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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 June 30, 2020
OR
TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF SECURITIES EXCHANGE ACT OF 1934
For the transition period from                      to                     
Commission File Number 000-19514
Gulfport Energy Corporation
(Exact Name of Registrant As Specified in Its Charter)
Delaware73-1521290
(State or Other Jurisdiction of Incorporation or Organization)(IRS Employer Identification Number)
3001 Quail Springs Parkway
Oklahoma City,Oklahoma73134
(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:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common stock, par value $0.01 per shareGPORNasdaq Global Select Market
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 July 31, 2020, 160,115,829 shares of the registrant’s common stock were outstanding.



GULFPORT ENERGY CORPORATION
TABLE OF CONTENTS
 
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Item 1.
Item 1A.
Item 2.
Item 3.
Item 4.
Item 5.
Item 6.

1



GULFPORT ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
June 30, 2020December 31, 2019
(Unaudited)
(In thousands, except share data)
Assets
Current assets:
Cash and cash equivalents$2,817  $6,060  
Accounts receivable—oil and natural gas sales65,645  121,210  
Accounts receivable—joint interest and other19,389  47,975  
Prepaid expenses and other current assets10,862  4,431  
Short-term derivative instruments53,188  126,201  
Total current assets151,901  305,877  
Property and equipment:
Oil and natural gas properties, full-cost accounting, $1,564,189 and $1,686,666 excluded from amortization in 2020 and 2019, respectively
10,730,992  10,595,735  
Other property and equipment96,838  96,719  
Accumulated depletion, depreciation, amortization and impairment(8,457,464) (7,228,660) 
Property and equipment, net2,370,366  3,463,794  
Other assets:
Equity investments 13,052  32,044  
Long-term derivative instruments4,298  563  
Deferred tax asset  7,563  
Operating lease assets3,640  14,168  
Operating lease assets—related parties  43,270  
Other assets37,000  15,540  
Total other assets57,990  113,148  
Total assets$2,580,257  $3,882,819  
Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable and accrued liabilities$315,575  $415,218  
Short-term derivative instruments8,540  303  
Current portion of operating lease liabilities3,356  13,826  
Current portion of operating lease liabilities—related parties  21,220  
Current maturities of long-term debt649  631  
Total current liabilities328,120  451,198  
Long-term derivative instruments45,615  53,135  
Asset retirement obligation61,371  60,355  
Uncertain tax position liability3,209  3,127  
Non-current operating lease liabilities284  342  
Non-current operating lease liabilities—related parties  22,050  
Long-term debt, net of current maturities1,910,318  1,978,020  
Total liabilities2,348,917  2,568,227  
Commitments and contingencies (Note 9)
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’ equity:
Common stock - $0.01 par value, 200.0 million shares authorized, 160.1 million issued and outstanding at June 30, 2020 and 159.7 million at December 31, 2019
1,601  1,597  
Paid-in capital4,211,062  4,207,554  
Accumulated other comprehensive loss(54,991) (46,833) 
Accumulated deficit(3,926,332) (2,847,726) 
Total stockholders’ equity231,340  1,314,592  
Total liabilities and stockholders’ equity$2,580,257  $3,882,819  

See accompanying notes to consolidated financial statements.
2

GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited) 
 Three months ended June 30,Six months ended June 30,
2020201920202019
(In thousands)
REVENUES:
Natural gas sales$86,797  $225,257  $195,344  $501,273  
Oil and condensate sales8,390  36,910  31,541  69,392  
Natural gas liquid sales10,252  25,687  27,165  57,812  
Net gain on natural gas, oil and NGL derivatives26,971  171,140  125,237  151,095  
Total Revenues132,410  458,994  379,287  779,572  
OPERATING EXPENSES:
Lease operating expenses15,686  22,388  31,672  42,195  
Production taxes3,605  8,098  8,404  16,019  
Midstream gathering and processing expenses59,974  72,015  117,870  142,297  
Depreciation, depletion and amortization64,790  124,951  142,818  243,384  
Impairment of oil and natural gas properties532,880    1,086,225    
General and administrative expenses10,470  11,727  26,639  21,784  
Accretion expense755  1,359  1,496  2,426  
Total Operating Expenses688,160  240,538  1,415,124  468,105  
(LOSS) INCOME FROM OPERATIONS(555,750) 218,456  (1,035,837) 311,467  
OTHER EXPENSE (INCOME):
Interest expense32,366  36,418  65,356  72,039  
Interest income(78) (159) (230) (311) 
Gain on debt extinguishment(34,257)   (49,579)   
Loss from equity method investments, net45  125,582  10,834  121,309  
Other expense7,242  990  9,098  563  
Total Other Expense5,318  162,831  35,479  193,600  
(LOSS) INCOME BEFORE INCOME TAXES(561,068) 55,625  (1,071,316) 117,867  
Income Tax Expense (Benefit)  (179,331) 7,290  (179,331) 
NET (LOSS) INCOME $(561,068) $234,956  $(1,078,606) $297,198  
NET (LOSS) INCOME PER COMMON SHARE:
Basic$(3.51) $1.47  $(6.75) $1.85  
Diluted$(3.51) $1.47  $(6.75) $1.84  
Weighted average common shares outstanding—Basic159,934  159,325  159,847  161,065  
Weighted average common shares outstanding—Diluted159,934  159,507  159,847  161,590  

See accompanying notes to consolidated financial statements.

3

GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME
(Unaudited)
 Three months ended June 30,Six months ended June 30,
2020201920202019
(In thousands)
Net (loss) income $(561,068) $234,956  $(1,078,606) $297,198  
Foreign currency translation adjustment6,872  3,610  (8,158) 7,411  
Other comprehensive income (loss)6,872  3,610  (8,158) 7,411  
Comprehensive (loss) income $(554,196) $238,566  $(1,086,764) $304,609  

See accompanying notes to consolidated financial statements.

