COVER PAGE
COVER PAGE - shares | 3 Months Ended | |
Mar. 31, 2022 | Apr. 25, 2022 | |
Cover [Abstract] | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Mar. 31, 2022 | |
Document Transition Report | false | |
Entity File Number | 001-19514 | |
Entity Registrant Name | Gulfport Energy Corp | |
Entity Incorporation, State or Country Code | DE | |
Entity Tax Identification Number | 86-3684669 | |
Entity Address, Address Line One | 3001 Quail Springs Parkway | |
Entity Address, City or Town | Oklahoma City, | |
Entity Address, State or Province | OK | |
Entity Address, Postal Zip Code | 73134 | |
City Area Code | 405 | |
Local Phone Number | 252-4600 | |
Title of 12(b) Security | Common Stock, $0.0001 par value per share | |
Trading Symbol | GPOR | |
Security Exchange Name | NYSE | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding (in shares) | 20,933,661 | |
Amendment Flag | false | |
Entity Central Index Key | 0000874499 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | Q1 |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Current assets: | ||
Cash and cash equivalents | $ 5,898 | $ 3,260 |
Accounts receivable—oil and natural gas sales | 206,869 | 232,854 |
Accounts receivable—joint interest and other | 38,480 | 20,383 |
Prepaid expenses and other current assets | 5,348 | 12,359 |
Short-term derivative instruments | 15,720 | 4,695 |
Total current assets | 272,315 | 273,551 |
Property and equipment: | ||
Proved oil and natural gas properties | 2,030,289 | 1,917,833 |
Unproved properties | 203,678 | 211,007 |
Other property and equipment | 5,420 | 5,329 |
Total property and equipment | 2,239,387 | 2,134,169 |
Less: accumulated depletion, depreciation and amortization | (340,709) | (278,341) |
Total property and equipment, net | 1,898,678 | 1,855,828 |
Other assets: | ||
Long-term derivative instruments | 20,696 | 18,664 |
Operating lease assets | 274 | 322 |
Other assets | 19,557 | 19,867 |
Total other assets | 40,527 | 38,853 |
Total assets | 2,211,520 | 2,168,232 |
Current liabilities: | ||
Accounts payable and accrued liabilities | 398,067 | 394,011 |
Short-term derivative instruments | 820,255 | 240,735 |
Current portion of operating lease liabilities | 173 | 182 |
Total current liabilities | 1,218,495 | 634,928 |
Non-current liabilities: | ||
Long-term derivative instruments | 281,622 | 184,580 |
Total asset retirement obligation reflected as non-current liabilities | 28,972 | 28,264 |
Non-current operating lease liabilities | 100 | 140 |
Long-term debt | 573,996 | 712,946 |
Total non-current liabilities | 884,690 | 925,930 |
Total liabilities | 2,103,185 | 1,560,858 |
Commitments and contingencies (Note 7) | ||
Mezzanine Equity: | ||
Preferred stock - $0.0001 par value, 110.0 thousand shares authorized, 57.9 thousand issued and outstanding at March 31, 2022 and December 31, 2021 | 57,878 | 57,896 |
Stockholders’ Equity: | ||
Common stock - $0.0001 par value, 42.0 million shares authorized, 21.1 million issued and outstanding at March 31, 2022, and 20.6 million issued and outstanding at December 31, 2021 | 2 | 2 |
Additional paid-in capital | 662,573 | 692,521 |
Common stock held in reserve, 62 thousand shares at March 31, 2022, and 938 thousand shares at December 31, 2021 | (1,996) | (30,216) |
Accumulated deficit | (604,804) | (112,829) |
Treasury stock, at cost - 59.6 thousand at March 31, 2022, and no shares at December 31, 2021 | (5,318) | 0 |
Total stockholders’ equity | 50,457 | 549,478 |
Total liabilities, mezzanine equity and stockholders’ equity | $ 2,211,520 | $ 2,168,232 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares | Mar. 31, 2022 | Dec. 31, 2021 |
Statement of Financial Position [Abstract] | ||
Temporary equity, par or stated value (in usd per share) | $ 0.0001 | $ 0.0001 |
Temporary equity, shares authorized (in shares) | 110,000 | 110,000 |
Temporary equity, shares outstanding (in shares) | 57,878 | 57,896 |
Temporary equity, shares issued (in shares) | 57,900 | 57,900 |
Common stock, par value (in usd per share) | $ 0.0001 | |
Common stock, shares authorized (in shares) | 42,000,000 | |
Common stock, shares, issued (in shares) | 21,100,000 | 20,600,000 |
Common stock, shares, outstanding (in shares) | 21,100,000 | 20,600,000 |
Common stock, capital shares reserved for future issuance (in shares) | 62,000 | 938,000 |
Treasury stock shares (in shares) | 59,600 | 0 |
CONSOLIDATED STATEMENTS OF OPER
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
REVENUES: | ||
Net loss on natural gas, oil and NGL derivatives | $ (788,551) | $ (29,978) |
Total Revenues | (307,816) | 247,358 |
OPERATING EXPENSES: | ||
Lease operating expenses | 17,644 | 12,653 |
Taxes other than income | 12,468 | 8,704 |
Transportation, gathering, processing and compression | 84,792 | 105,867 |
Depreciation, depletion and amortization | 62,284 | 41,147 |
Impairment of other property and equipment | 0 | 14,568 |
General and administrative expenses | 7,105 | 12,757 |
Accretion expense | 692 | 805 |
Total Operating Expenses | 184,985 | 196,501 |
(LOSS) INCOME FROM OPERATIONS | (492,801) | 50,857 |
OTHER (INCOME) EXPENSE: | ||
Interest expense | 13,984 | 3,261 |
Loss from equity method investments, net | 0 | 342 |
Reorganization items, net | 0 | 38,721 |
Other, net | (14,810) | (247) |
Total Other (Income) Expense | (826) | 42,077 |
(LOSS) INCOME BEFORE INCOME TAXES | (491,975) | 8,780 |
Income tax expense | 0 | 0 |
NET (LOSS) INCOME | (491,975) | 8,780 |
Dividends on preferred stock | (1,447) | 0 |
NET (LOSS) INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS | $ (493,422) | $ 8,780 |
NET (LOSS) INCOME PER COMMON SHARE: | ||
Basic (in usd per share) | $ (23.23) | $ 0.05 |
Diluted (in usd per share) | $ (23.23) | $ 0.05 |
Weighted average common shares outstanding - Basic (in shares) | 21,242,000 | 160,813,000 |
Weighted average common shares outstanding - Diluted (in shares) | 21,242,000 | 160,813,000 |
Natural gas sales | ||
REVENUES: | ||
Revenue from contract with customer | $ 405,212 | $ 235,321 |
Oil and condensate sales | ||
REVENUES: | ||
Revenue from contract with customer | 30,239 | 18,239 |
Natural gas liquid sales | ||
REVENUES: | ||
Revenue from contract with customer | $ 45,284 | $ 23,776 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Statement of Comprehensive Income [Abstract] | ||
Net (loss) income | $ (491,975) | $ 8,780 |
Foreign currency translation adjustment | 0 | 2,570 |
Other comprehensive income | 0 | 2,570 |
Comprehensive (loss) income | $ (491,975) | $ 11,350 |
CONSOLIDATED STATEMENTS OF STOC
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (DEFICIT) - USD ($) $ in Thousands | Total | Common Stock | Common Stock Held in Reserve | Treasury Stock | Paid-in Capital | Accumulated Other Comprehensive (Loss) Income | Retained Earnings (Accumulated Deficit) |
Beginning balance (in shares) at Dec. 31, 2020 | 160,762,000 | 0 | |||||
Beginning balance at Dec. 31, 2020 | $ (300,500) | $ 1,607 | $ 0 | $ 0 | $ 4,213,752 | $ (43,000) | $ (4,472,859) |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||
Net income (loss) | 8,780 | 8,780 | |||||
Other comprehensive income | 2,570 | 2,570 | |||||
Stock compensation | 1,419 | 1,419 | |||||
Shares repurchased (in shares) | (86,000) | ||||||
Shares repurchased | (8) | $ (1) | (7) | ||||
Issuance of restricted stock (in shares) | 203,000 | ||||||
Issuance of restricted stock | 1 | $ 3 | (2) | ||||
Ending balance (in shares) at Mar. 31, 2021 | 160,878,000 | 0 | |||||
Ending balance at Mar. 31, 2021 | $ (287,738) | $ 1,609 | $ 0 | 0 | 4,215,162 | (40,430) | (4,464,079) |
Beginning balance (in shares) at Dec. 31, 2021 | 20,600,000 | 21,537,000 | (938,000) | ||||
Beginning balance at Dec. 31, 2021 | $ 549,478 | $ 2 | $ (30,216) | 0 | 692,521 | 0 | (112,829) |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||
Net income (loss) | (491,975) | (491,975) | |||||
Other comprehensive income | $ 0 | ||||||
Conversion of preferred stock (in shares) | 18 | 1,000 | |||||
Conversion of preferred stock | $ 18 | 18 | |||||
Stock compensation | 1,755 | 1,755 | |||||
Shares repurchased (in shares) | (378,000) | ||||||
Shares repurchased | (35,512) | (5,318) | (30,194) | ||||
Issuance of common stock held in reserve (in shares) | 876,000 | ||||||
Issuance of common stock held in reserve | 28,220 | $ 28,220 | |||||
Issuance of restricted stock (in shares) | 2,000 | ||||||
Issuance of restricted stock | (80) | (80) | |||||
Dividends on preferred stock | $ (1,447) | (1,447) | |||||
Ending balance (in shares) at Mar. 31, 2022 | 21,100,000 | 21,162,000 | (62,000) | ||||
