company's named executive officers were cancelled and replaced with cash retention incentives. These cash retention incentives are equally weighted between achievement of certain specified performance metrics and a service period. Of the cash retention incentives, 50% may be clawed back on an after-tax basis if an executive officer terminates employment for any reason other than a qualifying termination prior to the earlier of July 31, 2021, a change in control or completion of a restructuring, and the remaining 50% will be subject to repayment on an after-tax basis if established performance metrics are not met over performance periods from August 1, 2020 through July 31, 2021. In total, $13.5 million in cash retention incentives were paid to the Company's executives in August 2020.

The transactions were considered a modification to the previously issued equity- and liability-classified awards, and the previously issued equity-classified awards were reclassified as liability awards. The after-tax value of the cash incentives paid to the Company's executives of was capitalized to prepaid expenses and other current assets in the accompanying consolidated balance sheets and will be amortized over the remaining service period. Unrecognized compensation expense as of March 31, 2021 related to these payments was $2.1 million.

7.EARNINGS (LOSS) 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 March 31,
	2021		2020
	(In thousands, except share data)
Net income (loss)	$	8,780	$	(517,538)
Basic Shares	160,812,935		159,760,222
Basic EPS	$	0.05	$	(3.24)
Effect of dilutive securities:
Stock options and awards	—		—
Dilutive Shares	160,812,935		159,760,222
Dilutive EPS	$	0.05	$	(3.24)

There were no potential shares of common stock that were considered dilutive for the three months ended March 31, 2021. There were 1,552,423 potential shares of common stock that were considered anti-dilutive for the three months ended March 31, 2020.

8.COMMITMENTS AND CONTINGENCIES

Future Firm Transportation and Gathering Agreements

The Company has contractual commitments with pipeline companies for future gathering and transportation of natural gas from the Company's producing wells to downstream markets. Under certain of these agreements, the Company has minimum daily volume commitments. The Company is also obligated under certain of these arrangements to pay a demand charge for firm capacity rights on pipeline systems regardless of the amount of pipeline capacity utilized by the Company. If the Company does not utilize the capacity, it often can release it to other counterparties, thus reducing the cost of these commitments. Commitments related to future firm transportation and gathering agreements are not recorded as obligations in the accompanying consolidated balance sheets; however, they are reflected in the Company's estimates of proved reserves.

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Additionally, one of the requirements provided for in the RSA is that the Company must permanently reduce its future demand reservation fees owed over the life of all of its firm transportation agreements, taken as a whole, by at least 50% of the amount of all such fees owed on October 31, 2020, as calculated on a PV-10 basis. Additionally, the Company must reduce the future firm transportation demand reservation volumes over the life of all of its firm transportation agreements, taken as a whole, by at least 35%. Since the filing of the Chapter 11 Cases in November 2020, the Company has successfully renegotiated or terminated certain of its midstream contracts and commitments, significantly reducing its transportation expenses. As of March 31, 2021, the Company was still negotiating certain of its midstream contracts pending emergence from Chapter 11. However, there can be no assurances the Company will successfully renegotiate or terminate any additional midstream contracts. The below table reflects the Company's obligations as of March 31, 2021 excluding contemplation of any contracts yet to be terminated or renegotiated throughout the Chapter 11 Cases.

A summary of these commitments at March 31, 2021 are set forth in the table below:


	(In thousands)
Remaining 2021	$	242,253
2022	324,048
2023	322,241
2024	302,116
2025	215,119
Thereafter	1,575,874
Total	$	2,981,651

Future Firm Sales Commitments

The Company has entered into various firm sales contracts to deliver and sell natural gas. The Company expects to fulfill its delivery commitments primarily with production from proved developed reserves. The Company's operated production has generally been sufficient to satisfy its delivery commitments during the periods presented, and it expects its operated production will continue to be the primary means of fulfilling its future commitments. However, where the Company's operated production is not sufficient to satisfy its delivery commitments, it can and may use spot market purchases to satisfy the commitments.

A summary of these volume commitments at March 31, 2021 are set forth in the table below:


						(MMBtu per day)
Remaining 2021						61,000
2022						49,000
2023						17,000



Total						127,000

Litigation and Regulatory Proceedings

The Company is involved in a number of litigation and regulatory proceedings including those described below. Many of these proceedings are in early stages, and many of them seek or may seek damages and penalties, the amount of which is indeterminate. The Company's total accrued liabilities in respect of litigation and regulatory proceedings is determined on a case-by-case basis and represents an estimate of probable losses after considering, among other factors, the progress of each case or proceeding, its experience and the experience of others in similar cases or proceedings, and the opinions and views of legal counsel. Significant judgment is required in making these estimates and their final liabilities may ultimately be materially different.

The Company, along with a number of other oil and gas companies, has been named as a defendant 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 15th Judicial District of the State of Louisiana in the 15th Judicial District Court for the Parish of Vermilion on July 29, 2016 (together, the

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"Complaints"). The Complaints allege that certain of the defendants’ operations violated the State and Local Coastal Resources Management Act of 1978, as amended, and the rules, regulations, orders and ordinances adopted thereunder (the "CZM Laws") by causing substantial damage to land and waterbodies located in the coastal zone of the relevant Parish. 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 interest. The United States District Court for the Western District of Louisiana issued orders remanding the cases to their respective state court, and the defendants have appealed the remand orders to the 5th Circuit Court of Appeals.

In September 2019, a stockholder of Mammoth Energy filed a derivative action on behalf of Mammoth Energy against members of Mammoth Energy’s board of directors, including a director designated by the Company, and its significant stockholders, including the Company, in the United States District Court for the Western District of Oklahoma. The complaint alleges, among other things, that the members of Mammoth Energy’s board of directors breached their fiduciary duties and violated the Securities Exchange Act of 1934, as amended, in connection with Mammoth Energy’s activities in Puerto Rico following Hurricane Maria. The complaint seeks unspecified damages, the payment of reasonable attorney fees and legal expenses and interest and to force Mammoth Energy and its board of directors to make specified corporate governance reforms.

In October 2019, Kelsie Wagner, in her capacity as trustee of various trusts and on behalf of the trusts and other similarly situated royalty owners, filed an action against the Company in the District Court of Grady County, Oklahoma. The suit alleges that the Company underpaid royalty owners and seeks unspecified damages for violations of the Oklahoma Production Revenue Standards Act and fraud. This matter was administratively terminated on December 2, 2020.

In March 2020, Robert F. Woodley, individually and on behalf of all others similarly situated, filed a federal securities class action against the Company, David M. Wood, Keri Crowell and Quentin R. Hicks in the United States District Court for the Southern District of New York. The complaint alleges that the Company made materially false and misleading statements regarding the Company’s business and operations in violation of the federal securities laws and seeks unspecified damages, the payment of reasonable attorneys’ fees, expert fees and other costs, pre-judgment and post-judgment interest, and such other and further relief that may be deemed just and proper.

The Company filed a lawsuit against Stingray Pressure Pumping LLC, a subsidiary of Mammoth Energy (“Stingray”), for breach of contract and to terminate the Master Services Agreement for pressure pumping services, effective as of October 1, 2014, as amended (the “Master Services Agreement”), between Stingray and the Company. In March 2020, Stingray filed a counterclaim against the Company in the Superior Court of the State of Delaware. The counterclaim alleges that the Company has breached the Master Services Agreement. The counterclaim seeks actual damages, and Stingray filed claims in the Chapter 11 proceedings exceeding $80 million related to breach of contract damages, attorneys' fees and interest.

In April 2020, Bryon Lefort, individually and on behalf of similarly situated individuals, filed an action against the Company in the United States District Court for the Southern District of Ohio Eastern Division. The complaint alleges that the Company violated the Fair Labor Standards Act (“FLSA”), the Ohio Wage Act and the Ohio Prompt Pay Act by classifying the plaintiffs as independent contractors and paying them a daily rate with no overtime compensation for hours worked in excess of 40 hours per week. The complaint seeks to recover unpaid regular and overtime wages, liquidated damages in an amount equal to six percent of all unpaid overtime compensation, the payment of reasonable attorney fees and legal expenses and pre-judgment and post-judgment interest, and such other damages that may be owed to the workers, and claims were filed in the Chapter 11 proceedings totaling $5.8 million.

In August 2020, Muskie filed an action against the Company in the Superior Court of the State of Delaware for breach of contract. The complaint alleges that the Company breached its obligation to purchase a certain amount of proppant sand each month or make designated shortfall payments under the Sand Supply Agreement, effective October 1, 2014, as amended (the “Sand Supply Agreement”), between Muskie and the Company, and seeks payment of unpaid shortfall payments, and Muskie filed a claim in the Chapter 11 proceedings for $3.4 million.

As part of its Chapter 11 Cases and restructuring efforts as discussed in Note 2, the Company filed motions to reject certain firm transportation agreements between the Company and affiliates of TC Energy Corporation and Rover Pipeline LLC (the “Pending Motions to Reject”). The Pending Motions to Reject were removed to the United States District Court for the Southern District of Texas. While the Pending Motions to Reject are litigated, the Company isn’t required to perform under these firm transportation agreements. The Company believes that the Pending Motions to Reject will be ultimately granted, and that the Company does not have any ongoing obligations pursuant to the contracts; however, in the event that the Company is not permitted to reject these firm transportation contracts, the monetary damages awarded could be greater than $57 million.