4

GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(Unaudited)

Paid-in
Capital
Accumulated
Other
Comprehensive (Loss) Income
Accumulated
Deficit
Total
Stockholders’
Equity
Common Stock
 SharesAmount
(In thousands)
Balance at January 1, 2020159,711  $1,597  $4,207,554  $(46,833) $(2,847,726) $1,314,592  
Net Loss—  —  —  —  (517,538) (517,538) 
Other Comprehensive Loss—  —  —  (15,030) —  (15,030) 
Stock Compensation—  —  2,104  —  —  2,104  
Shares Repurchased(80) (1) (78) —  —  (79) 
Issuance of Restricted Stock211  2  (2) —  —    
Balance at March 31, 2020159,842  $1,598  $4,209,578  $(61,863) $(3,365,264) $784,049  
Net Loss—  —  —  —  (561,068) (561,068) 
Other Comprehensive Income—  —  —  6,872  —  6,872  
Stock Compensation—  —  1,515  —  —  1,515  
Shares Repurchased(27) —  (28) —  —  (28) 
Issuance of Restricted Stock301  3  (3) —  —    
Balance at June 30, 2020160,116  $1,601  $4,211,062  $(54,991) $(3,926,332) $231,340  


Paid-in
Capital
Accumulated
Other
Comprehensive (Loss) Income
Accumulated
Deficit
Total
Stockholders’
Equity
Common Stock
 SharesAmount
(In thousands)
Balance at January 1, 2019162,986  $1,630  $4,227,532  $(56,026) $(845,368) $3,327,768  
Net Income—  —  —  —  62,242  62,242  
Other Comprehensive Income—  —  —  3,801  —  3,801  
Stock Compensation—  —  2,785  —  —  2,785  
Shares Repurchased(3,619) (37) (28,293) —  —  (28,330) 
Issuance of Restricted Stock55  1  (1) —  —    
Balance at March 31, 2019159,422  $1,594  $4,202,023  $(52,225) $(783,126) $3,368,266  
Net Income—  —  —  —  234,956  234,956  
Other Comprehensive Income—  —  —  3,610  —  3,610  
Stock Compensation—  —  2,846  —  —  2,846  
Shares Repurchased(297) (3) (2,267) —  —  (2,270) 
Issuance of Restricted Stock271  3  (3) —  —    
Balance at June 30, 2019159,396  $1,594  $4,202,599  $(48,615) $(548,170) $3,607,408  

See accompanying notes to consolidated financial statements.
5

GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
 Six months ended June 30,
20202019
(In thousands)
Cash flows from operating activities:
Net (loss) income $(1,078,606) $297,198  
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depletion, depreciation and amortization142,818  243,384  
Impairment of oil and natural gas properties1,086,225    
Loss (income) from equity investments10,834  121,449  
Gain on debt extinguishment(49,579)   
Net gain on derivative instruments(125,237) (151,095) 
Net cash receipts (payments) on settled derivative instruments195,232  (1,494) 
Deferred income tax expense7,290  (179,331) 
Other, net9,844  11,341  
Changes in operating assets and liabilities:
Decrease in accounts receivable—oil and natural gas sales55,565  78,525  
Decrease (increase) in accounts receivable—joint interest and other29,159  (24,148) 
(Decrease) increase in accounts payable and accrued liabilities(30,620) 3,220  
Other, net(5,703) 720  
Net cash provided by operating activities247,222  399,769  
Cash flows from investing activities:
Additions to oil and natural gas properties(274,851) (508,315) 
Proceeds from sale of oil and natural gas properties45,185  745  
Additions to other property and equipment(575) (4,298) 
Proceeds from sale of other property and equipment151  130  
Contributions to equity method investments  (432) 
Distributions from equity method investments  1,945  
Net cash used in investing activities(230,090) (510,225) 
Cash flows from financing activities:
Principal payments on borrowings(323,322) (345,350) 
Borrowings on line of credit326,000  455,000  
Repurchases of senior notes(22,827)   
Payments for repurchases of stock under approved stock repurchase program  (30,000) 
Other, net(226) (714) 
Net cash (used in) provided by financing activities(20,375) 78,936  
Net decrease in cash, cash equivalents and restricted cash(3,243) (31,520) 
Cash, cash equivalents and restricted cash at beginning of period6,060  52,297  
Cash, cash equivalents and restricted cash at end of period$2,817  $20,777  
Supplemental disclosure of cash flow information:
Interest payments$60,523  $67,472  
Income tax receipts$  $(1,794) 
Supplemental disclosure of non-cash transactions:
Capitalized stock-based compensation$1,891  $2,252  
Asset retirement obligation capitalized$1,553  $6,230  
Asset retirement obligation removed due to divestiture$(2,033) $  
Interest capitalized$710  $1,771  
Fair value of contingent consideration asset on date of divestiture$23,090  $  
Foreign currency translation (loss) gain on equity method investments$(8,158) $7,411  
 See accompanying notes to consolidated financial statements.
6

GULFPORT ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

1.BASIS OF PRESENTATION, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES 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 and six months ended June 30, 2020 are not necessarily indicative of the results expected for the full year.
COVID-19
In March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic and recommended containment and mitigation measures worldwide. The measures have led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world have imposed regulations in efforts to control the spread of COVID-19 such as shelter-in-place orders, quarantines, executive orders and similar restrictions.
Gulfport remains focused on protecting the health and well-being of its employees and the communities in which it operates while assuring the continuity of its business operations. The Company implemented preventative measures and developed corporate and field response plans to minimize unnecessary risk of exposure and prevent infection. Additionally, the Company has a crisis management team for health, safety and environmental matters and personnel issues, and has established a COVID-19 Response Team to address various impacts of the situation, as they have been developing. Gulfport has modified certain business practices (including remote working for its corporate employees and restricted employee business travel) to conform to government restrictions and best practices encouraged by the Centers for Disease Control and Prevention, the World Health Organization and other governmental and regulatory authorities. In May 2020, the Company began its phased transition back to the office for its corporate employees. As part of this transition, the Company put into place preventative measures to focus on social distancing and minimizing unnecessary risk of exposure. As of the date of this filing, Gulfport has transitioned approximately 60% of its corporate employees back to the corporate office. The Company will continue to monitor trends and governmental guidelines and may adjust its return to office plans accordingly to ensure the health and safety of its employees. As a result of its business continuity measures, the Company has not experienced significant disruptions in executing its business operations in 2020.
Gulfport is closely monitoring the impact of COVID-19 on all aspects of its business and the current commodity price environment and is unable to predict the impact it will have on its future financial position or operating results. In response to the current commodity price environment, the Company voluntarily shut-in a portion of its production during the second quarter of 2020 and announced tiered salary reduction for most employees, senior management team and the Board of Directors beginning in June 2020 with such measures expected to last through December 2020. Additionally, select furloughs were implemented to reduce costs and preserve liquidity.
On March 27, 2020, the U.S. government enacted the Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”). The CARES Act did not have a material impact on the Company’s consolidated financial statements.
Liquidity, Management's Plans and Going Concern
As noted above, decreased demand for oil and natural gas as a result of the COVID-19 pandemic and the accompanying decrease in commodity prices has significantly impaired the Company's ability to access capital markets and to refinance its
7