Ending balance at Mar. 31, 2022 | $ 50,457 | $ 2 | $ (1,996) | $ (5,318) | $ 662,573 | $ 0 | $ (604,804) |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Cash flows from operating activities: | ||
Net (loss) income | $ (491,975) | $ 8,780 |
Adjustments to reconcile net loss to net cash provided by operating activities: | ||
Depletion, depreciation and amortization | 62,284 | 41,147 |
Impairment of other property and equipment | 0 | 14,568 |
Loss from equity investments | 0 | 342 |
Net loss on derivative instruments | 788,551 | 29,978 |
Net cash (payments) receipts on settled derivative instruments | (125,046) | 125 |
Other | 2,690 | 1,574 |
Changes in operating assets and liabilities, net | 17,192 | 26,661 |
Net cash provided by operating activities | 253,696 | 123,175 |
Cash flows from investing activities: | ||
Additions to oil and natural gas properties | (80,271) | (56,895) |
Proceeds from sale of oil and natural gas properties | 0 | 15 |
Other | (7) | (296) |
Net cash used in investing activities | (80,278) | (57,176) |
Cash flows from financing activities: | ||
Repurchase of common stock under Repurchase Program | (30,192) | 0 |
Dividends on preferred stock | (1,447) | 0 |
Other | (141) | (7) |
Net cash (used in) provided by financing activities | (170,780) | 23,841 |
Net increase in cash, cash equivalents and restricted cash | 2,638 | 89,840 |
Cash, cash equivalents and restricted cash at beginning of period | 3,260 | 89,861 |
Cash, cash equivalents and restricted cash at end of period | 5,898 | 179,701 |
Revolving Credit Facility | ||
Cash flows from financing activities: | ||
Principals payments on credit facility | 0 | (2,202) |
Borrowings on credit facility | 0 | 26,050 |
Credit Facility | ||
Cash flows from financing activities: | ||
Principals payments on credit facility | (456,000) | 0 |
Borrowings on credit facility | $ 317,000 | $ 0 |
BASIS OF PRESENTATION
BASIS OF PRESENTATION | 3 Months Ended |
Mar. 31, 2022 | |
Accounting Policies [Abstract] | |
BASIS OF PRESENTATION | BASIS OF PRESENTATION Description of Company Gulfport Energy Corporation (the "Company" or "Gulfport") is an independent natural gas-weighted exploration and production company focused on the production of natural gas, crude oil and NGL in the United States. The Company's principal properties are located in eastern Ohio targeting the Utica and in central Oklahoma targeting the SCOOP Woodford and SCOOP Springer formations. Gulfport filed for voluntary reorganization under Chapter 11 of the Bankruptcy Code on November 13, 2020, and subsequently operated as a debtor-in-possession, in accordance with applicable provisions of the Bankruptcy Code, until its emergence on May 17, 2021. The Company refers to the post-emergence reorganized organization in the condensed financial statements and footnotes as the "Successor" for periods subsequent to May 17, 2021, and the pre-emergence organization as "Predecessor" for periods on or prior to May 17, 2021. Basis of Presentation The accompanying unaudited condensed consolidated financial statements of Gulfport were prepared in accordance with GAAP and the rules and regulations of the SEC. This Quarterly Report on Form 10-Q (this “Form 10-Q”) relates to the financial position and periods as of and for the three months ended March 31, 2022 ("Successor Quarter") and the three months ended March 31, 2021 (“Predecessor Quarter”). The Company's annual report on Form 10-K for the year ended December 31, 2021 (“2021 Form 10-K”) should be read in conjunction with this Form 10-Q. The accompanying unaudited consolidated financial statements reflect all normal recurring adjustments which, in the opinion of management, are necessary for a fair statement of our condensed consolidated financial statements and accompanying notes and include the accounts of our wholly-owned subsidiaries. Intercompany accounts and balances have been eliminated. The accompanying consolidated financial statements have been prepared assuming the Company will continue as a going concern. Voluntary Reorganization Under Chapter 11 of the Bankruptcy Code In connection with the Company's emergence from bankruptcy and in accordance with ASC 852, the Company qualified for and applied fresh start accounting on the Emergence date. For further information on the Company’s reorganization value and the resulting fresh start adjustments made on the Emergence Date, refer to the “Fresh Start Accounting” footnote in the notes to the consolidated financial statements in Item 8 of the Company’s 2021 Form 10-K. Accounts Payable and Accrued Liabilities Accounts payable and accrued liabilities consisted of the following at March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Accounts payable and other accrued liabilities $ 183,786 $ 143,938 Revenue payable and suspense 173,285 180,857 Accrued contract rejection damages and shares held in reserve 40,996 69,216 Total accounts payable and accrued liabilities $ 398,067 $ 394,011 Reorganization Items, Net In the Predecessor Quarter, the Company incurred significant expenses related to its Chapter 11 filing. The amount of these items, which were incurred in reorganization items, net within the Company's accompanying consolidated statements of operations, significantly affected the Company's statements of operations. The Company also incurred adjustments for allowable claims related to its legal proceedings and executory contracts approved for rejection by the Bankruptcy Court. The following table summarizes the components in reorganization items, net included in the Company's consolidated statements of operations for the Predecessor Quarter (in thousands): Predecessor Three Months Ended March 31, 2021 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 Other Income Other, net included in the Company's consolidated statements of operations for the Successor Quarter included $11.5 million related to the TC claim distribution received as discussed in Note 7 . Supplemental Cash Flow and Non-Cash Information (in thousands) Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Supplemental disclosure of cash flow information: Cash paid for reorganization items, net $ — $ 21,367 Interest payments $ 2,110 $ 4,763 Changes in operating assets and liabilities: Decrease (increase) in accounts receivable - oil and natural gas sales $ 25,985 $ (14,117) Increase in accounts receivable - joint interest and other (17,722) (478) Increase in accounts payable and accrued liabilities 2,135 15,555 Decrease in prepaid expenses 6,811 26,356 Increase in other assets (17) (655) Total changes in operating assets and liabilities $ 17,192 $ 26,661 Supplemental disclosure of non-cash transactions: Capitalized stock-based compensation $ 597 $ 630 Asset retirement obligation capitalized $ 16 $ 483 Release of common stock held in reserve $ 28,220 $ — Foreign currency translation gain on equity method investments $ — $ 2,570 |
PROPERTY AND EQUIPMENT
PROPERTY AND EQUIPMENT | 3 Months Ended |
Mar. 31, 2022 | |
Property, Plant and Equipment [Abstract] | |
PROPERTY AND EQUIPMENT | PROPERTY AND EQUIPMENT The major categories of property and equipment and related accumulated DD&A and impairment as of March 31, 2022 and December 31, 2021 are as follows (in thousands): Successor March 31, 2022 December 31, 2021 Proved oil and natural gas properties $ 2,030,289 $ 1,917,833 Unproved properties 203,678 211,007 Other depreciable property and equipment 5,034 4,943 Land 386 386 Total property and equipment 2,239,387 2,134,169 Accumulated DD&A and impairment (340,709) (278,341) Property and equipment, net $ 1,898,678 $ 1,855,828 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, 2022, 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, 2022. As a result, the Company did not record an impairment of its oil and natural gas properties for the Successor Quarter. The Company did not record impairment of its oil and natural gas properties for the Predecessor Quarter. 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 $4.7 million and $5.5 million for the Successor Quarter and Predecessor Quarter, respectively. 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. The following table summarizes the Company’s non-producing properties excluded from amortization by area as of March 31, 2022: Successor March 31, 2022 (In thousands) Utica $ 168,809 SCOOP 34,865 Other 4 Total unproved properties $ 203,678 Asset Retirement Obligation The following table provides a reconciliation of the Company’s asset retirement obligation for the Successor and Predecessor Quarters (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Asset retirement obligation, beginning of period $ 28,264 $ 63,566 Liabilities incurred 16 483 Accretion expense 692 805 Total asset retirement obligation as of end of period $ 28,972 $ 64,854 Less: amounts reclassified to liabilities subject to compromise $ — $ (64,854) Total asset retirement obligation reflected as non-current liabilities $ 28,972 $ — |