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Business Operations

The Company is involved in various lawsuits and disputes incidental to its business operations, including commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions.

Environmental Contingencies

The nature of the oil and gas business carries with it certain environmental risks for Gulfport and its subsidiaries. Gulfport and its subsidiaries have implemented various policies, programs, procedures, training and audits to reduce and mitigate environmental risks. They conduct periodic reviews, on a company-wide basis, to assess changes in their environmental risk profile. Environmental reserves are established for environmental liabilities for which economic losses are probable and reasonably estimable. The Company manages its exposure to environmental liabilities in acquisitions by using an evaluation process that seeks to identify pre-existing contamination or compliance concerns and address the potential liability. Depending on the extent of an identified environmental concern, they may, among other things, exclude a property from the transaction, require the seller to remediate the property to their satisfaction in an acquisition or agree to assume liability for the remediation of the property.

Other Matters

Based on management’s current assessment, they are of the opinion that no pending or threatened lawsuit or dispute relating to its business operations is likely to have a material adverse effect on their future consolidated financial position, results of operations or cash flows. The final resolution of such matters could exceed amounts accrued, however, and actual results could differ materially from management’s estimates.

9.DERIVATIVE INSTRUMENTS

Natural Gas, Oil and Natural Gas Liquids Derivative Instruments

The Company seeks to mitigate risks related to unfavorable changes in natural gas, oil and NGL prices, which are subject to significant and often volatile fluctuation, by entering into over-the-counter fixed price swaps, basis swaps, collars and various types of option contracts. These contracts allow the Company to mitigate the impact of declines in future natural gas, oil and NGL prices by effectively locking in floor price for a certain level of the Company’s production. However, these hedge contracts also limit the benefit to the Company in periods when the future market prices of natural gas, oil and NGL that are higher than the hedged prices.

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, the NYMEX West Texas Intermediate for oil and Mont Belvieu for propane, pentane and ethane. Below is a summary of the Company’s open fixed price swap positions as of March 31, 2021.

Location

Daily Volume
(MMBtu/day)

Weighted
Average Price

Remaining 2021

NYMEX Henry Hub

351,316

2.73

Location

Daily Volume
(Bbl/day)

Weighted
Average Price

Remaining 2021

NYMEX WTI

1,505

53.07


	Location	Daily Volume (Bbl/day)	Weighted Average Price
Remaining 2021	Mont Belvieu C3	2,074	$	27.80
2022	Mont Belvieu C3	496	$	27.30

In the second half of 2019, the Company sold 2022 and 2023 natural gas call options in exchange for a premium, and used the associated premiums to enhance the fixed price on certain natural gas swaps that settled in 2020. Each call option has an established ceiling price of $2.90/MMBtu. If monthly NYMEX natural gas prices settle above the $2.90 ceiling price, the Company is required to pay the option counterparty an amount equal to the difference between the referenced NYMEX natural gas settlement price and $2.90 multiplied by the hedged contract volumes. Below is a summary of the Company's sold call option positions as of March 31, 2021.


	Location	Daily Volume (MMBtu/day)	Weighted Average Price

2022	NYMEX Henry Hub	152,675	$	2.90
2023	NYMEX Henry Hub	627,675	$	2.90

The Company entered into costless collars based off the NYMEX Henry Hub natural gas index. Each two-way price collar has a set floor and ceiling price for the hedged production. If the applicable monthly price indices are outside of the ranges set by the floor and ceiling prices in the various collars, the Company will cash-settle the difference with the hedge counterparty. Below is a summary of the Company's costless collar positions as of March 31, 2021.


	Location	Daily Volume (MMBtu/day)	Weighted Average Floor Price		Weighted Average Ceiling Price
Remaining 2021	NYMEX Henry Hub	390,509	$	2.54	$	2.93
2022	NYMEX Henry Hub	186,438	$	2.63	$	3.04

In addition, the Company entered into natural gas basis swap hedge contracts. If the applicable monthly price indices are outside of the ranges set forth in the various natural gas basis swap contracts, the Company will cash-settle the difference with the hedge counterparty. Below is a summary of the Company's basis swap positions as of March 31, 2021.


	Gulfport Pays	Gulfport Receives	Daily Volume (MMBtu/day)	Weighted Average Fixed Spread
Remaining 2021	Rex Zone 3	NYMEX Plus Fixed Spread	85,309	$	(0.22)
Remaining 2021	Tetco M2	NYMEX Plus Fixed Spread	32,384	$	(0.63)
2022	Rex Zone 3	NYMEX Plus Fixed Spread	14,795	$	(0.10)

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 March 31, 2021 and December 31, 2020:


	March 31, 2021		December 31, 2020
	(In thousands)

Short-term derivative asset	$	12,422	$	27,146
Long-term derivative asset	652		322
Short-term derivative liability	(20,687)		(11,641)
Long-term derivative liability	(43,267)		(36,604)
Total commodity derivative position	$	(50,880)	$	(20,777)

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 months ended March 31, 2021 and 2020.


	Net (loss) gain on derivative instruments
	Three months ended March 31,
	2021		2020
	(In thousands)
Natural gas derivatives	$	(25,413)	$	45,853
Oil derivatives	(1,731)		52,874
NGL derivatives	(2,834)		920
Contingent consideration arrangement	—		(1,381)
Total	$	(29,978)	$	98,266

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 March 31, 2021
	Gross Assets (Liabilities)		Gross Amounts
	Presented in the		Subject to Master		Net
	Consolidated Balance Sheets		Netting Agreements		Amount
	(In thousands)
Derivative assets	$	13,074	$	(13,074)	$	—
Derivative liabilities	$	(63,954)	$	13,074	$	(50,880)


	As of December 31, 2020
	Gross Assets (Liabilities)		Gross Amounts
	Presented in the		Subject to Master		Net
	Consolidated Balance Sheets		Netting Agreements		Amount
	(In thousands)
Derivative assets	$	27,468	$	(25,730)	$	1,738
Derivative liabilities	$	(48,245)	$	25,730	$	(22,515)

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.

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10.FAIR VALUE MEASUREMENTS

The Company records certain financial and non-financial assets and liabilities on the balance sheet at fair value. Fair value is 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. Market or observable inputs are the preferred sources of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. Fair value measurements are 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.

Financial assets and liabilities

The following tables summarize the Company’s financial and non-financial assets and liabilities by valuation level as of March 31, 2021 and December 31, 2020:


	March 31, 2021
	Level 1		Level 2		Level 3
	(In thousands)
Assets:
Derivative Instruments	$	—	$	13,074	$	—
Contingent consideration arrangement	$	—	$	—	$	6,000
Total assets	$	—	$	13,074	$	6,000
Liabilities:
Derivative Instruments	$	—	$	63,954	$	—


	December 31, 2020
	Level 1		Level 2		Level 3
	(In thousands)
Assets:
Derivative Instruments	$	—	$	27,468	$	—
Contingent consideration arrangement	$	—	$	—	$	6,200
Total assets	$	—	$	27,468	$	6,200
Liabilities:
Derivative Instruments	$	—	$	48,245	$	—

The Company estimates the fair value of all derivative instruments using industry-standard models that consider 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 Company's SCOOP water infrastructure sale, which closed in the first quarter of 2020, included a contingent consideration arrangement. As of March 31, 2021, the fair value of the contingent consideration was $6.0 million, of which

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$1.3 million is included in prepaid expenses and other assets and $4.7 million is included in other assets in the accompanying consolidated balance sheets. The fair value of the contingent consideration arrangement is calculated using discounted cash flow techniques and is based on internal estimates of the Company's future development program and water production levels. Given the unobservable nature of the inputs, the fair value measurement of the contingent consideration arrangement is deemed to use Level 3 inputs. The Company has elected the fair value option for this contingent consideration arrangement and, therefore, records changes in fair value in earnings. The Company recognized an immaterial gain and a gain of $0.2 million on changes in fair value of the contingent consideration during the three months ended March 31, 2021 and 2020, respectively, which is included in other expense (income) in the accompanying consolidated statements of operations.

Non-financial assets and liabilities

The initial measurement of asset retirement obligations at fair value is 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 3 for further discussion of the Company’s asset retirement obligations. Asset retirement obligations incurred during the three months ended March 31, 2021 were approximately $0.5 million.

As discussed in Note 3, the Company recorded an impairment during the three months ended March 31, 2021 on its corporate headquarters. The estimated fair value of the building was primarily based on third party estimates and, therefore, is deemed to use Level 3 inputs.

Fair value of other 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 Company's building loan is carried at cost, which approximates market value based on the borrowing rates currently available to the Company with similar terms and maturities.

11.REVENUE FROM CONTRACTS WITH CUSTOMERS

Revenue Recognition

The Company’s revenues are primarily derived from the sale of natural gas, oil and condensate and NGL. Sales of natural gas, oil and condensate and NGL are recognized in the period that the performance obligations are satisfied. The Company generally considers the delivery of each unit (MMBtu or Bbl) to be separately identifiable and represents a distinct performance obligation that is satisfied at the time control of the product is transferred to the customer. Revenue is measured based on consideration specified in the contract with the customer, and excludes any amounts collected on behalf of third parties. These contracts typically include variable consideration that is based on pricing tied to market indices and volumes delivered in the current month. As such, this market pricing may be constrained (i.e., not estimable) at the inception of the contract but will be recognized based on the applicable market pricing, which will be known upon transfer of the goods to the customer. The payment date is usually within 30 days of the end of the calendar month in which the commodity is delivered.