existing indebtedness. Further, these conditions have made amendments or waivers to its revolving credit facility more difficult to obtain and available on terms less favorable to the Company. If depressed commodity prices persist or decline further, the borrowing base under the Company's revolving credit facility could be further reduced at its next scheduled redetermination date in November 2020. Any such reduction would constrain the Company's liquidity and may impair its ability to fund its planned capital expenditures and meet its obligations under its existing indebtedness. Further, a reduction in the Company's capital expenditures would decrease its production, revenues, operating cash flow and EBITDA, which could limit its ability to comply with the restrictive covenants in its revolving credit facility and other existing indebtedness. Finally, the Company's existing revolving credit facility matures in December 2021 and therefore will become a current liability at year end 2020 unless the Company is able to refinance the credit facility with a new credit facility or other financing. Considering the current state of the first lien market and the Company's elevated leverage profile, there is substantial risk that a refinancing will not be available to the Company on reasonable terms. A current liability under the revolving credit facility at year end 2020 may result in a qualified audit opinion which could result in a default under the terms of the current revolving credit facility. As a result of these uncertainties and other factors, management has concluded that there is substantial doubt about the Company's ability to continue as a going concern. Failure to meet the Company's obligations under its existing indebtedness or failure to comply with any of its covenants, if not waived, would result in an event of default under such indebtedness and result in the potential acceleration of outstanding indebtedness thereunder and, with respect to the revolving credit facility, the potential foreclosure on the collateral securing such debt, and could cause a cross-default under its other outstanding indebtedness.

In the current depressed commodity price environment and period of economic uncertainty, the Company has taken various steps over the last several months to improve its balance sheet and preserve liquidity including (1) exercising capital discipline by reducing 2020 capital spending by 50% as compared to 2019, (2) focusing on operational efficiencies to reduce operating costs as evidenced by the recent reductions in Development and Completion costs per lateral foot, (3) reducing corporate general and administrative costs significantly, (4) and repurchasing unsecured notes at a deep discount.

Although management’s actions listed above have helped to improve our liquidity and leverage profile, continued macro headwinds including the depressed state of energy capital markets and the extraordinarily low commodity price environments present significant risks to the Company's ability to fund its operations going forward. Accordingly, management has determined there is substantial doubt about its ability to continue as a going concern over the next twelve months from the issuance of these financial statements. The Company has engaged financial and legal advisors to assist with the evaluation of a range of liability management alternatives. Additionally, the Company maintains an active dialogue with its senior lenders and bondholders regarding liability management alternatives to improve its balance sheet. There can be no assurances that the Company will be able to successfully complete a liability management transaction that materially improves the Company’s leverage profile or liquidity position.

The consolidated financial statements (i) have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities and other commitments in the normal course of business and (ii) do not include any adjustments to reflect the possible future effects of the uncertainty on the recoverability or classification of recorded asset amounts or the amounts or classifications of liabilities.

Impact on Previously Reported Results
During the third quarter of 2019, the Company identified that certain activities were misclassified between cash flows from operating activities and cash flows from investing activities. These activities had been included in accounts payable, accrued liabilities and other and presented as cash flows from operating activities while they should have been presented as additions to oil and natural gas properties in cash flows from investing activities.  The Company corrected the previously presented statements of cash flows for these additions and in doing so, for the six months ended June 30, 2019 contained herein, the consolidated statements of cash flows and the condensed consolidating statements of cash flows were adjusted to increase net cash flows provided by operating activities by $90.8 million with a corresponding increase in net cash flows used in investing activities. The Company has evaluated the effect of the previous presentation, both qualitatively and quantitatively, and concluded that it did not have a material impact on any previously filed annual or quarterly consolidated financial statements.
Recently Adopted Accounting Standards
On January 1, 2020, the Company adopted ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments, which replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses is based on relevant information about past events, including historical experience, current conditions and reasonable and supportable forecasts that affect the collectibility of the
8

reported amount. The Company adopted the new standard using the prospective transition method, and it did not have a material impact on the Company's consolidated financial statements and related disclosures.

2.PROPERTY AND EQUIPMENT
The major categories of property and equipment and related accumulated depletion, depreciation, amortization ("DD&A") and impairment as of June 30, 2020 and December 31, 2019 are as follows:
June 30, 2020December 31, 2019
(In thousands)
Oil and natural gas properties$10,730,992  $10,595,735  
Accumulated DD&A and impairment(8,415,756) (7,191,957) 
Oil and natural gas properties, net2,315,236  3,403,778  
Other depreciable property and equipment91,317  91,198  
Land5,521  5,521  
Accumulated DD&A(41,708) (36,703) 
Other property and equipment, net55,130  60,016  
Property and equipment, net$2,370,366  $3,463,794  

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 June 30, 2020, the net book value of the Company's oil and gas properties, less related deferred income taxes, was above the calculated ceiling primarily as a result of reduced commodity prices for the period leading up to June 30, 2020. As a result, the Company was required to record impairments of its oil and natural gas properties of $532.9 million and $1.1 billion for the three and six months ended June 30, 2020, respectively. No impairments were required for oil and natural gas properties for the three and six months ended June 30, 2019.
Based on prices for the last nine months and the short-term pricing outlook for the third quarter of 2020, the Company expects to recognize additional full cost impairments in the third quarter of 2020. The amount of any future impairments is difficult to predict as it depends on future commodity prices, production rates, proved reserves, evaluation of costs excluded from amortization, future development costs and production costs. Any future full cost impairments are not expected to have an impact to the Company's future cash flows or liquidity.
General and administrative costs capitalized to the full cost pool represent management’s estimate of costs incurred directly related to exploration and development activities such as geological and other costs associated with overseeing exploration and development activities. All general and administrative costs not directly associated with exploration and development activities are charged to expense as they are incurred. Capitalized general and administrative costs were approximately $8.2 million and $13.6 million for the three and six months ended June 30, 2020, respectively, and $8.8 million and $16.5 million for the three and six months ended June 30, 2019, respectively.
The average depletion rate per Mcfe, which is a function of capitalized costs, future development costs and the related underlying reserves in the periods presented, was $0.73 and $1.00 per Mcfe for the six months ended June 30, 2020 and 2019, respectively.
The following table summarizes the Company’s unevaluated properties excluded from amortization by area at June 30, 2020:
June 30, 2020
(In thousands)
Utica$874,886  
MidContinent687,169  
Other2,134  
$1,564,189  
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At December 31, 2019, approximately $1.7 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.
Asset Retirement Obligation
A reconciliation of the Company’s asset retirement obligation for the six months ended June 30, 2020 and 2019 is as follows:
June 30, 2020June 30, 2019
(In thousands)
Asset retirement obligation, beginning of period$60,355  $79,952  
Liabilities incurred1,553  5,153  
Liabilities settled  (117) 
Liabilities removed due to divestitures(2,033)   
Accretion expense1,496  2,426  
Revisions in estimated cash flows  1,077  
Asset retirement obligation as of end of period61,371  88,491  

3.DIVESTITURES
Sale of Water Infrastructure Assets
On January 2, 2020, the Company closed on the sale of its SCOOP water infrastructure assets to a third-party water service provider. The Company received $50.0 million in cash proceeds upon closing and has an opportunity to earn potential additional incentive payments over the next 15 years, subject to the Company's ability to meet certain thresholds which will be driven by, among other things, the Company's future development program and water production levels. The agreement contained no minimum volume commitments. The fair value of the contingent consideration as of the closing date was $23.1 million. The divested assets were included in the amortization base of the full cost pool and no gain or loss was recognized in the accompanying consolidated statements of operations as a result of the sale.