LONG-TERM DEBT
LONG-TERM DEBT | 3 Months Ended |
Mar. 31, 2022 | |
Long-term Debt, Unclassified [Abstract] | |
LONG-TERM DEBT | DEBT Debt consisted of the following items as of March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Credit Facility $ 25,000 $ 164,000 8.000% senior unsecured notes due 2026 550,000 550,000 Net unamortized debt issuance costs (1,004) (1,054) Total debt, net 573,996 712,946 Less: current maturities of long-term debt — — Total long-term debt, net $ 573,996 $ 712,946 Credit Facility On October 14, 2021, the Company entered into the Third Amended and Restated Credit Agreement with JPMorgan Chase Bank, N.A., as administrative agent, and various lender parties ("Credit Facility"). The Credit Facility provides for an aggregate maximum principal amount of up to $1.5 billion, an initial borrowing base of $850.0 million and an initial aggregate elected commitment amount of $700.0 million. The credit agreement also provides for a $175.0 million sublimit of the aggregate commitments that is available for the issuance of letters of credit. The Credit Facility matures October 14, 2025. As of March 31, 2022, the Company had $25.0 million outstanding borrowings under the Credit Facility and $113.2 million in letters of credit outstanding. As of March 31, 2022, the Company was in compliance with all covenants under the Credit Facility. The Credit Facility bears interest at a rate equal to, at the Company’s election, either (a) LIBOR plus an applicable margin that varies from 2.75% to 3.75% per annum or (b) a base rate plus an applicable margin that varies from 1.75% to 2.75% per annum, based on borrowing base utilization. The Company is required to pay a commitment fee of 0.50% per annum on the average daily unused portion of the current aggregate commitments under the Credit Facility. The Company is also required to pay customary letter of credit and fronting fees. The borrowing base will be redetermined semiannually on or around May 1 and November 1 of each year, with the first scheduled redetermination to be on or around May 1, 2022. On May 2, 2022, the Company completed its semi-annual borrowing base redetermination as discussed in Note 13 . As of March 31, 2022, the Credit Facility bore interest at a weighted average rate of 3.21%. The credit agreement requires the Company to maintain as of the last day of each fiscal quarter (i) a net funded leverage ratio of less than or equal to 3.25 to 1.00, and (ii) a current ratio of greater than or equal to 1.00 to 1.00. The obligations under the Credit Facility, certain swap obligations and certain cash management obligations, are guaranteed by the Company and the wholly-owned domestic material subsidiaries of the Borrower (collectively, the “Guarantors” and, together with the Borrower, the “Loan Parties”) and secured by substantially all of the Loan Parties’ assets (subject to customary exceptions). The credit agreement also contains customary affirmative and negative covenants, including, among other things, as to compliance with laws (including environmental laws and anti-corruption laws), delivery of quarterly and annual financial statements and borrowing base certificates, conduct of business, maintenance of property, maintenance of insurance, entry into certain derivatives contracts, restrictions on the incurrence of liens, indebtedness, asset dispositions, restricted payments, and other customary covenants. These covenants are subject to a number of limitations and exceptions. 2026 Senior Notes On the Emergence Date, pursuant to the terms of the Plan, the Company issued $550 million aggregate principal amount of its 8.000% senior notes due 2026. The notes are guaranteed on a senior unsecured basis by each of the Company's subsidiaries that guarantee the Credit Facility. Interest on the 2026 Senior Notes is payable semi-annually, on June 1 and December 1 of each year. The 2026 Senior Notes were issued under the Indentures, dated as of May 17, 2021, by and among the Issuer, UMB Bank, National Association, as trustee, and the Guarantors and mature on May 17, 2026. The covenants of the 1145 Indenture (other than the payment covenant) require that the Company comply with the covenants of the 4(a)(2) Indenture, as amended. The 4(a)(2) Indenture contains covenants limiting the Issuer’s and its restricted subsidiaries’ ability to (i) incur additional debt, (ii) pay dividends or distributions in respect of certain equity interests or redeem, repurchase or retire certain equity interests or subordinated indebtedness, (iii) make certain investments, (iv) create restrictions on distributions from restricted subsidiaries, (v) engage in specified sales of assets, (vi) enter into certain transactions among affiliates, (vii) engage in certain lines of business, (viii) engage in consolidations, mergers and acquisitions, (ix) create unrestricted subsidiaries and (x) incur or create liens. These covenants contain important exceptions, limitations and qualifications. At any time that the 2026 Senior Notes are rated investment grade, certain covenants will be terminated and cease to apply. Capitalization of Interest The Company did not capitalize interest expense for the Successor Quarter or Predecessor Quarter. Fair Value of Debt At March 31, 2022, the carrying value of the outstanding debt represented by the 2026 Senior Notes was $549.0 million. Based on the quoted market prices (Level 1), the fair value of the 2026 Senior Notes was determined to be $570.1 million at March 31, 2022. |
EQUITY AND MEZZANINE EQUITY
EQUITY AND MEZZANINE EQUITY | 3 Months Ended |
Mar. 31, 2022 | |
Equity [Abstract] | |
EQUITY AND MEZZANINE EQUITY | EQUITY AND MEZZANINE EQUITY On the Emergence Date, the Company filed an amended and restated certificate of incorporation with the Delaware Secretary of State to provide for, among other things, (i) the authority to issue 42 million shares of common stock with a par value of $0.0001 per share and (ii) the designation of 110,000 shares of preferred stock, with a par value of $0.0001 per share and a liquidation preference of $1,000 per share. Equity Common Stock On the Emergence Date, all existing shares of the Predecessor's common stock were cancelled. The Successor issued approximately 19.8 million shares of common stock and 1.7 million shares of common stock were issued to the Disputed Claims reserve. In January 2022, approximately 876,000 shares in the Disputed Claims reserve at December 31, 2021 were issued to certain claimants. As of March 31, 2022, approximately 62,000 shares continue to be held in the Disputed Claims reserve and may be issued upon finalization of remaining claims. Share Repurchase Program On November 1, 2021, the Company's Board of Directors approved a stock repurchase program to acquire up to $100.0 million of its common stock ("Repurchase Program"). Purchases under the Repurchase Program may be made from time to time in open market or privately negotiated transactions, and will be subject to available liquidity, market conditions, credit agreement restrictions, applicable legal requirements, contractual obligations and other factors. The Repurchase Program does not require the Company to acquire any specific number of shares of common stock. The Company intends to purchase shares under the Repurchase Program opportunistically with available funds while maintaining sufficient liquidity to fund its capital development program. The Repurchase Program is authorized to extend through December 31, 2022, and may be suspended from time to time, modified, extended or discontinued by the board of directors at any time. Any shares of common stock repurchased are expected to be cancelled. As of March 31, 2022, 438,082 shares have been repurchased for approximately $35.5 million under the Repurchase Program at a weighted average price of $81.06 per share. Mezzanine Equity Preferred Stock On the Emergence Date, the Successor issued 55,000 shares of preferred stock. Holders of preferred stock are entitled to receive cumulative quarterly dividends at a rate of 10% per annum of the Liquidation Preference (as