Gathering, processing and compression fees attributable to gas processing, as well as any transportation fees, including firm transportation fees, incurred to deliver the product to the purchaser, are presented as midstream, gathering and processing expense in the accompanying consolidated statements of operations.

Transaction Price Allocated to Remaining Performance Obligations

A significant number of the Company's product sales are short-term in nature generally through evergreen contracts with contract terms of one year or less. These contracts typically automatically renew under the same provisions. For those contracts, the Company has utilized the practical expedient allowed in the new revenue accounting standard that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less.

For product sales that have a contract term greater than one year, the Company has utilized the practical expedient that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of

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product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Currently, the Company's product sales that have a contractual term greater than one year have no long-term fixed consideration.

Contract Balances

Receivables from contracts with customers are recorded when the right to consideration becomes unconditional, generally when control of the product has been transferred to the customer. Receivables from contracts with customers were $134.0 million and $119.9 million as of March 31, 2021 and December 31, 2020, respectively, and are reported in accounts receivable - oil and natural gas sales on the consolidated balance sheets. The Company currently has no assets or liabilities related to its revenue contracts, including no upfront or rights to deficiency payments.

Prior-Period Performance Obligations

The Company records revenue in the month production is delivered to the purchaser. However, settlement statements for certain sales may be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. The differences between the estimates and the actual amounts for product sales is recorded in the month that payment is received from the purchaser. For the three months ended March 31, 2021, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.

12.LEASES

Nature of Leases

The Company has operating leases on certain equipment and field offices with remaining lease durations in excess of one year. The Company recognizes a right-of-use asset and lease liability on the balance sheet for all leases with lease terms of greater than one year. Short-term leases that have an initial term of one year or less are not capitalized.

The Company has entered into contracts for drilling rigs with varying terms with third parties to ensure operational continuity, cost control and rig availability in its operations. The Company has concluded its drilling rig contracts are operating leases as the assets are identifiable and the Company has the right to control the identified assets. The Company's drilling rig commitments are typically structured with an initial term of less than one year to two years, although at March 31, 2021, the Company did not have any active long-term drilling rig contracts in place.

The Company rents office space for its field locations and certain other equipment from third parties, which expire at various dates through 2024. These agreements are typically structured with non-cancelable terms of one to five years. The Company has determined these agreements represent operating leases with a lease term that equals the primary non-cancelable contract term. The Company has included any renewal options that it has determined are reasonably certain of exercise in the determination of the lease terms.

Discount Rate

As most of the Company's leases do not provide an implicit rate, the Company uses its incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. The Company's incremental borrowing rate reflects the estimated rate of interest that it would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment.

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Maturities of operating lease liabilities as of March 31, 2021 were as follows:


	(In thousands)
Remaining 2021	$	97
2022	115
2023	90
2024	30

Total lease payments	$	332
Less: Imputed interest	(18)
Total	$	314

Lease cost for the three months ended March 31, 2021 and 2020 consisted of the following:


	Three months ended March 31,
	2021		2020
	(In thousands)
Operating lease cost	$	32	$	4,082

Variable lease cost	—		224

Short-term lease cost	2,189		2,810
Total lease cost(1)	$	2,221	$	7,116


(1)			The majority of the Company's total lease cost was capitalized to the full cost pool, and the remainder was included in general and administrative expenses in the accompanying consolidated statements of operations.

Supplemental cash flow information for the three months ended March 31, 2021 and 2020 related to leases was as follows:


	Three months ended March 31,
	2021		2020
Cash paid for amounts included in the measurement of lease liabilities	(In thousands)
Operating cash flows from operating leases	$	31	$	36
Investing cash flow from operating leases	$	—	$	3,997
Investing cash flow from operating leases—related party	$	—	$	6,800

The weighted-average remaining lease term as of March 31, 2021 was 2.8 years. The weighted-average discount rate used to determine the operating lease liability as of March 31, 2021 was 4.22%.

13.INCOME TAXES

The Company records its quarterly tax provision based on an estimate of the annual effective tax rate expected to apply to continuing operations for the various jurisdictions in which it operates. The tax effects of certain items, such as tax rate changes, significant unusual or infrequent items, and certain changes in the assessment of the realizability of deferred taxes, are recognized as discrete items in the period in which they occur and are excluded from the estimated annual effective tax rate.

For the three months ended March 31, 2021, the Company's estimated annual effective tax rate before discrete items was approximately 0% as a result of the valuation allowance on its deferred tax assets.

At each reporting period, the Company weighs all available positive and negative evidence to determine whether its deferred tax assets are more likely than not to be realized. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax assets will not be realized. To assess that likelihood, the Company uses estimates and judgment regarding future taxable income and considers the tax laws in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is

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required. Such evidence can include current financial position, results of operations, both actual and forecasted, the reversal of deferred tax liabilities and tax planning strategies as well as the current and forecasted business economics of the oil and gas industry. The cumulative loss in recent years is a significant piece of negative evidence that is hard to overcome and therefore the Company placed more reliance on historical results than forecasts. As a result of this analysis, the Company determined a full valuation allowance of $911.4 million was necessary against its net deferred tax asset as of March 31, 2021.

14.SUBSEQUENT EVENTS

Chapter 11 Proceedings Update

The Bankruptcy Court entered an order confirming the Plan on April 28, 2021. In support of the Plan, the enterprise value of the Successor was estimated and approved by the Bankruptcy Court to be in the range of $1.3 billion to $1.9 billion.

Upon emergence from bankruptcy, which is expected to occur in May 2021, Gulfport expects to qualify for fresh-start reporting. In order to qualify for fresh start-reporting (i) the holders of existing voting shares of the Company prior to its emergence must receive less than 50% of the voting shares of the Company outstanding following its emergence from bankruptcy and (ii) the reorganization value of our assets immediately prior to confirmation of the plan of reorganization must be less than the post-petition liabilities and allowed claims. Under the principles of fresh-start reporting, a new reporting entity will be considered to have been created, and, as a result, the Company will allocate the reorganization value of the Company to its individual assets, including property, plant and equipment, based on their estimated fair values. Gulfport cannot currently estimate the financial effect of emergence from bankruptcy on its financial statements, although it expects to record material adjustments related to its Plan and the application of fresh-start reporting guidance upon the Effective Date.

Natural Gas, Oil and Natural Gas Liquids Derivative Instruments

Subsequent to March 31, 2021 and as of April 30, 2021, the Company entered into the following natural gas and oil derivative contracts as it completed minimum hedging requirements as provided for in the RSA:

Period

Type of Derivative Instrument

Index

Daily Volume(1)

Weighted
Average Price

November 2021 - March 2022

Basis Swaps

Rex Zone 3

40,000

(0.10)

April 2022 - December 2022

Costless Collars

NYMEX Henry Hub

139,773

$2.40/$2.60

January 2022 - December 2022

Costless Collars

NYMEX WTI

1,500

$55.00/$60.00

(1) Volume units for gas instruments are presented as MMBtu/day and oil is presented in Bbls/day.

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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 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section and audited consolidated financial statements and related notes included in our Annual Report on Form 10-K and with the unaudited consolidated financial statements and related notes thereto presented in this Quarterly Report on Form 10-Q.

Cautionary Note Regarding Forward-Looking Statements

This Form 10-Q may include forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), and the Private Securities Litigation Reform Act of 1995, that are subject to risks and uncertainties. These statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements. In some cases, you can identify forward looking statements by terms such as “may,” “will,” “should,” “could,” “would,” “expects,” “plans,” “anticipates,” “intends,” “believes,” “estimates,” “projects,” “predicts,” “potential” and similar expressions intended to identify forward-looking statements. All statements, other than statements of historical facts, included in this Form 10-Q that address activities, events or developments that we expect or anticipate will or may occur in the future, including such things as the potential effects of the Chapter 11 Cases on our operations, management, and employees, our ability to consummate the restructuring, our ability to continue as a going concern, the expected impact of the COVID-19 pandemic on our business, our industry and the global economy, estimated future net revenues from oil and gas reserves and the present value thereof, future capital expenditures (including the amount and nature thereof), business strategy and measures to implement strategy, competitive strength, goals, expansion and growth of our business and operations, plans, references to future success, reference to intentions as to future matters and other such matters are forward-looking statements.

These forward-looking statements are largely based on our expectations and beliefs concerning future events, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors relating to our operations and business environment, all of which are difficult to predict and many of which are beyond our control.

Although we believe our estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management's assumptions about future events may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained in this Form 10-Q are not guarantees of future performance, and we cannot assure any reader that those statements will be realized or the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to the factors listed in Item 1A. “Risk Factors” and Item 7. “Management's Discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K for the year ended December 31, 2020 and elsewhere in this Form 10-Q. All forward-looking statements speak only as of the date of this Form 10-Q.

All forward-looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this Quarterly Report.

Investors should note that we announce financial information in SEC filings. We may use the Investors section of our website (www.gulfportenergy.com) to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. The information on our website is not part of this Quarterly Report on Form 10-Q.

Overview

We are an independent natural gas-weighted exploration and production company focused on the exploration, acquisition and production of natural gas, crude oil and NGL in the United States with primary focus in the Appalachia and Anadarko

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basins. Our principal properties are located in Eastern Ohio targeting the Utica formation and in central Oklahoma targeting the SCOOP Woodford and SCOOP Springer formations.