4.EQUITY INVESTMENTS
Investments accounted for by the equity method consist of the following as of June 30, 2020 and December 31, 2019:
Carrying value(Loss) income from equity method investments
Approximate ownership %June 30, 2020December 31, 2019Three months ended June 30,Six months ended June 30,
2020201920202019
(In thousands)
Investment in Grizzly Oil Sands ULC24.6 %$13,013  $21,000  $(45) $54  (188) $(339) 
Investment in Mammoth Energy Services, Inc.21.5 %  11,005    (127,581) (10,646) (123,055) 
Investment in Windsor Midstream LLC22.5 %39  39          
Investment in Tatex Thailand II, LLC23.5 %      1,945    2,085  
$13,052  $32,044  $(45) $(125,582) $(10,834) $(121,309) 
The tables below summarize financial information for the Company’s equity investments as of June 30, 2020 and December 31, 2019.
Summarized balance sheet information:
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June 30, 2020December 31, 2019
(In thousands)
Current assets$434,966  $421,326  
Noncurrent assets$1,107,221  $1,260,075  
Current liabilities$115,281  $132,569  
Noncurrent liabilities$172,478  $163,241  
Summarized results of operations: 
 Three months ended June 30,Six months ended June 30,
 2020201920202019
(In thousands)
Gross revenue$60,109  $179,114  $157,492  $443,958  
Net (loss) income$(14,922) $(4,072) $(99,953) $20,684  
Grizzly Oil Sands ULC
The Company, through its wholly owned subsidiary Grizzly Holdings Inc. (“Grizzly Holdings”), owns an approximate 24.6% interest in Grizzly Oil Sands ULC (“Grizzly”), a Canadian unlimited liability company. The remaining interest in Grizzly is owned by Grizzly Oil Sands Inc. As of June 30, 2020, 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 June 30, 2020 and 2019 and determined no impairment was required. The Company paid $0.4 million in cash calls during the six months ended June 30, 2019 prior to its election to cease funding further capital calls. Grizzly’s functional currency is the Canadian dollar. The Company’s investment in Grizzly increased by $6.9 million as a result of a foreign currency translation gain and decreased by $7.8 million as a result of a foreign currency translation loss for the three and six months ended June 30, 2020, respectively. The Company's investment in Grizzly was increased by $3.5 million and $7.3 million for the three and six months ended June 30, 2019, respectively, as a result of a foreign currency translation gain.
Mammoth Energy Services, Inc.
At June 30, 2020, 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 June 30, 2020 was $11.6 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 second quarter of 2020, the Company's 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 June 30, 2020.
The Company received no distributions from Mammoth Energy during the six months ended June 30, 2020 and distributions of $2.5 million during the six months ended June 30, 2019 as a result of $0.125 per share dividends in February 2019 and May 2019. The loss (income) from equity method investments presented in the table above reflects any intercompany profit eliminations.
Windsor Midstream LLC
At June 30, 2020, the Company held a 22.5% interest in Windsor Midstream LLC (“Midstream”), an entity controlled and managed by an unrelated third party. The Company received no distributions from Midstream during the six months ended June 30, 2020.
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Tatex Thailand II, LLC
The Company has an indirect ownership interest in Tatex Thailand II, LLC ("Tatex") and received no distributions and $2.1 million in distributions from Tatex during the six months ended June 30, 2020 and 2019, respectively. Tatex previously held an 8.5% interest in APICO, LLC (“APICO”), an international oil and gas exploration company, before selling its interest in June 2019. APICO has a reserve base located in Southeast Asia through its ownership of concessions covering approximately 108,000 acres which includes the Phu Horm Field.

5.LONG-TERM DEBT
Long-term debt consisted of the following items as of June 30, 2020 and December 31, 2019:
June 30, 2020December 31, 2019
(In thousands)
Revolving credit agreement(1)
$123,000  $120,000  
6.625% senior unsecured notes due 2023
324,583  329,467  
6.000% senior unsecured notes due 2024
579,568  603,428  
6.375% senior unsecured notes due 2025
507,870  529,525  
6.375% senior unsecured notes due 2026
374,617  397,529  
Net unamortized debt issuance costs(2)
(20,802) (23,751) 
Construction loan 22,131  22,453  
Less: current maturities of long term debt(649) (631) 
Debt reflected as long term$1,910,318  $1,978,020  
(1) The Company has entered into a senior secured revolving credit facility, as amended (the "revolving credit facility"), with The Bank of Nova Scotia, as the lead arranger and administrative agent and other lenders. The credit agreement provides for a maximum facility of $1.5 billion and matures on December 13, 2021. On May 1, 2020, the Company entered into the fifteenth amendment to the Amended and Restated Credit Agreement. As part of the amendment, the Company's borrowing base and elected commitment were reduced from $1.2 billion and $1.0 billion, respectively, to $700.0 million. Additionally, the amendment added a requirement to maintain a ratio of Net Secured Debt to EBITDAX (as defined under the revolving credit agreement) not exceeding 2.00 to 1.00, deferred the requirement to maintain a ratio of Net Funded Debt to EBITDAX of 4.00 to 1.00 until September 30, 2021 and added a limitation on the repurchase of unsecured notes, among other amendments.
On July 27, 2020, the Company entered into the sixteenth amendment to the Amended and Restated Credit Agreement. The sixteenth amendment allows for the Company to issue up to $750 million in second lien debt subject to certain conditions. See Note 16 for further information on this amendment.
As of June 30, 2020, $123.0 million was outstanding under the revolving credit facility and the total availability for future borrowings under this facility, after giving effect to an aggregate of $324.1 million letters of credit, was $252.9 million. The Company’s wholly owned subsidiaries have guaranteed the obligations of the Company under the revolving credit facility.
At June 30, 2020, amounts borrowed under the revolving credit facility bore interest at a weighted average rate of 2.44%.
The Company was in compliance with its financial covenants under the revolving credit facility at June 30, 2020.
(2) Loan issuance costs related to the 6.625% Senior Notes due 2023 (the "2023 Notes"), the 6.000% Senior Notes due 2024 (the "2024 Notes"), the 6.375% Senior Notes due 2025 (the "2025 Notes") and the 6.375% Senior Notes due 2026 (the "2026 Notes") (collectively the “Notes”) have been presented as a reduction to the principal amount of the Notes. At June 30, 2020, total unamortized debt issuance costs were $2.8 million for the 2023 Notes, $6.1 million for the 2024 Notes, $8.5 million for the 2025 Notes and $3.4 million for the 2026 Notes. In addition, loan commitment fee costs for the Company's construction loan agreement were $0.1 million at June 30, 2020.
The Company capitalized approximately $0.5 million and $0.7 million in interest expense to its unevaluated oil and natural gas properties during the three and six months ended June 30, 2020, respectively. The Company capitalized approximately $1.0
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million and $1.8 million in interest expense to its unevaluated oil and natural gas properties during the three and six months ended June 30, 2019, respectively.
Debt Repurchases
In 2019, the Company's Board of Directors authorized $200 million of cash to be used to repurchase its senior notes in the open market at discounted values to par. The Company used borrowings under its revolving credit facility to repurchase in the open market $47.5 million and $73.3 million aggregate principal amount of its outstanding Notes for $12.6 million and $22.8 million during the three and six months ended June 30, 2020, respectively. For the three months ended June 30, 2020, this included $4.9 million principal amount of the 2023 Notes, $16.3 million principal amount of the 2024 Notes, $13.5 million principal amount of the 2025 Notes, and $12.8 million principal amount of the 2026 Notes. The Company recognized a $34.3 million and $49.6 million gain on debt extinguishment, which included retirement of unamortized issuance costs and fees associated with the repurchased debt, during the three and six months ended June 30, 2020, respectively. This gain is included in gain on debt extinguishment in the accompanying consolidated statements of operations. As of May 1, 2020, further repurchases under this program are limited due to the agreements entered into under the fifteenth amendment to the Amended and Restated Credit Agreement of the Company's credit facility.
Fair Value of Debt
At June 30, 2020, 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 $930.2 million at June 30, 2020.