defined below) with respect to cash dividends and 15% per annum of the Liquidation Preference with respect to dividends paid in kind as additional shares of preferred stock (“PIK Dividends”). Gulfport currently has the option to pay either cash or PIK dividends on a quarterly basis. Each holder of shares of preferred stock has the right (the “Conversion Right”), at its option and at any time, to convert all or a portion of the shares of preferred stock that it holds into a number of shares of common stock equal to the quotient obtained by dividing (x) the product obtained by multiplying (i) the Liquidation Preference times (ii) an amount equal to one (1) plus the Per Share Makewhole Amount (as defined in the Preferred Terms) on the date of conversion, by (y) $14.00 per share (as may be adjusted under the Preferred Terms) (the “Conversion Price”). The shares of preferred stock outstanding at March 31, 2022 would convert to approximately 4.1 million shares of common stock if all holders of preferred stock exercised their Conversion Right. Gulfport shall have the right, but not the obligation, to redeem all, but not less than all, of the outstanding shares of preferred stock by notice to the holders of preferred stock, at the greater of (i) the aggregate value of the preferred stock, calculated by the Current Market Price (as defined in the Preferred Terms) of the number of shares of common stock into which, subject to redemption, such preferred stock would have been converted if such shares were converted pursuant to the Conversion Right at the time of such redemption and (ii) (y) if the date of such redemption is on or prior to the three year anniversary of the Emergence Date, the sum of the Liquidation Preference plus the sum of all unpaid PIK Dividends through the three year anniversary of the Emergence Date, or (x) if the date of such redemption is after the three year anniversary of the Emergence Date, the Liquidation Preference (the “Redemption Price”). Following the Emergence Date, if there is a Fundamental Change (as defined in the Preferred Terms), Gulfport is required to redeem all, but not less than all, of the outstanding shares of preferred stock by cash payment of the Redemption Price per share of preferred stock within three (3) business days of the occurrence of such Fundamental Change. Notwithstanding the foregoing, in the event of a redemption pursuant to the preceding sentence, if Gulfport lacks sufficient cash to redeem all outstanding shares of preferred stock, the Company is required to redeem a pro rata portion of each holder’s shares of preferred stock. The preferred stock has no stated maturity and will remain outstanding indefinitely unless repurchased or redeemed by Gulfport or converted into common stock. Each share of preferred stock has a liquidation preference of $1,000 (the "Liquidation Preference"). The preferred stock has been classified as mezzanine equity in the accompanying consolidated balance sheets due to the redemption features noted above. Dividends and Conversions During the Successor Quarter, the company paid $1.5 million of cash dividends to holders of our preferred stock. The following table summarizes activity of the Company’s preferred stock for the Successor Quarter: Preferred stock at December 31, 2021 57,896 Conversion of preferred stock (18) Preferred stock at March 31, 2022 57,878 |
STOCK-BASED COMPENSATION
STOCK-BASED COMPENSATION | 3 Months Ended |
Mar. 31, 2022 | |
Share-based Payment Arrangement, Noncash Expense [Abstract] | |
STOCK-BASED COMPENSATION | STOCK-BASED COMPENSATION On the Emergence Date, the Company's Predecessor common stock was cancelled and the Company's Successor common stock was issued. Accordingly, the Company's then existing stock-based compensation awards were also cancelled. Stock-based compensation for the Predecessor and Successor periods are not comparable. Successor Stock-Based Compensation As of the Emergence Date, the board of directors adopted the Incentive Plan with a share reserve equal to 2.8 million shares of common stock. The Incentive Plan provides for the grant of incentive stock options, nonstatutory stock options, restricted stock, restricted stock units, stock appreciation rights, dividend equivalents and performance awards or any combination of the foregoing. The Company has granted both restricted stock units and performance vesting restricted stock units to employees and directors pursuant to the Incentive Plan, as discussed below. During the Successor Quarter, the Company's stock-based compensation expense was $1.8 million, of which the Company capitalized $0.6 million relating to its exploration and development efforts. Stock compensation expense, net of the amounts capitalized, is included in general and administrative expenses in the accompanying consolidated statements of operations. As of March 31, 2022, the Company has awarded an aggregate of approximately 196,000 restricted stock units and approximately 153,000 performance vesting restricted stock units under the Incentive Plan. The following table summarizes restricted stock unit activity for the Successor Quarter: Number of Weighted Number of Weighted Unvested shares as of January 1, 2022 198,413 $ 66.04 153,138 $ 48.54 Granted 2,154 73.83 — — Vested (3,074) 65.75 — — Forfeited/canceled (1,157) 66.89 — — Unvested shares as of March 31, 2022 196,336 $ 67.16 153,138 $ 48.54 Successor Restricted Stock Units Restricted stock units awarded under the Incentive Plan generally vest over a period of 1 to 4 years in the case of employees and 4 years in the case of directors upon the recipient meeting applicable service requirements. Stock-based compensation expense is 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 the grant. Unrecognized compensation expense as of March 31, 2022 was $10.0 million. The expense is expected to be recognized over a weighted average period of 2.63 years. Successor Performance Vesting Restricted Stock Units The Company has awarded performance vesting restricted stock units to certain of its executive officers under the Incentive Plan. The number of shares of common stock issued pursuant to the award will be based on a combination of (i) the Company's total shareholder return ("TSR") and (ii) the Company's relative total shareholder return ("RTSR") for the performance period. Participants will earn from 0% to 200% of the target award based on the Company's TSR and RTSR ranking compared to the TSR 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 from May 17, 2021 to May 17, 2024, subject to earlier termination of the performance period in the event of a change in control. The grant date fair values were determined using the Monte Carlo simulation method and are being recorded ratably over the performance period. Unrecognized compensation expense as of March 31, 2022, related to performance vesting restricted shares was $5.7 million. The expense is expected to be recognized over a weighted average period of 2.13 years. Predecessor Stock-Based Compensation The Predecessor granted restricted stock units to employees and directors pursuant to the 2019 Plan. During the Predecessor Quarter, 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. 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 Predecessor Quarter: Number of Weighted Number of Weighted 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 Predecessor Restricted Stock Units Restricted stock units awarded under the 2019 Plan generally vested over a period of one year in the case of directors and three years in the case of employees and vesting was 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. All unrecognized compensation expense was recognized as of the Emergence Date. Predecessor Performance Vesting Restricted Stock Units The Company previously awarded performance vesting restricted stock units to certain of its executive officers under the 2019 Plan. The number of shares of common stock issued pursuant to the award was based on RTSR. RTSR is an incentive measure whereby participants will earn from 0% to 200% of the target award based on the Company’s TSR ranking compared to the TSR of the companies in the Company’s designated peer group at the end of the performance period. Awards were to 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. All unrecognized compensation expense was recognized as of the Emergence Date. |
EARNINGS PER SHARE
EARNINGS PER SHARE | 3 Months Ended |
Mar. 31, 2022 | |
Earnings Per Share [Abstract] | |