Voluntary Reorganization Under Chapter 11

On November 13, 2020, we and our subsidiaries filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the Southern District of Texas. The Chapter 11 Cases are being administered jointly under the caption In re Gulfport Energy Corporation, et al., Case No. 20-35562 (DRJ). We continue to operate our businesses as "debtors-in-possession" under the jurisdiction of the Bankruptcy Court, in accordance with the applicable provisions of the Bankruptcy Code and the orders of the Bankruptcy Court.

The Bankruptcy Court has granted first- and second-day motions filed by us that were designed primarily to mitigate the impact of the Chapter 11 Cases on our operations, customers and employees. As a result, we are able to conduct normal business activities and pay all associated obligations for the period following the Bankruptcy Filing and are authorized to pay owner royalties, employee wages and benefits and certain vendors and suppliers in the ordinary course for goods and services provided. During the pendency of the Chapter 11 Cases, all transactions outside the ordinary course of business require the prior approval of the Bankruptcy Court.

For the duration of the Chapter 11 Cases, our operations and ability to develop and execute our business plan are subject to the risks and uncertainties associated with the Chapter 11 process as described in "Risk Factors" in Item 1A. of our Annual Report on Form 10-K for the year ended December 31, 2020. As a result of these risks and uncertainties, the number of our shares of common stock and stockholders, assets, liabilities, officers and/or directors could be significantly different following the outcome of the Chapter 11 Cases, and the description of our operations, properties and capital plans included in this Form 10-Q may not accurately reflect our operations, properties and capital plans following the Chapter 11 Cases.

During the Chapter 11 Cases, we expect our financial results to continue to be volatile as restructuring activities and expenses, contract terminations and rejections and claims assessments significantly impact our consolidated financial statements. As a result, our historical financial performance is likely not indicative of our financial performance after the date of the Bankruptcy Filing. In addition, we have incurred significant professional fees and other costs in connection with the Chapter 11 Cases and expect that we will continue to incur significant professional fees and costs throughout our Chapter 11 Cases until emergence.

See Note 2 of the notes to our consolidated financial statements included in Item 8 of Part II of this report for a complete discussion of the Chapter 11 Cases.

Delisting of our Common Stock from Nasdaq

On November 27, 2020, our common stock was suspended from trading on NASDAQ. On November 30, 2020, our common stock began trading on the OTC Pink Marketplace maintained by the OTC Markets Group, Inc. under the symbol “GPORQ". On February 2, 2021, NASDAQ filed a Form 25 delisting our common stock from trading on NASDAQ, which delisting became effective 10 days after the filing of the Form 25. In accordance with Rule 12d2-2 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), the de-registration of our common stock under section 12(b) of the Exchange Act became effective on February 12, 2021.

COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas

As a result of our business continuity measures, we have not experienced significant disruptions in executing our business operations due to COVID-19. While we did not experience significant disruptions to our operations in the first quarter of 2021, we are unable to predict the impact on our business, including our cash flows, liquidity, and results of operations in future periods due to numerous uncertainties. Restrictions may cause, us, our suppliers and other business counterparties to experience operational delays, or delays in the delivery of materials and supplies. We expect the principal areas of operational risk for us are the availability and reliability of service providers and potential supply chain disruption. Additionally, the operations of our midstream service providers, on whom we rely for the transmission, gathering and processing of a significant portion of our produced natural gas, NGL and oil, may be disrupted or suspended in response to containing the outbreak, or the difficult economic environment may lead to the bankruptcy or closing of the facilities and infrastructure of our midstream service providers. This may result in substantial discount in the prices we receive for our produced natural gas, NGL and oil or result in the shut-in of producing wells or the delay or discontinuance of development plans for our properties.

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We cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the oil and natural gas markets will have on our business, cash flows, liquidity, financial condition and results of operations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments and the timing and extent to which normal economic and operating conditions resume. While we have seen meaningful recovery in demand during the second half 2020 and into 2021, significant uncertainty remains regarding the duration and extent of the impact of the pandemic on the energy industry, including demand and commodities pricing, although we expect to see further recovery as vaccines are distributed and more normal societal activity resumes.

2021 Operational and Financial Highlights

During the three months ended March 31, 2021, we had the following notable achievements:

•An order was entered to confirm our Plan by the Bankruptcy Court on April 28, 2021. We expect to emerge from Chapter 11 proceedings and complete our financial restructuring in May 2021.

•We continued to improve operational efficiencies and reduce drilling and completion costs in our operating areas. In the Utica, our average spud to rig release time was 17.0 days in the first quarter of 2021, which was a 9% improvement from full year 2020 levels.

•We have continued to decrease costs as a result of our ongoing cost reduction initiatives highlighted by a 7% decrease in lease operating expenses per Mcfe and a 13% decrease in general and administrative expenses per Mcfe for the first quarter of 2021 as compared to the first quarter of 2020.

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2021 Production and Drilling Activity

Production Volumes


	Three months ended March 31,
	2021	% of Total		2020	% of Total		Change	% Change
Natural gas (Mcf/day)
Utica	797,452	88	%	785,781	83	%	11,671	1	%
SCOOP	111,708	12	%	159,886	17	%	(48,178)	(30)	%
Other	80	—	%	39	—	%	41	105	%
Total	909,240			945,706			(36,466)	(5)	%
Oil and condensate (Bbl/day)
Utica	1,403	37	%	592	10	%	811	137	%
SCOOP	2,379	62	%	5,174	89	%	(2,795)	(54)	%
Other	40	1	%	78	1	%	(38)	(49)	%
Total	3,822			5,844			(2,022)	(35)	%
NGL (Bbl/day)
Utica	2,665	32	%	3,197	26	%	(532)	(17)	%
SCOOP	5,758	68	%	8,974	74	%	(3,216)	(36)	%
Other	4	—	%	—	—	%	4	100	%
Total	8,427			12,171			(3,744)	(31)	%
Combined (Mcfe/day)
Utica	821,858	84	%	808,520	77	%	13,338	2	%
SCOOP	160,528	16	%	244,771	23	%	(84,243)	(34)	%
Other	343	—	%	508	—	%	(165)	(32)	%
Total	982,729			1,053,799			(71,070)	(7)	%

Our total net production averaged approximately 982.7 MMcfe per day during the three months ended March 31, 2021, as compared to 1,053.8 MMcfe per day during the same period in 2020. The 7% decrease in production is largely the result of a decrease in development activities in the SCOOP throughout 2020.

Utica. From January 1, 2021 through March 31, 2021, we spud nine gross (nine net) wells in the Utica, of which five were being drilled and four were in various stages of operations at March 31, 2021. In addition, we completed seven gross and net operated wells. We did not participate in any additional wells that were drilled by other operators on our Utica acreage.

As of April 30, 2021, we had two operated drilling rigs running in the Utica, both of which we expect to release in May 2021. We expect to add back one operated drilling rig in the Utica in the third quarter of 2021.

SCOOP. From January 1, 2021 through March 31, 2021, we did not spud any wells in the SCOOP. We completed three gross (2.69 net) operated wells. We also participated in an additional three gross wells that were drilled by other operators on our SCOOP acreage.

As of April 30, 2021, we had one operated drilling rig running in the SCOOP, which we expect will continue through the remainder of 2021.

RESULTS OF OPERATIONS

Comparison of the Three Month Periods Ended March 31, 2021 and 2020

We reported a net income of $8.8 million for the three months ended March 31, 2021 as compared to net loss of $517.5 million for the three months ended March 31, 2020. The graph below shows the change in the net income (loss) from the three

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months ended March 31, 2020 to the three months ended March 31, 2021. The material changes are further discussed by category on the following pages. Some totals and changes throughout below section may not sum or recalculate due to rounding.

(1) Includes lease operating expenses, taxes other than income and transportation, gathering, processing and compression.

Natural Gas, Oil and NGL Sales


	Three months ended March 31,
	2021		2020		change
	($ In thousands)
Natural gas	$	235,321	$	161,008	46	%
Oil and condensate	18,239		23,151		(21)	%
NGL	23,776		16,913		41	%
Natural gas, oil and NGL sales	$	277,336	$	201,072	38	%

The increase in natural gas sales without the impact of derivatives was due to a 54% increase in realized natural gas prices partially offset by a 5% decrease in sales volumes.

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The decrease in oil and condensate sales without the impact of derivatives was due to a 35% decrease in oil and condensate sales volumes partially offset by a 22% increase in realized oil and condensate prices.

The increase in NGL sales without the impact of derivatives was due to a 105% increase in realized prices partially offset by a 31% decrease in NGL sales volumes.

Natural Gas, Oil and NGL Derivatives


	Three months ended March 31,
	2021		2020
	($ In thousands)
Natural gas derivatives - fair value losses	$	(25,538)	$	(15,125)
Natural gas derivatives - settlement gains	125		60,978
Total (losses) gains on natural gas derivatives	(25,413)		45,853

Oil and condensate derivatives - fair value (losses) gains	(1,731)		43,374
Oil and condensate derivatives - settlement gains	—		9,500
Total (losses) gains on oil and condensate derivatives	(1,731)		52,874

NGL derivatives - fair value (losses) gains	(2,834)		665
NGL derivatives - settlement gains	—		255
Total (losses) gains on NGL derivatives	(2,834)		920

Contingent consideration arrangement - fair value losses	—		(1,381)
Total (losses) gains on natural gas, oil and NGL derivatives	$	(29,978)	$	98,266

See Note 9 to our consolidated financial statements for further discussion of our derivative activity.