6.CHANGES IN CAPITALIZATION
Stock Repurchases
In January 2019, the Company's Board of Directors approved a stock repurchase program to acquire a portion of the Company's outstanding common stock within a 24-month period. The program was suspended in the fourth quarter of 2019, and the May 1, 2020 amendment to the Company's revolving credit facility prohibits further stock repurchases.
For the three and six months ended June 30, 2019, the Company repurchased 0.2 million and 3.8 million shares for a cost of approximately $1.8 million and $30.0 million, respectively, under this repurchase program.
Additionally, during the three and six months ended June 30, 2020, the Company repurchased approximately 27,000 and 107,000 shares, respectively, for a cost of $28 thousand and $0.1 million, respectively, to satisfy tax withholding requirements incurred upon the vesting of restricted stock. During the three and six months ended June 30, 2019, the Company repurchased approximately 72,000 and 87,000 shares, respectively, for a cost of $0.5 million and $0.6 million, respectively, to satisfy tax withholding requirements incurred upon the vesting of restricted stock. All repurchased shares have been canceled and returned to the status of authorized but unissued shares.

7.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 and six months ended June 30, 2020, the Company’s stock-based compensation cost was $2.2 million and $4.3 million, respectively, of which the Company capitalized $1.0 million and $1.9 million, respectively, relating to its exploration and development efforts. During the three and six months ended June 30, 2019, the Company’s stock-based compensation cost was $2.8 million and $5.6 million, respectively, of which the Company capitalized $1.1 million and $2.3 million, respectively, 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 six months ended June 30, 2020:
 
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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, 20204,098,318  $4.73  1,783,660  $2.96  
Granted1,985,452  0.67      
Vested(512,283) 7.19      
Forfeited(979,929) 3.82  (830,323) 1.98  
Unvested shares as of June 30, 20204,591,558  $3.00  953,337  $3.82  
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 June 30, 2020 related to restricted stock units was $9.4 million. The expense is expected to be recognized over a weighted average period of 1.75 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 June 30, 2020 related to performance vesting restricted shares was $2.2 million. The expense is expected to be recognized over a weighted average period of 1.78 years.
Cash Incentive Awards
On March 16, 2020, the Board of Directors of the Company approved the Company's 2020 Incentive Plan (the "2020 Incentive Plan"). The 2020 Incentive Plan provides for incentive compensation opportunities ("Incentive Awards") for select employees of the Company that are tied to the achievement of one or more performance goals relating to certain financial and operational metrics over a period of time. The earning of an Incentive Award and payout opportunity is contingent upon meeting the Incentive Award's applicable threshold performance levels. If such threshold performance levels are satisfied, the payout amount varies for performance above or below the pre-established target performance levels.
During the six months ended June 30, 2020, the Company awarded Incentive Awards to certain of its executive officers under the 2020 Incentive Plan. The cash amount of each award ultimately received is based on the attainment of certain financial, operational and total shareholder return performance targets and is subject to the recipient's continuous employment. Each Incentive Award is subject to a Performance Period of January 1, 2020 to December 31, 2020, and different vesting periods apply to separate one-third portions of each Incentive Award, with a different tranche vesting each on December 31, 2020, 2021, and 2022. The Incentive Awards are considered liability awards as the ultimate amount of the award is based, at least in part, on the price of the Company's shares, and as such, are remeasured to fair value at the end of each reporting period. The fair value of the Incentive Awards at June 30, 2020 was $3.0 million. Unrecognized compensation expense as of June 30, 2020 related to Incentive Awards was $2.4 million. The expense is expected to be recognized over a weighted average period of 1.62 years.

8.EARNINGS PER SHARE
Reconciliations of the components of basic and diluted net income per common share are presented in the tables below:
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Three months ended June 30,
 20202019
LossSharesPer
Share
IncomeSharesPer
Share
(In thousands, except share data)
Basic:
Net (loss) income $(561,068) 159,933,739  $(3.51) $234,956  159,324,909  $1.47  
Effect of dilutive securities:
Stock awards      181,917  
Diluted:
Net (loss) income$(561,068) 159,933,739  $(3.51) $234,956  159,506,826  $1.47  
Six months ended June 30,
20202019
LossSharesPer
Share
IncomeSharesPer
Share
(In thousands, except share data)
Basic:
Net (loss) income$(1,078,606) 159,846,981  $(6.75) $297,198  161,064,787  $1.85  
Effect of dilutive securities:
Stock options and awards      525,300  
Diluted:
Net (loss) income$(1,078,606) 159,846,981  $(6.75) $297,198  161,590,087  $1.84  

There were 1,281,773 and 1,610,572 shares of common stock that were considered anti-dilutive for the three and six months ended June 30, 2020, respectively. There were no potential shares of common stock that were considered anti-dilutive for the three and six months ended June 30, 2019.