EARNINGS PER SHARE | EARNINGS PER SHAREBasic income or loss per share attributable to common stockholders is computed as (i) net income or loss less (ii) dividends paid to holders of preferred stock less (iii) net income or loss attributable to participating securities divided by (iv) weighted average basic shares outstanding. Diluted net income or loss per share attributable to common stockholders is computed as (i) basic net income or loss attributable to common stockholders plus (ii) diluted adjustments to income allocable to participating securities divided by (iii) weighted average diluted shares outstanding. The "if-converted" method is used to determine the dilutive impact for the Company's convertible preferred stock and the treasury stock method is used to determine the dilutive impact of unvested restricted stock. There were no potential shares of common stock that were considered dilutive for the Successor Quarter or Predecessor Quarter. There were 4.1 million shares of potential common shares issuable due to the Company's convertible preferred stock and 0.1 million shares of restricted stock that were considered anti-dilutive during the Successor Quarter. Reconciliations of the components of basic and diluted net (loss) income per common share are presented in the table below (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Net (loss) income $ (491,975) $ 8,780 Dividends on preferred stock (1,447) — Participating securities - preferred stock (1) — — Net (loss) income attributable to common stockholders $ (493,422) $ 8,780 Basic Shares 21,242 160,813 Basic and Dilutive EPS $ (23.23) $ 0.05 _____________________ (1) Preferred stock represents participating securities because it participates in any dividends on shares of common stock on a pari passu , pro rata basis. However, preferred stock does not participate in undistributed net losses. |
COMMITMENTS AND CONTINGENCIES
COMMITMENTS AND CONTINGENCIES | 3 Months Ended |
Mar. 31, 2022 | |
Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES Commitments Future Firm Transportation and Gathering Agreements The Company has contractual commitments with midstream and 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. Working interest owners and royalty interest owners, where appropriate, will be responsible for their proportionate share of these costs. Commitments related to future firm transportation and gathering agreements are not recorded as obligations in the accompanying consolidated balance sheets; however, costs associated with utilized future firm transportation and gathering agreements are reflected in the Company's estimates of proved reserves. A summary of these commitments at March 31, 2022 are set forth in the table below, excluding contracts in the process of being rejected as discussed in the Litigation and Regulatory Proceedings section below (in thousands): Remaining 2022 $ 180,807 2023 229,733 2024 220,708 2025 139,706 2026 136,235 Thereafter 889,674 Total $ 1,796,863 Contingencies 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. In accordance with ASC Topic 450, Contingencies , an accrual is recorded for a material loss contingency when its occurrence is probable and damages are reasonably estimable based on the anticipated most likely outcome or the minimum amount within a range of possible outcomes. Litigation and Regulatory Proceedings Commencement of the Chapter 11 Cases automatically stayed the proceedings and actions against us that are described below, in addition to actions seeking to collect pre-petition indebtedness or to exercise control over the property of the Company's bankruptcy estates. The Plan in the Chapter 11 Cases, which became effective on May 17, 2021, provided for the treatment of claims against the Company's bankruptcy estates, including pre-petition liabilities that had not been satisfied or addressed during the Chapter 11 Cases. As part of its Chapter 11 Cases and restructuring efforts, the Company filed motions to reject certain firm transportation agreements between the Company and affiliates of TC Energy Corporation ("TC") and Rover Pipeline LLC ("Rover") (jointly, 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. During the third quarter of 2021, Gulfport finalized a settlement agreement with TC that was approved by the Bankruptcy Court on September 21, 2021. Pursuant to the settlement agreement, Gulfport and TC agreed that the firm transportation contracts between Gulfport and TC would be rejected without any further payment or obligation by Gulfport or TC, and TC assigned its damages claims from such rejection to Gulfport. In exchange, Gulfport agreed to make a payment of $43.8 million in cash to TC. The $43.8 million was paid to TC on October 7, 2021. Gulfport expects to receive distributions for a significant portion of such amounts through future distributions with respect to the assigned claims pursuant to Gulfport’s Chapter 11 plan of reorganization that became effective in May 2021. Any future distributions will be recognized once received by Gulfport. In February 2022, Gulfport received an initial distribution of $11.5 million from the above mentioned claim, which is included in Other, net in the accompanying consolidated statements of operations. The timing and amount of any future distributions are not certain, and the total amount received will be impacted by the bankruptcy trustee's liquidation of Mammoth Energy shares and other bankruptcy claims. The Company believes that the Pending Motion to Reject with respect to Rover will be ultimately granted, and that the Company does not have any ongoing obligation pursuant to the contract; however, in the event that the Company is not permitted to reject the Rover firm transportation contract, it could be liable for demand charges, attorneys' fees and interest in excess of approximately $64 million. 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. On January 11, 2022, the court granted Gulfport's motion to dismiss and the case was closed by the court on February 14, 2022. The plaintiffs appealed the district court ruling on March 10, 2022. The Company, along with other oil and gas companies, have been named as a defendant in J&R Passmore, LLC, individually and on behalf of all others similarly situated, in the United States District Court for the Southern District of Ohio on December 6, 2018. Plaintiffs assert their respective leases are limited to the Marcellus and Utica shale geological formations and allege that Defendants have willfully trespassed and illegally produced oil, natural gas, and other hydrocarbon products beyond these respective formations. Plaintiffs seek the full value of any production from below the Marcellus and Utica shale formations, unspecified damages from the diminution of value to their mineral estate, unspecified punitive damages, and the payment of reasonable attorney fees, legal expenses, and interest. On April 27, 2021, the Bankruptcy Court for the Southern District of Texas approved a settlement agreement in which the plaintiffs fully released the Company from all claims for amounts allegedly owed to the plaintiffs through the effective date of the Company’s Chapter 11 plan, which occurred on May 17, 2021. The plaintiffs are continuing to pursue alleged damages after May 17, 2021. 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. The Company conducts 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. |
DERIVATIVE INSTRUMENTS
DERIVATIVE INSTRUMENTS | 3 Months Ended |
Mar. 31, 2022 | |
General Discussion of Derivative Instruments and Hedging Activities [Abstract] | |