Natural Gas, Oil and NGL Production and Pricing

The following table summarizes our oil and condensate, natural gas and NGL production and related pricing for the three months ended March 31, 2021, as compared to such data for the three months ended March 31, 2020:

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	Three months ended March 31,
	2021		2020
	($ In thousands)
Natural gas sales
Natural gas production volumes (MMcf)	81,832		86,059
Natural gas production volumes (MMcf) per day	909		946
Total sales	235,321		161,008
Average price without the impact of derivatives ($/Mcf)	2.88		1.87
Impact from settled derivatives ($/Mcf)	—		0.71
Average price, including settled derivatives ($/Mcf)	2.88		2.58

Oil and condensate sales
Oil and condensate production volumes (MBbl)	344		532
Oil and condensate production volumes (MBbl) per day	4		6
Total sales	18,239		23,151
Average price without the impact of derivatives ($/Bbl)	53.03		43.53
Impact from settled derivatives ($/Bbl)	—		17.86
Average price, including settled derivatives ($/Bbl)	53.03		61.39

NGL sales
NGL production volumes (MBbl)	758		1,108
NGL production volumes (MBbl) per day	8		12
Total sales	23,776		16,913
Average price without the impact of derivatives ($/Bbl)	31.35		15.27
Impact from settled derivatives ($/Bbl)	—		—
Average price, including settled derivatives ($/Bbl)	31.35		15.27

Natural gas, oil and condensate and NGL sales
Natural gas equivalents (MMcfe)	88,446		95,896
Natural gas equivalents (MMcfe) per day	983		1,054
Total sales	277,336		201,072
Average price without the impact of derivatives ($/Mcfe)	3.14		2.10
Impact from settled derivatives ($/Mcfe)	—		0.74
Average price, including settled derivatives ($/Mcfe)	3.14		2.84

Production Costs:
Average lease operating expenses ($/Mcfe)	$	0.14	$	0.15
Average production taxes ($/Mcfe)	$	0.07	$	0.05
Average transportation, gathering, processing and compression ($/Mcfe)	$	1.20	$	1.15
Total lease operating expenses, midstream costs and production taxes ($/Mcfe)	$	1.41	$	1.35

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Lease Operating Expenses


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)
Lease operating expenses
Utica	$	9,222	$	9,898	(7)	%
SCOOP	3,357		4,765		(30)	%
Other(1)	74		32		131	%
Total lease operating expenses	$	12,653	$	14,695	(14)	%

Lease operating expenses per Mcfe
Utica	$	0.12	$	0.13	(7)	%
SCOOP	0.23		0.21		9	%
Other(1)	2.41		0.69		251	%
Total lease operating expenses per Mcfe	$	0.14	$	0.15	(7)	%

_____________________

(1) Includes Niobrara and Bakken.

The decrease in total LOE was primarily the result of a 7% decrease in production as well as ongoing cost reduction initiatives. The decrease in per unit LOE is primarily the result of ongoing cost reduction initiatives.

Taxes Other Than Income


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)
Production taxes	$	5,803	$	4,799	21	%
Property taxes	1,912		1,282		49	%
Other	989		556		78	%
Total taxes other than income	$	8,704	$	6,637	31	%
Production taxes per Mcfe	$	0.07	$	0.05	40	%

The increase in total and per unit production taxes was primarily related to an increase in revenues due to an increase in realized prices.

Transportation, Gathering, Processing and Compression


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)
Transportation, gathering, processing and compression	$	105,867	$	110,357	(4)	%
Transportation, gathering, processing and compression per Mcfe	$	1.20	$	1.15	4	%

The decrease in transportation, gathering, processing and compression was primarily related to a 7% decrease in our production. The increase in per unit transportation, gathering, processing and compression is primarily related to Utica

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production volumes falling below our minimum volume commitments on certain firm transportation and gathering contracts during the three months ended March 31, 2021.

Depreciation, Depletion and Amortization


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)
Depreciation, depletion and amortization of oil and gas properties	$	39,767	$	75,359	(47)	%
Depreciation, depletion and amortization of other property and equipment	$	1,380	$	2,669	(48)	%
Total Depreciation, depletion and amortization	$	41,147	$	78,028	(47)	%
Depreciation, depletion and amortization per Mcfe	$	0.47	$	0.81	(42)	%

The decrease in DD&A of oil and gas properties was due to both a decrease in our depletion rate as a result of a decrease in our amortization base from full cost ceiling test impairments recorded throughout 2020, as well as a decrease in our production.

Impairment of Oil and Gas Properties

We did not incur an oil and natural gas properties impairment charge during the three months ended March 31, 2021 while we recorded a $553.3 million impairment charge of oil and gas properties during the three months ended March 31, 2020. No impairment was required during the Current Quarter primarily due to the combination of improved commodity prices and a decrease in the net book value of our oil and gas properties stemming from impairment charges in 2020.

Impairment of Other Property and Equipment

We recognized a $14.6 million impairment charge on the Company's corporate headquarters during the three months ended March 31, 2021 as a result in a change in expected future use.

General and Administrative Expenses


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)
General and administrative expenses, gross	$	21,317	$	24,105	(12)	%
Reimbursed from third parties	$	(3,039)	$	(3,052)	—	%
Capitalized general and administrative expenses	$	(5,521)	$	(5,431)	2	%
General and administrative expenses, net	$	12,757	$	15,622	(18)	%

General and administrative expenses, net per Mcfe	$	0.14	$	0.16	(13)	%

The decrease in general and administrative expenses on a total and per unit basis was primarily driven by our continued focus on reducing costs across our organization and lower non-recurring legal and consulting expenses.

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Interest Expense


	Three months ended March 31,
	2021		2020
	($ In thousands, except per unit)
Interest expense on senior notes	$	—	$	29,119
Interest expense on pre-petition revolving credit facility	1,020		2,165
Interest expense on building loan and other	75		340
Capitalized interest	—		(187)
Amortization of loan costs	—		1,553
Interest on DIP credit facility	2,166		—
Total interest expense	$	3,261	$	32,990

Interest expense per Mcfe	$	0.04	$	0.34

Weighted average debt outstanding under revolving credit facility	$	307,208	$	81,978

The decrease of total and per unit interest expense was due to the cessation of interest accrual on borrowings classified as subject to compromise as of the petition date.

Gain on Debt Extinguishment.

In July of 2019, our Board of Directors authorized $100 million of cash to be used to repurchase its senior notes in the open market at discounted values to par. In December 2019, our Board of Directors increased the authorized size of the senior note repurchase program to $200 million in total. During the three months ended March 31, 2020, we repurchased in the open market $25.9 million aggregate principal amount of our outstanding Senior Notes for $10.2 million in cash and recognized a $15.3 million gain on debt extinguishment. We did not repurchase any of our Senior Notes in the three months ended March 31, 2021.

Equity Investments


	Three months ended March 31,
	2021		2020		change
	($ In thousands, except per unit)

Loss from equity method investments, net	$	342	$	10,789	(97)	%

During the three months ended March 31, 2020, our share of net loss from Mammoth was in excess of the carrying value of our investment, which reduced our investment to zero. Our carrying value has remained at zero as of March 31, 2021 and thus no additional net loss or income was recorded . See Note 4 to our consolidated financial statements for further discussion on our equity investments.

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Reorganization Items, Net.

The following table summarizes the components in reorganization items, net included in our consolidated statements of operations for the three months ended March 31, 2021:


	Three months ended March 31, 2021
	(in thousands)
Adjustment to allowed claims	$	2,088
Legal and professional fees	40,783


Gain on settlement of pre-petition accounts payable	(4,150)
Reorganization items, net	$	38,721

We have incurred and will continue to incur additional gains and losses associated with our reorganization, primarily related to legal and professional fees related to our ongoing Chapter 11 cases.

Income Taxes

We recorded no income tax expense for the three months ended March 31, 2021 as a result of maintaining a full valuation allowance of $911.4 million against our net deferred tax asset. We recorded income tax expense of $7.3 million for the three months ended March 31, 2020 as a result of the recognition of a valuation allowance against a state deferred tax asset.

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Liquidity and Capital Resources

Overview. Historically, our primary sources of capital funding and liquidity have been our operating cash flow, borrowings under our Pre-Petition Revolving Credit Facility and issuances of equity and debt securities. Our ability to issue additional indebtedness, dispose of assets or access the capital markets may be substantially limited or nonexistent during the Chapter 11 Cases and will require court approval in most instances. Accordingly, our liquidity will depend mainly on cash generated from operating activities and available funds under the DIP Credit Facility as discussed below.

Filing of the Chapter 11 Cases constituted an event of default with respect to certain of our secured and unsecured debt obligations. As a result of the Chapter 11 Cases, the principal and interest due under these debt instruments became immediately due and payable. However, the creditors are stayed from taking any action as a result of the default under Section 362 of the Bankruptcy Code.