9.COMMITMENTS AND CONTINGENCIES
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 proved reserves have generally been sufficient to satisfy its delivery commitments during the three most recent years, and it expects such reserves will continue to be the primary means of fulfilling its future commitments. However, where the Company's proved reserves are not sufficient to satisfy its delivery commitments, it can and may use spot market purchases to satisfy the commitments.
A summary of these commitments at June 30, 2020 are set forth in the table below:
(MMBtu per day)
Remaining 2020311,000  
2021192,000  
202270,000  
202317,000  
Total590,000
Future Firm Transportation Commitments
The Company has contractual commitments with pipeline carriers for future transportation of natural gas from the Company's production areas to downstream markets. Commitments related to future firm transportation agreements are not
15

recorded as obligations in the accompanying consolidated balance sheets; however, the costs associated with these commitments are reflected in the Company's estimates of proved reserves and future net revenues.
A summary of these commitments at June 30, 2020 are set forth in the table below:
Total MMBtu(In thousands)
Remaining 2020267,720,000  $138,495  
2021531,075,000  285,779  
2022531,075,000  286,616  
2023515,775,000  282,936  
2024489,490,000  265,558  
Thereafter3,767,959,000  2,160,634  
Total6,103,094,000  $3,420,018  
As of June 30, 2020, the Company had entered into firm transportation contracts to deliver approximately 1,455,000 MMBtu per day for the remainder of 2020 and 2021, respectively. Under these firm transportation contracts, the Company is obligated to deliver minimum daily volumes or pay fees for any deficiencies in deliveries. As a result of the reduced production from the Company's Utica Shale or SCOOP acreage due to decreased developmental activities, taking into consideration the current low commodity price environment, the Company expects that it will be unable to meet its obligations under the existing firm transportation contracts, resulting in fees, which may be significant and may have a material adverse effect on its operations.
Other Commitments
Effective October 1, 2014, the Company entered into a Sand Supply Agreement with Muskie Proppant LLC (“Muskie”), a subsidiary of Mammoth Energy and a related party. Pursuant to this agreement, as amended effective August 3, 2018, the Company agreed to purchase annual and monthly amounts of proppant sand subject to exceptions specified in the agreement at agreed pricing plus agreed costs and expenses through 2021. Failure by either Muskie or the Company to deliver or accept the minimum monthly amount results in damages calculated per ton based on the difference between the monthly obligation amount and the amount actually delivered or accepted, as applicable. The Company incurred $1.9 million and $3.8 million in non-utilization fees under this agreement during the three and six months ended June 30, 2020, respectively. The Company did not incur any non-utilization fees under this agreement during the three months ended June 30, 2019 and incurred $0.3 million of such fees during the six months ended June 30, 2019.
Future minimum commitments under this agreement at June 30, 2020 are:
(In thousands)
Remaining 2020$3,750  
20217,500  
Total$11,250  

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
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District of the State of Louisiana in the 15th Judicial District Court for the Parish of Vermilion on July 29, 2016 (together, the "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 July 2019, Pigeon Land Company, Inc., a successor in interest to certain of the Company’s legacy Louisiana properties, filed an action against the Company and many other oil and gas companies in the 16th Judicial District Court for the Parish of Iberia in Louisiana. The suit alleges negligence, strict liability and various violations of Louisiana statutes relating to property damage in connection with the historic development of the Company’s Louisiana properties and seeks unspecified damages (including punitive damages), an injunction to return the affected property to its original condition, and the payment of reasonable attorney fees and legal expenses and interest.
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.
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.
In June 2020, Sam L. Carter, derivatively on behalf of the Company, filed an action against certain of our current and former executive officers and directors in the United States District Court for the District of Delaware. The complaint alleges that the defendants breached their fiduciary duties to the Company in connection with certain alleged materially false and misleading statements regarding our business and operations in violation of the federal securities laws. The complaint seeks to recover unspecified damages from the defendants, the implementation of specified corporate governance reforms, reasonable attorneys’ and experts’ fees, costs and expenses, and such other relief as may be deemed just and proper.

In December 2019, 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, which the complaint calculates to be approximately $28.0 million as of June 2020 (such amount to increase each month), the payment of reasonable attorney fees and legal expenses and pre- and post-judgment interest as allowed, and such other and further relief which it may be justly entitled.
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
17