DERIVATIVE INSTRUMENTS | DERIVATIVE INSTRUMENTS Natural Gas, Oil and NGL 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 a floor price for a certain level of the Company’s production. However, these hedge contracts also limit the benefit to the Company in periods of favorable price movements. The volume of production subject to commodity derivative instruments and the mix of the instruments are frequently evaluated and adjusted by management in response to changing market conditions. Gulfport may enter into commodity derivative contracts up to limitations set forth in its Credit Facility. The Company generally enters into commodity derivative contracts for approximately 50% to 75% of its forecasted annual production by the end of the first quarter of each fiscal year. The Company typically enters into commodity derivative contracts for the next 12 to 24 months. Gulfport does not enter into commodity derivative contracts for speculative purposes. 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 WTI for oil and Mont Belvieu for propane. The Company does not currently have any commodity derivative transactions that have margin requirements or collateral provisions that would require payments prior to the scheduled settlement dates. The Company's commodity derivative contract counterparties are typically financial institutions and energy trading firms with investment-grade credit ratings. Gulfport routinely monitors and manages its exposure to counterparty risk by requiring specific minimum credit standards for all counterparties, actively monitoring counterparties' public credit ratings and avoiding the concentration of credit exposure by transacting with multiple counterparties. The Company has master netting agreements with some counterparties that allow the offsetting of receivables and payables in a default situation. Below is a summary of the Company’s open fixed price swap positions as of March 31, 2022. Index Daily Volume Weighted Natural Gas (MMBtu/d) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 190,145 $ 2.90 2023 NYMEX Henry Hub 155,014 $ 3.54 2024 NYMEX Henry Hub 24,973 $ 3.62 Oil (Bbl/d) ($/Bbl) Remaining 2022 NYMEX WTI 2,335 $ 66.17 2023 NYMEX WTI 2,000 $ 67.89 NGL (Bbl/d) ($/Bbl) Remaining 2022 Mont Belvieu C3 3,502 $ 35.62 2023 Mont Belvieu C3 2,000 $ 35.05 The Company entered into costless collars based off the NYMEX WTI and Henry Hub oil and natural gas indices. 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, 2022. Index Daily Volume Weighted Average Floor Price Weighted Average Ceiling Price Natural Gas (MMBtu/d) ($/MMBtu) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 431,391 $ 2.56 $ 3.07 2023 NYMEX Henry Hub 85,000 $ 2.75 $ 4.25 Oil (Bbl/d) ($/Bbl) ($/Bbl) Remaining 2022 NYMEX WTI 1,500 $ 55.00 $ 60.00 In the third quarter of 2019, the Company sold call options in exchange for a premium, and used the associated premiums received to enhance the fixed price for a portion of the fixed price natural gas swaps primarily for 2020. Each short call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these short call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volumes. No payment is due from either party if the referenced settlement price is below the price ceiling. Below is a summary of the Company's open sold call option positions as of March 31, 2022. Index Daily Volume Weighted Average Price Natural Gas (MMBtu/d) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 152,675 $ 2.90 2023 NYMEX Henry Hub 507,925 $ 2.90 2024 NYMEX Henry Hub 162,000 $ 3.00 In addition, the Company entered into natural gas basis swap positions. As of March 31, 2022, the Company had the following natural gas swap positions open: Gulfport Pays Gulfport Receives Daily Volume Weighted Average Fixed Spread Natural Gas (MMBtu/d) ($/MMBtu) 2023 Rex Zone 3 NYMEX Plus Fixed Spread 20,000 $ (0.21) 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, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Short-term derivative asset $ 15,720 $ 4,695 Long-term derivative asset 20,696 18,664 Short-term derivative liability (820,255) (240,735) Long-term derivative liability (281,622) (184,580) Total commodity derivative position $ (1,065,461) $ (401,956) Gains and Losses The following table presents the gain and loss recognized in net loss on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the Successor Quarter and Predecessor Quarter (in thousands): Net loss on derivative instruments Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Natural gas derivatives - fair value losses $ (619,319) $ (25,538) Natural gas derivatives - settlement (losses) gains (111,157) 125 Total losses on natural gas derivatives (730,476) (25,413) Oil derivatives - fair value losses (29,853) (1,731) Oil derivatives - settlement losses (8,144) — Total losses on oil derivatives (37,997) (1,731) NGL derivatives - fair value losses (14,333) (2,834) NGL derivatives - settlement losses (5,745) — Total losses on NGL derivatives (20,078) (2,834) Total losses on natural gas, oil and NGL derivatives $ (788,551) $ (29,978) Offsetting of Derivative Assets and Liabilities As noted above, the Company records the fair value of derivative instruments on a gross basis. The following tables present 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 (in thousands): Successor As of March 31, 2022 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 36,416 $ (36,416) $ — Derivative liabilities $ (1,101,877) $ 36,416 $ (1,065,461) Successor As of December 31, 2021 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 23,359 $ (20,265) $ 3,094 Derivative liabilities $ (425,315) $ 20,265 $ (405,050) 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 |
FAIR VALUE MEASUREMENTS
FAIR VALUE MEASUREMENTS | 3 Months Ended |
Mar. 31, 2022 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | 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 (unadjusted) in active markets for identical assets and liabilities that the Company has the ability to access at the measurement date. 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, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 Level 1 Level 2 Level 3 Assets: Derivative instruments $ — $ 36,416 $ — Contingent consideration arrangement — — 5,300 Total assets $ — $ 36,416 $ 5,300 Liabilities: Derivative instruments $ — $ 1,101,877 $ — Successor December 31, 2021 Level 1 Level 2 Level 3 Assets: Derivative instruments $ — $ 23,359 $ — Contingent consideration arrangement — — 5,800 Total assets $ — $ 23,359 $ 5,800 Liabilities: Derivative instruments $ — $ 425,315 $ — 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 adjusted the fair value of its derivative instruments as a fresh start adjustment at the Emergence Date as a result of changes in the Company's credit adjustment to reflect its new credit standing at emergence. The Company's SCOOP water infrastructure sale, which closed in the first quarter of 2020, included a contingent consideration arrangement. As of March 31, 2022, the fair value of the contingent consideration was $5.3 million, of which $0.8 million is included in prepaid expenses and other assets and $4.5 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 $0.1 million loss for the Successor Quarter and a nominal gain for the Predecessor Quarter, which are 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 2 for further discussion of the Company’s asset retirement obligations. Fair value of other financial instruments |
REVENUE FROM CONTRACTS WITH CUS
REVENUE FROM CONTRACTS WITH CUSTOMERS | 3 Months Ended |
Mar. 31, 2022 | |
Revenue from Contract with Customer [Abstract] | |
REVENUE FROM CONTRACTS WITH CUSTOMERS | 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 transportation, gathering, processing and compression 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 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 $206.9 million and $232.9 million as of March 31, 2022 and December 31, 2021, 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 Predecessor Quarter and Successor Quarter, revenue recognized in the reporting periods related to performance obligations satisfied in prior reporting periods was not material. |
LEASES
LEASES | 3 Months Ended |
Mar. 31, 2022 | |
Leases [Abstract] | |
LEASES | LEASES Nature of Leases The Company has operating leases on certain equipment 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 Comp any has concluded its d rilling rig contracts are operating leases as the assets are identifiable and the Company has the right to control the identified assets. However, at March 31, 2022, the Company did not have any active long-term drilling rig contracts in place. The Company rents office space for its corporate headquarters, field locations and certain other equipment from third parties, which expire at various dates through 2023. These agreements are typically structured with non-cancelable terms of one 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. Future amounts due under operating lease liabilities as of March 31, 2022 were as follows (in thousands): Remaining 2022 $ 137 2023 142 Total lease payments $ 279 Less: Imputed interest (6) Total $ 273 Lease costs incurred for the Successor Quarter and Predecessor Quarter consisted of the following (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Operating lease cost $ 50 $ 32 Variable lease cost — — Short-term lease cost 8,622 2,189 Total lease cost (1) $ 8,672 $ 2,221 _____________________ (1) The majority of the Company's total lease cost was capitalized to the full cost pool, and the remainder was included in either lease operating expenses or general and administrative expenses in the accompanying consolidated statements of operations. Supplemental cash flow information related to leases was as follows (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 49 $ 31 |