As of March 31, 2021, we had a cash balance of $179.7 million compared to $89.9 million as of December 31, 2020, and a net working capital deficit of $137.1 million as of March 31, 2021, compared to a net working capital deficit of $100.5 million as of December 31, 2020. As of March 31, 2021, our working capital deficit includes $279.8 million of debt due in the next 12 months. Our total principal debt as of both March 31, 2021 and December 31, 2020 was $2.3 billion. As of March 31, 2021, we had no borrowing capacity available under the Pre-Petition Revolving Credit Facility, with outstanding borrowings of $316.8 million and $121.2 million utilized for various letters of credit and $76.5 million of borrowing capacity available under the DIP Credit Facility, with outstanding borrowings of $157.5 million and $28.5 million utilized for various letters of credit. See Note 5 of the notes to our consolidated financial statements for further discussion of our debt obligations, including principal and carrying amounts of our notes.

We believe our cash flow from operations, borrowing capacity under the DIP Credit Facility and cash on hand will provide sufficient liquidity during the Chapter 11 process. We expect to continue to incur significant costs related to our ongoing Chapter 11 Cases until our expected emergence in May 2021, including fees for legal, financial and restructuring advisors to the Company, certain of our creditors and royalty interest owners.

Our ability to continue as a going concern is contingent on our ability to comply with the financial and other covenants contained in our DIP Credit Facility, our ability to successfully implement the Plan and obtain exit financing, among other factors. As a result of the Bankruptcy Filing, the realization of assets and the satisfaction of liabilities are subject to uncertainty. While operating as debtors-in-possession under Chapter 11, we may settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business (and subject to restrictions contained in the DIP Credit Facility), for amounts other than those reflected in the accompanying consolidated financial statements.

The Bankruptcy Court entered an order confirming the Plan on April 28, 2021. See Note 2 for discussion of the exit facility to become effective upon emergence.

Debtor-In-Possession Credit Facility. Pursuant to the RSA, the Consenting RBL Lenders have agreed to provide the Company with a senior secured superpriority debtor-in-possession revolving credit facility in an aggregate principal amount of $262.5 million consisting of $105 million of new money and $157.5 million to roll up a portion of the existing outstanding obligations under the Pre-Petition Revolving Credit Facility. The proceeds of the DIP Credit Facility may be used for, among other things, post-petition working capital, permitted capital investments, general corporate purposes, letters of credit, administrative costs, premiums, expenses and fees for the transactions contemplated by the Chapter 11 Cases and payment of court approved adequate protection obligations.

Advances under our DIP 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 of 3.50%, plus (2) the base rate. The interest rate for eurodollar loans is equal to (1) the applicable rate of 4.50%, plus (2) the highest of: (a) 1% or (b) the eurodollar rate. As of March 31, 2021 amounts borrowed under our DIP Credit Facility bore interest at the weighted average rate of 5.50%. In addition to paying interest on outstanding principal and letters of credit posted under the DIP Credit Facility, we are required to pay a commitment fee of 0.50% per annum to the lenders of the DIP Credit Facility in respect of the unutilized DIP commitments thereunder and a letter of credit fee equal to 0.20% per annum.

The DIP Credit Facility includes negative covenants that, subject to significant exceptions, limit our ability and the ability of our restricted subsidiaries to, among other things, (i) create liens on assets, property revenues, (ii) make investments, (iii) incur additional indebtedness, (iv) engage in mergers, consolidations, liquidations and dissolutions, (v) sell assets, (vi) pay dividends and distributions or repurchase capital stock, (vii) cease for any reason to be the operator of its properties, (viii) enter into letters of credit without prior written consent, (ix) enter into certain commodity hedging contracts except commodity

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hedging contracts with terms approved by the Bankruptcy Court in the hedging order or certain interest rate contracts, (x) change lines of business, (xi) engage in certain transactions with affiliates and (xii) incur more than a certain amount in capital expenditures in any calendar month. The DIP Credit Facility includes certain customary representations and warranties, affirmative covenants and events of default, including but not limited to defaults on account of nonpayment, breaches of representations and warranties and covenants, certain bankruptcy-related events, certain events under ERISA, material judgments and a change in control. If an event of default occurs, the lenders under the DIP Credit Facility will be entitled to take various actions, including the acceleration of all amounts due under the DIP Credit Facility and all actions permitted to be taken under the loan documents or application of law. In addition, the DIP Credit Facility is subject to various other financial performance covenants, including compliance with certain financial metrics and adherence to a budget approved by our DIP Credit Facility lenders.

Pre-Petition Revolving Credit Facility. We have entered into a senior secured revolving credit facility agreement, 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 borrowing base amount of $580 million and matures on December 31, 2021. The $316.8 million of outstanding borrowings under the Pre-Petition Revolving Credit Facility as of March 31, 2021 that were not rolled up into the DIP Credit Facility will remain outstanding throughout the Chapter 11 Cases and will continue to accrue interest on amounts drawn after the Petition Date. Additionally, as of March 31, 2021, we had an aggregate of $121.2 million of letters of credit outstanding under our Pre-Petition Revolving Credit Facility. This facility is secured by substantially all of our assets. Our wholly-owned subsidiaries, excluding Grizzly Holdings and Mule Sky, guarantee our obligations under our revolving credit facility.

Advances under our Pre-Petition 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 0.25% to 1.25%, plus (2) the highest of: (a) the federal funds rate plus 0.50%, (b) the rate of interest in effect for such day as publicly announced from time to time by the administrative 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 1.25% to 2.25%, 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 other service that displays an average London interbank offered rate as administered by ICE Benchmark Administration (or any other person that takes over the 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 administrative agent shall inquire as the “London Interbank Offered Rate” for deposits in U.S. dollars. As of March 31, 2021, amounts borrowed under our revolving credit facility bore interest at the weighted average rate of 3.12%.

Senior Notes. In April 2015, we issued an aggregate of $350.0 million in principal amount of our 2023 Notes. Interest on these senior 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. As of March 31, 2021, $324.6 million principal amount remained outstanding. The 2023 Notes mature on May 1, 2023.

In October 2016, we issued an aggregate of $650.0 million in principal amount of our 2024 Notes. Interest on the 2024 Notes accrues at a rate of 6.000% per annum on the outstanding principal amount thereof, payable semi-annually on April 15 and October 15 of each year. As of March 31, 2021, $579.6 million principal amount remained outstanding. The 2024 Notes mature on October 15, 2024.

In December 2016, we issued an aggregate of $600.0 million in principal amount of our 2025 Notes. Interest on the 2025 Notes accrues at a rate of 6.375% per annum on the outstanding principal amount thereof, payable semi-annually on May 15 and November 15 of each year. As of March 31, 2021, $507.9 million principal amount remained outstanding. The 2025 Notes mature on May 15, 2025.

In October 2017, we issued $450.0 million in aggregate principal amount of our 2026 Notes. Interest on the 2026 Notes accrues at a rate of 6.375% per annum on the outstanding principal amount thereof, payable semi-annually on January 15 and July 15 of each year. As of March 31, 2021, $374.6 million principal amount remained outstanding. The 2026 Notes mature on January 15, 2026.

All amounts outstanding on our Senior Notes have been classified as liabilities subject to compromise on the accompanying consolidated balance sheets as of March 31, 2021 and December 31, 2020.

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Building Loan. On June 4, 2015, we entered into a loan for the construction of our corporate headquarters in Oklahoma City, which was substantially completed in December 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum. The building loan matures on June 4, 2025. As of March 31, 2021, the total borrowings under the building loan were approximately $21.9 million, which has been classified as liabilities subject to compromise on the accompanying consolidated balance sheets as of March 31, 2021.

Supplemental Guarantor Financial Information. The 2023 Notes, 2024 Notes, 2025 Notes and 2026 Notes are guaranteed on a senior unsecured basis by all existing consolidated subsidiaries that guarantee our secured revolving credit facility or certain other debt (the “Guarantors”). The Senior Notes are not guaranteed by Grizzly Holdings or Mule Sky, LLC (the “Non-Guarantors”). The Guarantors are 100% owned by 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 guarantees rank equally in the right of payment with all of the senior indebtedness of the subsidiary guarantors and senior in the right of payment to any future subordinated indebtedness of the subsidiary guarantors. The Senior Notes and the guarantees are effectively subordinated to all of our and the subsidiary guarantors' secured indebtedness (including all borrowings and other obligations under our amended and restated credit agreement) to the extent of the value of the collateral securing such indebtedness, and structurally subordinated to all indebtedness and other liabilities of any of our subsidiaries that do not guarantee the Notes.

SEC Regulation S-X Rule 13-01 requires the presentation of "Summarized Financial Information" to replace the "Condensed Consolidating Financial Information" required under Rule 3-10. Rule 13-01 allows the omission of Summarized Financial Information if assets, liabilities and results of operations of the Guarantors are not materially different than the corresponding amounts presented in our consolidated financial statements. The Parent and Guarantor subsidiaries comprise our material operations. Therefore, we concluded that the presentation of the Summarized Financial Information is not required as our Summarized Financial Information of the Guarantors is not materially different from our consolidated financial statements.

Derivatives and Hedging Activities. Our results of operations and cash flows are impacted by changes in market prices for natural gas, oil and NGL. To mitigate a portion of the exposure to adverse market changes, we have entered into various derivative instruments. Our natural gas, oil and NGL derivative activities, when combined with our sales of natural gas, oil and NGL, allow us to predict with greater certainty the total revenue we will receive.