to six 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.
These cases are still in their early stages. As a result, the Company has not had the opportunity to evaluate the allegations made in the plaintiffs' complaints and intends to vigorously defend the suits.
SEC Investigation
The SEC has commenced an investigation with respect to certain actions by former Company management, including alleged improper personal use of Company assets, and potential violations by former management and the Company of the Sarbanes-Oxley Act of 2002 in connection with such actions. The Company has fully cooperated and intends to continue to cooperate fully with the SEC’s investigation. Although it is not possible to predict the ultimate resolution or financial liability with respect to this matter, the Company believes that the outcome of this matter will not have a material effect on the Company’s business, financial condition or results of operations.
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. They 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.
The Company received several Finding of Violation (“FOVs”) from the United States Environmental Protection Agency ("USEPA") alleging violations of the Clean Air Act at approximately 17 locations in Ohio. The first FOV for one site was dated December 11, 2013.  Two subsequent FOVs incorporated and expanded the scope on January 4, 2017 and April 15, 2019.  The Company has exchanged information with the USEPA and is engaged in discussions aimed at resolving the allegations. Resolution of the matter resulted in monetary sanctions of approximately $1.7 million.
In October 2018, the company submitted a Voluntary Disclosure document to the Oklahoma Department of Environmental Quality (ODEQ) stemming from improper air permitting at several sites in Midcon between 2014 and 2017. The sites were permitted by Vitruvian prior to the Company's purchase of those assets. The sites were permitted utilizing the “permit by rule” regulation but actually required Title V air permits. The Company has agreed in a draft Consent Order to obtain the proper permits and to pay the costs from not having the proper permits in place in the amount of $180,000 to the ODEQ. The Order received final approval at the ODEQ and is expected to be finalized in the third quarter of 2020.
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.
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10.DERIVATIVE INSTRUMENTS
Natural Gas, Oil and Natural Gas Liquids Derivative Instruments
The Company seeks to reduce its exposure to unfavorable changes in natural gas, oil and natural gas liquids ("NGL") prices, which are subject to significant and often volatile fluctuation, by entering into over-the-counter fixed price swaps, basis swaps, costless collars and various types of option contracts. These contracts allow the Company to predict with greater certainty the effective natural gas, oil and NGL prices to be received for hedged production and benefit operating cash flows and earnings when market prices are less than the fixed prices provided in the contracts. However, the Company will not benefit from market prices that are higher than the fixed prices in the contracts for hedged production.
Fixed price swaps are settled monthly based on differences between the fixed price specified in the contract and the referenced settlement price. When the referenced settlement price is less than the price specified in the contract, the Company receives an amount from the counterparty based on the price difference multiplied by the volume. Similarly, when the referenced settlement price exceeds the price specified in the contract, the Company pays the counterparty an amount based on the price difference multiplied by the volume. The prices contained in these fixed price swaps are based on the NYMEX Henry Hub for natural gas, 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 June 30, 2020. 
LocationDaily Volume
(MMBtu/day)
Weighted
Average Price
Remaining 2020NYMEX Henry Hub357,000  $2.86  
LocationDaily Volume
(Bbls/day)
Weighted
Average Price
Remaining 2020NYMEX WTI3,000  $35.49  
LocationDaily Volume
(Bbls/day)
Weighted
Average Price
Remaining 2020Mont Belvieu C31,500  $20.27  
The Company sold call options in exchange for a premium, and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps primarily for 2020 listed above. Each call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volumes.
LocationDaily Volume
(MMBtu/day)
Weighted Average Price
2022NYMEX Henry Hub628,000  $2.90  
2023NYMEX Henry Hub628,000  $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 counterparty.
LocationDaily Volume (MMBtu/day)Weighted Average Floor PriceWeighted Average Ceiling Price
2021NYMEX Henry Hub250,000  $2.46  $2.81  
In addition, the Company entered into natural gas basis swap positions. As of June 30, 2020, the Company had the following natural gas basis swap positions open:
Gulfport PaysGulfport ReceivesDaily Volume
(MMBtu/day)
Weighted Average Fixed Spread
Remaining 2020Transco Zone 4NYMEX Plus Fixed Spread60,000  $(0.05) 
Remaining 2020Fixed SpreadONEOK Minus NYMEX10,000  $(0.54) 
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During the three months ended June 30, 2020, we early terminated oil fixed price swaps which represented approximately 6,000 BBls of oil per day for the remainder of 2020. The early termination resulted in a cash settlement of $40.5 million.
Contingent Consideration Arrangement
The Company sold its non-core assets located in the West Cote Blanche Bay and Hackberry fields of Louisiana in July 2019. The sale price included the potential for the Company to receive contingent payments based on commodity prices exceeding specified thresholds over the two years following the closing date. This contingent consideration arrangement was determined to be an embedded derivative. See below for threshold and potential payment amounts.
Period
Threshold(1)
Payment to be received(2)
July 2020 - June 2021
Greater than or equal to $60.65
$150,000  
Between $52.62 - $60.65
Calculated Value(3)
Less than or equal to $52.62
$  
(1)Based on the "WTI NYMEX + Argus LLS Differential," as published by Argus Media.
(2)Payment will be assessed monthly from July 2020 through June 2021. If threshold is met, payment shall be received within five business days after the end of each calendar month.
(3)
If average daily price, as defined in (1), is greater than $52.62 but less than $60.65, payment received will be $150,000 multiplied by a fraction, the numerator of which is the amount determined by subtracting $52.62 from such average daily price, and the denominator of which is $8.03.
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 June 30, 2020 and December 31, 2019:
June 30, 2020December 31, 2019
(In thousands)
Commodity Contracts:
Short-term derivative asset$53,188  $125,383  
Long-term derivative asset4,298    
Short-term derivative liability(8,540) (303) 
Long-term derivative liability(45,615) (53,135) 
Total commodity derivative position$3,331  $71,945  
Contingent consideration arrangement:
Short-term derivative asset$—  $818  
Long-term derivative asset  563  
Total contingent consideration derivative position$  $1,381  
Total net asset derivative position$3,331  $73,326  
Gains and Losses
The following table presents the gain and loss recognized in net gain on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the three and six months ended June 30, 2020 and 2019.
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Net gain (loss) on derivative instruments
Three months ended June 30,Six months ended June 30,
2020201920202019
(In thousands)
Natural gas derivatives$35,689  $152,475  $81,542  $136,044  
Oil derivatives(7,937) 11,871  44,937  11,417  
NGL derivatives(781) 6,794  139  3,634  
Contingent consideration arrangement    (1,381)   
Total$26,971  $171,140  $125,237  $151,095  
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 June 30, 2020
Gross Assets (Liabilities)Gross Amounts
Presented in theSubject to MasterNet
Consolidated Balance SheetsNetting AgreementsAmount
(In thousands)
Derivative assets$57,486  $(48,761) $8,725  
Derivative liabilities$(54,155) $48,761  $(5,394) 
As of December 31, 2019
Gross Assets (Liabilities)Gross Amounts
Presented in theSubject to MasterNet
Consolidated Balance SheetsNetting AgreementsAmount
(In thousands)
Derivative assets$126,764  $(53,438) $73,326  
Derivative liabilities$(53,438) $53,438  $  
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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11.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.
The following tables summarize the Company’s financial and non-financial assets and liabilities by valuation level as of June 30, 2020 and December 31, 2019:
 June 30, 2020
Level 1Level 2Level 3
(In thousands)
Assets:
Derivative Instruments$  $57,486  $  
Liabilities:
Derivative Instruments $  $54,155  $  
 December 31, 2019
Level 1Level 2Level 3
(In thousands)
Assets:
Derivative Instruments$  $126,764  $  
Liabilities:
Derivative Instruments $  $53,438  $  

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.
As discussed in Note 3, the water infrastructure sale included a contingent consideration arrangement. As of June 30, 2020, the fair value of the contingent consideration was $19.8 million, of which $0.8 million is included in prepaid expenses and other assets and $19.0 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 a loss of $3.2 million and $3.0 million on changes in fair value of the contingent consideration during the three and six months ended June 30, 2020, respectively, which is included in other expense (income) in
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the accompanying consolidated statements of operations. Settlements under the contingent consideration arrangement totaled $0.3 million during the six months ended June 30, 2020.
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 2 for further discussion of the Company’s asset retirement obligations. Asset retirement obligations incurred during the six months ended June 30, 2020 were approximately $1.6 million.
Fair value of financial instruments
The carrying amounts on the accompanying consolidated balance sheet for cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, and current debt are carried at cost, which approximates market value due to their short-term nature. Long-term debt related to the Company's construction loan is carried at cost, which approximates market value based on the borrowing rates currently available to the Company with similar terms and maturities.
12.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.
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 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 $65.6 and $121.2 million as of June 30, 2020 and December 31, 2019, 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
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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 six months ended June 30, 2020, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.