INCOME TAXES
INCOME TAXES | 3 Months Ended |
Mar. 31, 2022 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | 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, 2022, the Company's effective tax rate was 0%, which differs from the statutory rate of 21% primarily as a result of the valuation allowance on the Company's 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 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. Based upon the Company’s analysis, the Company determined a full valuation allowance was necessary against its net deferred tax assets as of March 31, 2022. The Company will continue to evaluate whether the valuation allowance is needed in future reporting periods. The valuation allowance will remain until it is determined that the net deferred tax assets are more likely than not to be realized. Future events or new evidence which may lead us to conclude that it is more likely than not that its net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings, improvements in oil prices, and taxable events that could result from one or more transactions. The valuation allowance does not prevent future utilization of the tax attributes if the Company recognizes taxable income. As long as the Company concludes that the valuation allowance against its net deferred tax assets is necessary, the Company likely will not have any additional deferred income tax expense or benefit. Elements of the Plan provided that the Company’s indebtedness related to Predecessor Senior Notes and certain general unsecured claims were exchanged for common stock in settlement of those claims. Absent an exception, a debtor recognizes CODI upon discharge of its outstanding indebtedness for an amount of consideration that is less than its adjusted issue price. The IRC provides that a debtor in a Chapter 11 bankruptcy case may exclude CODI from taxable income, but must reduce certain of its tax attributes by the amount of any CODI realized as a result of the consummation of a plan of reorganization. The amount of CODI realized by a taxpayer is determined based on the fair market value of the consideration received by the creditors in settlement of outstanding indebtedness. As a result of the market value of equity upon emergence from Chapter 11 bankruptcy proceedings, the estimated amount of CODI and reduction in historical interest expense is approximately $661 million, which will reduce the value of the Company’s net operating losses. The actual reduction in tax attributes does not occur until the first day of the Company’s tax year subsequent to the date of emergence, or January 1, 2022. The reduction of net operating losses is expected to be fully offset by a corresponding decrease in valuation allowance. Emergence from Chapter 11 bankruptcy proceedings resulted in a change in ownership for purposes of IRC Section 382. The Company currently expects to apply rules under IRC Section 382(l)(5) that would allow the Company to mitigate the limitations imposed under the regulations with respect to the Company’s remaining tax attributes. The Company’s deferred tax assets and liabilities, prior to the valuation allowance, have been computed on such basis. Taxpayers who qualify for this provision may, at their option, elect not to apply the election. If the provision does not apply, the Company’s ability to realize the value of its tax attributes would be subject to limitation and the amount of deferred tax assets and liabilities, prior to the valuation allowance, may differ. Additionally, under IRC Section 382(l)(5), an ownership change subsequent to the Company’s emergence could severely limit or effectively eliminate its ability to realize the value of its tax attributes. |
SUBSEQUENT EVENTS
SUBSEQUENT EVENTS | 3 Months Ended |
Mar. 31, 2022 | |
Subsequent Events [Abstract] | |
SUBSEQUENT EVENTS | SUBSEQUENT EVENTS Natural Gas, Oil and NGL Derivative Instruments The Company entered into additional natural gas, oil and NGL derivative contracts subsequent to March 31, 2022, which included restructuring a portion of the Company's 2023 sold call options. The Company entered into the following natural gas, oil and NGL derivative contracts subsequent to March 31, 2022 as of April 29, 2022: Type of Derivative Instrument Index Daily Volume Weighted Natural Gas (MMBtu/d) ($/MMBtu) January 2023 - December 2023 Fixed price swap NYMEX Henry Hub 10,000 $5.17 January 2023 - December 2023 Costless collar NYMEX Henry Hub 200,000 $3.00 / $5.00 January 2023 - December 2023 Call option NYMEX Henry Hub (100,000) $2.90 January 2024 - December 2024 Fixed price swap NYMEX Henry Hub 10,000 $4.16 January 2024 - December 2024 Call option NYMEX Henry Hub 40,000 $4.65 January 2025 - October 2025 Call option NYMEX Henry Hub 40,000 $4.65 Oil (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap NYMEX WTI 1,000 $87.62 NGL (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap Mont Belvieu C3 1,000 $44.10 Credit Facility Redetermination On May 2, 2022, the Company entered into the borrowing base redetermination agreement and first amendment to its credit agreement (the “Amendment”) governing the Credit Facility. The Amendment, among other things, (a) increased the borrowing base under the New Credit Agreement from $850 million to $1.0 billion as a result of the spring 2022 scheduled redetermination with aggregate elected lender commitments to remain at $700 million, (b) amended certain covenants related to hedging to ease certain requirements and limitations and (c) amended the covenants governing restricted payments to (i) increase the Net Leverage Ratio allowing unlimited restricted payments from 1.00 to 1.00 to 1.25 to 1.00 and (ii) permit additional restricted payments to redeem preferred equity until December 31, 2022 provided certain leverage, no event of default or borrowing base deficiency and availability tests are met and (d) provide for the transition from a LIBOR to a SOFR benchmark, with a 10 basis point credit spread adjustment for all tenors. Expanded Common Stock Repurchase Program In April 2022, the Company's Board of Directors approved an increase to the authorized common stock repurchase amounts under its Repurchase Program from $100 million to $200 million. |
BASIS OF PRESENTATION (Policies
BASIS OF PRESENTATION (Policies) | 3 Months Ended |
Mar. 31, 2022 | |
Accounting Policies [Abstract] | |
Basis of Presentation | Basis of Presentation The accompanying unaudited condensed consolidated financial statements of Gulfport were prepared in accordance with GAAP and the rules and regulations of the SEC. This Quarterly Report on Form 10-Q (this “Form 10-Q”) relates to the financial position and periods as of and for the three months ended March 31, 2022 ("Successor Quarter") and the three months ended March 31, 2021 (“Predecessor Quarter”). The Company's annual report on Form 10-K for the year ended December 31, 2021 (“2021 Form 10-K”) should be read in conjunction with this Form 10-Q. The accompanying unaudited consolidated financial statements reflect all normal recurring adjustments which, in the opinion of management, are necessary for a fair statement of our condensed consolidated financial statements and accompanying notes and include the accounts of our wholly-owned subsidiaries. Intercompany accounts and balances have been eliminated. The accompanying consolidated financial statements have been prepared assuming the Company will continue as a going concern. |
BASIS OF PRESENTATION (Tables)
BASIS OF PRESENTATION (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Accounting Policies [Abstract] | |
Schedule of Accounts Payable and Accrued Liabilities | Accounts payable and accrued liabilities consisted of the following at March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Accounts payable and other accrued liabilities $ 183,786 $ 143,938 Revenue payable and suspense 173,285 180,857 Accrued contract rejection damages and shares held in reserve 40,996 69,216 Total accounts payable and accrued liabilities $ 398,067 $ 394,011 |
Fresh Start Adjustments | The following table summarizes the components in reorganization items, net included in the Company's consolidated statements of operations for the Predecessor Quarter (in thousands): Predecessor Three Months Ended March 31, 2021 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 |