As of March 31, 2021, we had the following open natural gas, oil and NGL derivative instruments:


Natural Gas Derivatives
Year	Type of Derivative Instrument	Index	Daily Volume (MMBtu/day)	Weighted Average Price ($)
2021	Swaps	NYMEX Henry Hub	351,316	$	2.73
2021	Basis Swaps	Tetco M2	32,384	$	(0.63)
2021	Basis Swaps	Rex Zone 3	85,309	$	(0.22)
2022	Basis Swaps	Rex Zone 3	14,795	$	(0.10)
2021	Costless Collars	NYMEX Henry Hub	390,509	$2.54/$2.93
2022	Costless Collars	NYMEX Henry Hub	186,438	$2.63/$3.04
2022	Sold Call Options	NYMEX Henry Hub	152,675	$	2.90
2023	Sold Call Options	NYMEX Henry Hub	627,675	$	2.90
Oil Derivatives
Year	Type of Derivative Instrument	Index	Daily Volume (Bbl/day)	Weighted Average Price ($)
2021	Swaps	NYMEX WTI	1,505	$	53.07
NGL Derivatives
Year	Type of Derivative Instrument	Index	Daily Volume (Bbl/day)	Weighted Average Price ($)
2021	Swaps	Mont Belvieu C3	2,074	$	27.80
2022	Swaps	Mont Belvieu C3	496	$	27.30

See Note 9 of the notes to our consolidated financial statements for further discussion of derivatives and hedging activities.

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Capital Expenditures. Our capital expenditures have historically been primarily related to the execution of our drilling and completion activities in addition to certain lease and other acquisition activities. Our capital investment strategy is focused on prudently developing our existing properties to generate sustainable cash flow considering current and forecasted commodity prices.

We continually monitor market conditions and are prepared to adjust our drilling program if commodity prices dictate. We believe our cash flow from operations, borrowing capacity under the DIP Credit Facility and cash on hand will provide sufficient liquidity during the Chapter 11 process. We expect to incur significant costs associated with our ongoing Chapter 11 Cases in 2021, including fees for legal, financial and restructuring advisors to the Company, certain of our creditors and royalty interest owners. Therefore, our ability to obtain confirmation of the Plan in a timely manner is critical to ensuring our liquidity is sufficient during the bankruptcy process.

Cash Flow from Operating Activities. Net cash flow provided by operating activities was $123.2 million for the three months ended March 31, 2021 as compared to $130.8 million for the same period in 2020. This decrease was primarily the result of working capital changes.

Uses of Funds. The following table presents the uses of our cash and cash equivalents for the three months ended March 31, 2021 and 2020:


	Three months ended March 31,
	2021		2020
	(In thousands)
Oil and Natural Gas Property Cash Expenditures:
Drilling and completion costs	$	51,702	$	97,538
Leasehold acquisitions	2,354		7,346
Other	2,839		8,860
Total oil and natural gas property expenditures	$	56,895	$	113,744
Other Uses of Cash and Cash Equivalents
Cash paid to repurchase senior notes	$	—	$	10,204
Principal payments on borrowings, net	—		55,106

Other	303		685
Total other uses of cash and cash equivalents	$	303	$	65,995
Total uses of cash and cash equivalents	$	57,198	$	179,739

Drilling and Completion Costs. During three months ended March 31, 2021, we spud nine gross (9.0 net) and commenced sales from seven gross and net operated wells in the Utica for a total cost of approximately $46.4 million. During the three months ended March 31, 2021, we did not spud any wells and commenced sales from three gross (2.7 net) operated wells in the SCOOP for a total cost of approximately $23.9 million.

During the three months ended March 31, 2021, we did not participate in any wells that were spud or turned to sales by other operators on our Utica acreage. In addition, three gross (0.001 net) wells were spud and 10 gross (1.86 net) wells were turned to sales by other operators on our SCOOP acreage during the three months ended March 31, 2021.

Drilling and completion costs presented in this section reflect incurred costs while drilling and completion costs presented above in Uses of Funds section reflect cash payments for drilling and completions.

Contractual and Commercial Obligations

We have various contractual obligations in the normal course of our operations and financing activities. See Note 8 of the notes to our consolidated financial statements for further discussion of the amendments to our firm gathering and transportation agreements. There have been no other material changes to our contractual obligations from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2020.

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Off-balance Sheet Arrangements

We may enter into off-balance sheet arrangements and transactions that can give rise to material off-balance sheet obligations. As of March 31, 2021, our material off-balance sheet arrangements and transactions include $121.2 million in letters of credit outstanding against our Pre-Petition Revolving Credit Facility, $28.5 million in letters of credit outstanding against our DIP Credit Facility and $110.9 million in surety bonds issued. Both the letters of credit and surety bonds are being used as financial assurance, primarily on certain firm transportation agreements. There are no other transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect our liquidity or availability of our capital resources. See Note 8 to our consolidated financial statements for further discussion of the various financial guarantees we have issued.

Critical Accounting Policies and Estimates

As of March 31, 2021, there have been no significant changes in our critical accounting policies from those disclosed in our 2020 Annual Report on Form 10-K.

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ITEM 3.			QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Natural Gas, Oil and Natural Gas Liquids Derivative Instruments. Our results of operations and cash flows are impacted by changes in market prices for natural gas, oil and NGL. To mitigate a portion of our exposure to adverse price changes, we have entered into various derivative instruments. Our natural gas, oil and NGL derivative activities, when combined with our sales of natural gas, oil and NGL, allow us to predict with greater certainty the revenue we will receive. We believe our derivative instruments continue to be highly effective in achieving our risk management objectives.

Our general strategy for protecting short-term cash flow and attempting to mitigate exposure to adverse natural gas, oil and NGL price changes is to hedge into strengthening natural gas, oil and NGL futures markets when prices reach levels that management believes provide reasonable rates of return on our invested capital. Information we consider in forming an opinion about future prices includes general economic conditions, industrial output levels and expectations, producer breakeven cost structures, liquefied natural gas trends, oil and natural gas storage inventory levels, industry decline rates for base production and weather trends. Executive management is involved in all risk management activities and the Board of Directors reviews our derivative program at its quarterly board meetings. We believe we have sufficient internal controls to prevent unauthorized trading.

We use derivative instruments to achieve our risk management objectives, including swaps, options and costless collars. All of these are described in more detail below. We typically use swaps for a large portion of the oil and natural gas price risk we hedge. We have also sold calls, taking advantage of premiums associated with market price volatility.

We determine the notional volume potentially subject to derivative contracts by reviewing our overall estimated future production levels, which are derived from extensive examination of existing producing reserve estimates and estimates of estimated production from new drilling. Production forecasts are updated at least monthly and adjusted if necessary to actual results and activity levels. We do not enter into derivative contracts for volumes in excess of our share of forecasted production, and if production estimates were lowered for future periods and derivative instruments are already executed for some volume above the new production forecasts, the positions are typically reversed. The actual fixed prices on our derivative instruments is derived from the reference prices from 3rd party indices such as NYMEX. All of our commodity derivative instruments are net settled based on the difference between the fixed price as stated in the contract and the floating-price, resulting in a net amount due to or from the counterparty.

We review our derivative positions continuously and if future market conditions change and prices are at levels we believe could jeopardize the effectiveness of a position, we will mitigate this risk by either negotiating a cash settlement with our counterparty, restructuring the position or entering a new trade that effectively reverses the current position. The factors we consider in closing or restructuring a position before the settlement date are identical to those we review when deciding to enter the original derivative position.

We have determined the fair value of our derivative instruments utilizing established index prices, volatility curves, discount factors and option pricing models. These estimates are compared to counterparty valuations for reasonableness. Derivative transactions are also subject to the risk that counterparties will be unable to meet their obligations. This non-performance risk is considered in the valuation of our derivative instruments, but to date has not had a material impact on the values of our derivatives. Future risk related to counterparties not being able to meet their obligations has been partially mitigated under our commodity hedging arrangements that require counterparties to post collateral if their obligations to us are in excess of defined thresholds. The values we report in our financial statements are as of a point in time and subsequently change as these estimates are revised to reflect actual results, changes in market conditions and other factors. See Note 9 of the notes to our consolidated financial statements for further discussion of the fair value measurements associated with our derivatives.

As of March 31, 2021, our natural gas, oil and NGL derivative instruments consisted of the following types of instruments:

•Swaps: We receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. In exchange for higher fixed prices on certain of our swap trades, we may sell call options.

•Basis Swaps: These instruments are arrangements that guarantee a fixed price differential to NYMEX from a specified delivery point. We receive the fixed price differential and pay the floating market price differential to the counterparty for the hedged commodity.

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•Call Options: We sell, and occasionally buy, call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess on sold call options, and we receive the excess on bought call options. If the market price settles below the fixed price of the call option, no payment is due from either party.

•Costless Collars: These instruments have a set floor and ceiling price for the hedged production. If the applicable monthly price indices are outside of the ranges set by the floor and ceiling prices in the various collars, we will cash-settle the difference with the counterparty.

To mitigate the effects of commodity price fluctuations on our oil and natural gas production, we had the following open fixed price swap positions at March 31, 2021:

Location

Daily Volume (MMBtu/day)

Weighted
Average Price

Remaining 2021

NYMEX Henry Hub

351,316

2.73

Location

Daily Volume
(Bbl/day)

Weighted
Average Price

Remaining 2021

NYMEX WTI

1,505

53.07


	Location	Daily Volume (Bbl/day)	Weighted Average Price
Remaining 2021	Mont Belvieu C2	2,074	$	27.80
2022	Mont Belvieu C3	496	$	27.30

In the second half of 2019, we sold 2022 and 2023 natural gas call options in exchange for a premium, and used the associated premiums to enhance the fixed price on certain natural gas swaps that settled in 2020. Each call option has an established ceiling price of $2.90/MMBtu. If monthly NYMEX natural gas prices settle above the $2.90 ceiling price, we are required to pay the option counterparty an amount equal to the difference between the referenced NYMEX natural gas settlement price and $2.90 multiplied by the hedged contract volumes. Below is a summary of our sold call option positions as of March 31, 2021.