13.LEASES
Nature of Leases
The Company has operating leases associated with drilling rig commitments, field offices and other equipment with remaining lease terms with contractual durations in excess of one year. Short-term leases that have an initial term of one year or less are not capitalized.
The Company has entered into a contract for a drilling rig with a third party to ensure rig availability. The Company has concluded its drilling rig contracts are operating leases as the assets are identifiable and the evaluation that the Company has the right to control the identified assets. The Company's drilling rig commitments are typically structured with an initial term of one to two years, and typically include renewal options at the end of the initial term. Due to the nature of the Company's drilling schedules and potential volatility in commodity prices, the Company is unable to determine at commencement with reasonable certainty if the renewal options will be exercised; therefore, renewal options are not considered in the lease term for drilling contracts. The operating lease liability associated with its rig commitment is based on the minimum contractual obligation, primarily standby rate, and does not include variable amounts based on actual activity in a given period. The Company has also entered into several drilling rig commitments with an initial term less than one year. The costs for these short-term rig commitments are included in the short-term lease cost for the period as shown below. Pursuant to the full cost method of accounting, these costs are capitalized as part of oil and natural gas properties on the accompanying consolidated balance sheets. A portion of these costs are borne by other interest owners.
Effective October 1, 2014, the Company entered into an Amended and Restated Master Services Agreement for pressure pumping services with Stingray Pressure Pumping LLC (“Stingray Pressure”), a subsidiary of Mammoth Energy and a related party. Pursuant to this agreement, as amended effective July 1, 2018, Stingray Pressure has agreed to provide hydraulic fracturing, stimulation and related completion and rework services to the Company through 2021 and the Company has agreed to pay Stingray Pressure a monthly service fee plus the associated costs of the services provided. As discussed further in Note 9, the Company has terminated the Master Services Agreement for pressure pumping with Stingray Pressure. As a result, in the first quarter of 2020, Gulfport has removed the related right of use assets and lease liabilities associated with the terminated contract.
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 June 30, 2020 were as follows:
(In thousands)
Remaining 2020$3,321  
2021129  
2022115  
202390  
202430  
Total lease payments$3,685  
Less: Imputed interest(45) 
Total$3,640  
Lease cost for the three and six months ended June 30, 2020 and 2019 consisted of the following:
Three months ended June 30,Six months ended June 30,
2020201920202019
(In thousands)
Operating lease cost$2,196  $7,748  $6,278  $16,284  
Operating lease cost—related party  5,610    11,220  
Variable lease cost235  531  460  960  
Variable lease cost—related party  28,158    59,611  
Short-term lease cost2,629  183  5,439  183  
Total lease cost(1)
$5,060  $42,230  $12,177  $88,258  
(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 six months ended June 30, 2020 and 2019 related to leases was as follows:
Six months ended June 30,
20202019
Cash paid for amounts included in the measurement of lease liabilities(In thousands)
     Operating cash flows from operating leases$72  $120  
     Investing cash flow from operating leases$7,727  $12,288  
     Investing cash flow from operating leases—related party$6,800  $43,925  
The weighted-average remaining lease term as of June 30, 2020 was 0.83 years. The weighted-average discount rate used to determine the operating lease liability as of June 30, 2020 was 2.47%.
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14.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 and six months ended June 30, 2020, the Company's estimated annual effective tax rate before discrete items remained near zero as a result of the valuation allowance on its deferred tax assets. During the first quarter of 2020, the Company recognized $7.3 million of income tax expense discretely in the quarter as a result of the sale of assets and a corresponding adjustment to the valuation allowance on remaining state net operating loss carryforwards.

The Company anticipates remaining in a net deferred tax position based on the analysis performed for three and six months ended June 30, 2020. The Company expects a full valuation allowance against its deferred tax assets based on its conclusion, considering all available evidence (both positive and negative), that it was more likely than not that the deferred tax assets would not 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 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.

On March 27, 2020, the CARES Act was enacted in response to the COVID-19 pandemic. The Act includes several significant provisions for corporations including allowing companies to carryback certain NOLs, increasing the amount of NOLs that corporations can use to offset income, and increasing the amount of deductible interest under section 163(j). The Company does not expect to be materially impacted by the CARES Act provision and does not anticipate the CARES Act to have a material effect on its ability to realized deferred tax assets.

The Company’s ability to utilize NOL carryforwards and other tax attributes to reduce future federal taxable income is subject to potential limitations under Internal Revenue Code Section 382 (“Section 382”) and its related tax regulations. The utilization of these attributes may be limited if certain ownership changes by 5% stockholders (as defined in Treasury regulations pursuant to Section 382) and the effects of stock issuances by the Company during any three-year period result in a cumulative change of more than 50% in the beneficial ownership of Gulfport. The Company updates its Section 382 analysis to determine if an ownership change has occurred at each reporting period. If it is determined that an ownership change has occurred under these rules, the Company would generally be subject to an annual limitation on the use of pre-ownership change NOL carryforwards and certain other losses and/or credits. In addition, certain future transactions regarding the Company's equity, including the cumulative effects of small transactions as well as transactions beyond the Company’s control, could cause an ownership change and therefore a potential limitation on the annual utilization of its deferred tax assets. On April 30, 2020, the board of directors of the Company adopted a tax benefits preservation plan in order to protect against a possible limitation on the Company’s ability to use its tax net operating losses and certain other tax benefits to reduce potential future U.S. federal income tax obligations. The Tax Benefits Preservation Plan is intended to prevent against such an ownership change by deterring any person or group from acquiring beneficial ownership of 4.9% or more of the Company’s securities.
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15.CONDENSED CONSOLIDATING FINANCIAL INFORMATION
The 2023 Notes, the 2024 Notes, the 2025 Notes and the 2026 Notes are guaranteed on a senior unsecured basis by all existing consolidated subsidiaries that guarantee the Company’s secured revolving credit facility or certain other debt (the “Guarantors”). The Notes are not guaranteed by Grizzly Holdings or Mule Sky LLC ("Mule Sky") (the “Non-Guarantors”). The Guarantors are 100% owned by Gulfport (the “Parent”), and the guarantees are full, unconditional, joint and several. There are no significant restrictions on the ability of the Parent or the Guarantors to obtain funds from each other in the form of a dividend or loan. Effective June 1, 2019, the Parent contributed interests in certain oil and gas assets and related liabilities to certain of the Guarantors.
The following condensed consolidating balance sheets, statements of operations, statements of comprehensive income and statements of cash flows are provided for the Parent, the Guarantors and the Non-Guarantors and include the consolidating adjustments and eliminations necessary to arrive at the information for the Company on a condensed consolidated basis. The information has been presented using the equity method of accounting for the Parent’s ownership of the Guarantors and the Non-Guarantors.

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CONDENSED CONSOLIDATING BALANCE SHEETS
(Amounts in thousands)
June 30, 2020
ParentGuarantorsNon-GuarantorsEliminationsConsolidated
Assets
Current assets:
Cash and cash equivalents$823  $1,748  $246  $  $2,817  
Accounts receivable - oil and natural gas sales860  64,785      65,645  
Accounts receivable - joint interest and other2,949  16,440      19,389  
Accounts receivable - intercompany1,482,102  1,150,631    (2,632,733)   
Prepaid expenses and other current assets10,781  5  76    10,862  
Short-term derivative instruments53,188        53,188  
Total current assets1,550,703  1,233,609  322  (2,632,733) 151,901  
Property and equipment:
Oil and natural gas properties, full-cost accounting1,247,631  9,478,228