	Location	Daily Volume (MMBtu/day)	Weighted Average Price

2022	NYMEX Henry Hub	152,675	$	2.90
2023	NYMEX Henry Hub	627,675	$	2.90

Below is a summary of our costless collar positions as of March 31, 2021.


	Location	Daily Volume (MMBtu/day)	Weighted Average Floor Price		Weighted Average Ceiling Price
2021	NYMEX Henry Hub	390,509	$	2.54	$	2.93
2022	NYMEX Henry Hub	186,438	$	2.63	$	3.04

Below is a summary of our basis swap positions as of March 31, 2021.


	Gulfport Pays	Gulfport Receives	Daily Volume (MMBtu/day)	Weighted Average Fixed Spread
Remaining 2021	Rex Zone 3	NYMEX Plus Fixed Spread	85,309	$	(0.22)
Remaining 2021	Tetco M2	NYMEX Plus Fixed Spread	32,384	$	(0.63)
2022	Rex Zone 3	NYMEX Plus Fixed Spread	14,795	$	(0.10)

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Our fixed price swap contracts are tied to the commodity prices on NYMEX Henry Hub for natural gas, NYMEX WTI for oil, and Mont Belvieu for propane, pentane and ethane. We will receive the fixed priced amount stated in the contract and pay to its counterparty the current market price as listed on the applicable index.

Our hedge arrangements may expose us to risk of financial loss in certain circumstances, including instances where production is less than expected or commodity prices increase. At March 31, 2021, we had a net liability derivative position of $50.9 million as compared to a net asset derivative position of $100.9 million as of March 31, 2020. Utilizing actual derivative contractual volumes, a 10% increase in underlying commodity prices would have reduced the fair value of these instruments by approximately $87.4 million, while a 10% decrease in underlying commodity prices would have increased the fair value of these instruments by approximately $80.0 million. However, any realized derivative gain or loss would be substantially offset by a decrease or increase, respectively, in the actual sales value of production covered by the derivative instrument.

Interest Rate Risk. Our revolving amended and restated credit agreement is structured under floating rate terms, as advances under this facility may be in the form of either base rate loans or eurodollar loans. As such, our interest expense is sensitive to fluctuations in the prime rates in the United States, or, if the eurodollar rates are elected, the eurodollar rates. At March 31, 2021, we had $316.8 million in borrowings outstanding under our Pre-Petition Revolving Credit Facility which bore interest at a weighted average rate of 3.12%. At March 31, 2021, we had $157.5 million in borrowings outstanding under our DIP Credit Facility which bore interest at a weighted average rate of 5.50%. As of March 31, 2021, we did not have any interest rate swaps to hedge interest rate risks.


ITEM 4.			CONTROLS AND PROCEDURES

Evaluation of Disclosure Control and Procedures. Under the direction of our Chief Executive Officer and President and our Chief Financial Officer, we have established disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. The disclosure controls and procedures are also intended to ensure that such information is accumulated and communicated to management, including our Chief Executive Officer and President and our Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosures.

As of March 31, 2021, an evaluation was performed under the supervision and with the participation of management, including our Chief Executive Officer and President and our Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) under the Exchange Act. Based upon our evaluation, our Chief Executive Officer and President and our Chief Financial Officer have concluded that, as of March 31, 2021, our disclosure controls and procedures are effective.

Changes in Internal Control over Financial Reporting. There have not been any changes in our internal control over financial reporting that occurred during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

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PART II


ITEM 1.			LEGAL PROCEEDINGS

The information with respect to this Item 1. Legal Proceedings is set forth in Note 8 in the accompanying condensed consolidated financial statements. Additionally, see Note 1 in the accompanying condensed consolidated financial statements for additional discussion of on-going claims and disputes in our Chapter 11 proceedings, certain of which may be material.


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 common stock or senior notes are described under "Risk Factors" in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2020.


ITEM 2.			UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Unregistered Sales of Equity Securities

None.

Issuer Repurchases of Equity Securities

Our common stock repurchase activity for the three months ended March 31, 2021 was as follows:


Period	Total number of shares purchased (1)	Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs
January	—	$	—	—
February	86,401	$	0.09	—
March	—	$	—	—
Total	86,401	$	0.09	—

(1)

During the three months ended March 31, 2021, we repurchased and canceled 86,401 shares of our common stock at a weighted average price of $0.09 to satisfy tax withholding requirements incurred upon the vesting of restricted stock unit awards.


ITEM 3.			DEFAULTS UPON SENIOR SECURITIES

Our Bankruptcy Filing described above constitutes an event of default that accelerated our obligations under our senior Pre-Petition Revolving Credit Facility and our Senior Notes. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against us as a result of an event of default. See Note 1 and Note 5 to the unaudited consolidated financial statements included in Part I, Item 1 of this Form 10-Q for additional details about the principal and interest amounts of debt included in liabilities subject to compromise on the accompanying unaudited consolidated balance sheet as of March 31, 2021 and our Bankruptcy Filing and the Chapter 11 Cases.


ITEM 4.			MINE SAFETY DISCLOSURES

Not applicable.

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ITEM 5.			OTHER INFORMATION

None.

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ITEM 6.			EXHIBITS


INDEX OF EXHIBITS
		Incorporated by Reference
Exhibit Number	Description	Form	SEC File Number	Exhibit	Filing Date	Filed or Furnished Herewith
2.1	Order (I) Confirming the Amended Joint Chapter 11 Plan of Reorganization of Gulfport Energy Corporation and its Debtor Subsidiaries and (II) Granting Related Relief.	8-K	001-19514	2.1	4/29/2021

2.2	Amended Joint Chapter 11 Plan of Reorganization of Gulfport Energy Corporation and its Debtor Subsidiaries, dated April 14, 2021.	8-K	001-19514	2.2	4/29/2021

3.1	Restated Certificate of Incorporation.	8-K	000-19514	3.1	4/26/2006

3.2	Certificate of Amendment No. 1 to Restated Certificate of Incorporation.	10-Q	000-19514	3.2	11/6/2009

3.3	Certificate of Amendment No. 2 to Restated Certificate of Incorporation.	8-K	000-19514	3.1	7/23/2013

3.4	Second Amended and Restated Bylaws of Gulfport Energy Corporation	8-K	000-19514	3.1	2/27/2020

3.5	First Amendment to the Second Amended and Restated Bylaws of Gulfport Energy Corporation	8-K	001-19514	3.1	5/29/2020

3.6	Certificate of Designation of Series B Junior Participating Preferred Stock of Gulfport Energy Corporation	8-A	001-19514	3.1	4/30/2020

4.1	Form of Common Stock certificate.	SB-2	333-115396	4.1	7/22/2004

4.2	Indenture, dated as of April 21, 2015, among the Company, the subsidiary guarantors party thereto and Wells Fargo Bank, N.A., as trustee (including the form of the Company’s 6.625% Senior Notes due 2023).	8-K	000-19514	4.1	4/21/2015

4.3	Indenture, dated as of October 14, 2016, among Gulfport Energy Corporation, the subsidiary guarantors party thereto and Wells Fargo Bank, N.A., as trustee (including the form of Gulfport Energy Corporation’s 6.000% Senior Notes due 2024).	8-K	000-19514	4.1	10/19/2016

4.4	Indenture, dated as of December 21, 2016, among Gulfport Energy Corporation, the subsidiary guarantors party thereto and Wells Fargo Bank, N.A., as trustee (including the form of Gulfport Energy Corporation’s 6.375% Senior Notes due 2025).	8-K	000-19514	4.1	12/21/2016

4.5	Indenture, dated as of October 11, 2017, among Gulfport Energy Corporation, the subsidiary guarantors party thereto and Wells Fargo Bank, N.A., as trustee (including the form of Gulfport Energy Corporation’s 6.375% Senior Notes due 2026).	8-K	000-19514	4.1	10/11/2017

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4.6

Tax Benefits Preservation Plan, dated as of April 30, 2020, between Gulfport Energy Corporation and Computershare Trust Company, N.A., as rights agent (which includes the Form of Rights Certificate as Exhibit B thereto)

8-A

001-19514

4.1

4/30/2020

31.1

Certification of Chief Executive Officer of the Registrant pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended.

31.2

Certification of Chief Financial Officer of the Registrant pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended.

32.1

Certification of Chief Executive Officer of the Registrant pursuant to Rule 13a-14(b) promulgated under the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code.

32.2

Certification of Chief Financial Officer of the Registrant pursuant to Rule 13a-14(b) promulgated under the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code.

101.INS

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101.SCH

XBRL Taxonomy Extension Schema Document.

101.CAL

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XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB

XBRL Taxonomy Extension Labels Linkbase Document.

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XBRL Taxonomy Extension Presentation Linkbase Document.

104

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SIGNATURES

In accordance with Section 13 or 15(d) of the Exchange Act, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: May 6, 2021


GULFPORT ENERGY CORPORATION

By:						/s/ Quentin Hicks
						Quentin Hicks Executive Vice President & Chief Financial Officer