Schedule of Cash Flow, Supplemental Disclosures | Supplemental Cash Flow and Non-Cash Information (in thousands) Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Supplemental disclosure of cash flow information: Cash paid for reorganization items, net $ — $ 21,367 Interest payments $ 2,110 $ 4,763 Changes in operating assets and liabilities: Decrease (increase) in accounts receivable - oil and natural gas sales $ 25,985 $ (14,117) Increase in accounts receivable - joint interest and other (17,722) (478) Increase in accounts payable and accrued liabilities 2,135 15,555 Decrease in prepaid expenses 6,811 26,356 Increase in other assets (17) (655) Total changes in operating assets and liabilities $ 17,192 $ 26,661 Supplemental disclosure of non-cash transactions: Capitalized stock-based compensation $ 597 $ 630 Asset retirement obligation capitalized $ 16 $ 483 Release of common stock held in reserve $ 28,220 $ — Foreign currency translation gain on equity method investments $ — $ 2,570 |
PROPERTY AND EQUIPMENT (Tables)
PROPERTY AND EQUIPMENT (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Property, Plant and Equipment [Abstract] | |
Schedule of Property and Equipment | The major categories of property and equipment and related accumulated DD&A and impairment as of March 31, 2022 and December 31, 2021 are as follows (in thousands): Successor March 31, 2022 December 31, 2021 Proved oil and natural gas properties $ 2,030,289 $ 1,917,833 Unproved properties 203,678 211,007 Other depreciable property and equipment 5,034 4,943 Land 386 386 Total property and equipment 2,239,387 2,134,169 Accumulated DD&A and impairment (340,709) (278,341) Property and equipment, net $ 1,898,678 $ 1,855,828 |
Schedule of Non-Producing Properties Excluded from Amortization by Area | The following table summarizes the Company’s non-producing properties excluded from amortization by area as of March 31, 2022: Successor March 31, 2022 (In thousands) Utica $ 168,809 SCOOP 34,865 Other 4 Total unproved properties $ 203,678 |
Schedule of Asset Retirement Obligation | The following table provides a reconciliation of the Company’s asset retirement obligation for the Successor and Predecessor Quarters (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Asset retirement obligation, beginning of period $ 28,264 $ 63,566 Liabilities incurred 16 483 Accretion expense 692 805 Total asset retirement obligation as of end of period $ 28,972 $ 64,854 Less: amounts reclassified to liabilities subject to compromise $ — $ (64,854) Total asset retirement obligation reflected as non-current liabilities $ 28,972 $ — |
LONG-TERM DEBT (Tables)
LONG-TERM DEBT (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Long-term Debt, Unclassified [Abstract] | |
Schedule of Long-Term Debt | Debt consisted of the following items as of March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Credit Facility $ 25,000 $ 164,000 8.000% senior unsecured notes due 2026 550,000 550,000 Net unamortized debt issuance costs (1,004) (1,054) Total debt, net 573,996 712,946 Less: current maturities of long-term debt — — Total long-term debt, net $ 573,996 $ 712,946 |
EQUITY AND MEZZANINE EQUITY (Ta
EQUITY AND MEZZANINE EQUITY (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Equity [Abstract] | |
Schedule of Movement on Temporary Equity | The following table summarizes activity of the Company’s preferred stock for the Successor Quarter: Preferred stock at December 31, 2021 57,896 Conversion of preferred stock (18) Preferred stock at March 31, 2022 57,878 |
STOCK-BASED COMPENSATION (Table
STOCK-BASED COMPENSATION (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Share-based Payment Arrangement, Noncash Expense [Abstract] | |
Schedule of Restricted Stock Activity | The following table summarizes restricted stock unit activity for the Successor Quarter: Number of Weighted Number of Weighted Unvested shares as of January 1, 2022 198,413 $ 66.04 153,138 $ 48.54 Granted 2,154 73.83 — — Vested (3,074) 65.75 — — Forfeited/canceled (1,157) 66.89 — — Unvested shares as of March 31, 2022 196,336 $ 67.16 153,138 $ 48.54 The following table summarizes restricted stock unit activity for the Predecessor Quarter: Number of Weighted Number of Weighted 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 |
EARNINGS PER SHARE (Tables)
EARNINGS PER SHARE (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Earnings Per Share [Abstract] | |
Schedule of Earnings Per Share | Reconciliations of the components of basic and diluted net (loss) income per common share are presented in the table below (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Net (loss) income $ (491,975) $ 8,780 Dividends on preferred stock (1,447) — Participating securities - preferred stock (1) — — Net (loss) income attributable to common stockholders $ (493,422) $ 8,780 Basic Shares 21,242 160,813 Basic and Dilutive EPS $ (23.23) $ 0.05 _____________________ (1) Preferred stock represents participating securities because it participates in any dividends on shares of common stock on a pari passu , pro rata basis. However, preferred stock does not participate in undistributed net losses. |
COMMITMENTS AND CONTINGENCIES (
COMMITMENTS AND CONTINGENCIES (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of Future Service Commitments | A summary of these commitments at March 31, 2022 are set forth in the table below, excluding contracts in the process of being rejected as discussed in the Litigation and Regulatory Proceedings section below (in thousands): Remaining 2022 $ 180,807 2023 229,733 2024 220,708 2025 139,706 2026 136,235 Thereafter 889,674 Total $ 1,796,863 |
DERIVATIVE INSTRUMENTS (Tables)
DERIVATIVE INSTRUMENTS (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
General Discussion of Derivative Instruments and Hedging Activities [Abstract] | |
Schedule of Open Fixed Price Swap Positions and Natural Gas Basis Swap Positions | Below is a summary of the Company’s open fixed price swap positions as of March 31, 2022. Index Daily Volume Weighted Natural Gas (MMBtu/d) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 190,145 $ 2.90 2023 NYMEX Henry Hub 155,014 $ 3.54 2024 NYMEX Henry Hub 24,973 $ 3.62 Oil (Bbl/d) ($/Bbl) Remaining 2022 NYMEX WTI 2,335 $ 66.17 2023 NYMEX WTI 2,000 $ 67.89 NGL (Bbl/d) ($/Bbl) Remaining 2022 Mont Belvieu C3 3,502 $ 35.62 2023 Mont Belvieu C3 2,000 $ 35.05 The Company entered into costless collars based off the NYMEX WTI and Henry Hub oil and natural gas indices. 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, 2022. Index Daily Volume Weighted Average Floor Price Weighted Average Ceiling Price Natural Gas (MMBtu/d) ($/MMBtu) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 431,391 $ 2.56 $ 3.07 2023 NYMEX Henry Hub 85,000 $ 2.75 $ 4.25 Oil (Bbl/d) ($/Bbl) ($/Bbl) Remaining 2022 NYMEX WTI 1,500 $ 55.00 $ 60.00 Index Daily Volume Weighted Average Price Natural Gas (MMBtu/d) ($/MMBtu) Remaining 2022 NYMEX Henry Hub 152,675 $ 2.90 2023 NYMEX Henry Hub 507,925 $ 2.90 2024 NYMEX Henry Hub 162,000 $ 3.00 |
Schedule of Natural Gas Basis Swap Positions | In addition, the Company entered into natural gas basis swap positions. As of March 31, 2022, the Company had the following natural gas swap positions open: Gulfport Pays Gulfport Receives Daily Volume Weighted Average Fixed Spread Natural Gas (MMBtu/d) ($/MMBtu) 2023 Rex Zone 3 NYMEX Plus Fixed Spread 20,000 $ (0.21) Type of Derivative Instrument Index Daily Volume Weighted Natural Gas (MMBtu/d) ($/MMBtu) January 2023 - December 2023 Fixed price swap NYMEX Henry Hub 10,000 $5.17 January 2023 - December 2023 Costless collar NYMEX Henry Hub 200,000 $3.00 / $5.00 January 2023 - December 2023 Call option NYMEX Henry Hub (100,000) $2.90 January 2024 - December 2024 Fixed price swap NYMEX Henry Hub 10,000 $4.16 January 2024 - December 2024 Call option NYMEX Henry Hub 40,000 $4.65 January 2025 - October 2025 Call option NYMEX Henry Hub 40,000 $4.65 Oil (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap NYMEX WTI 1,000 $87.62 NGL (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap Mont Belvieu C3 1,000 $44.10 |
Schedule of Derivative Instruments in Balance Sheet | The following table presents the fair value of the Company’s derivative instruments on a gross basis at March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 December 31, 2021 Short-term derivative asset $ 15,720 $ 4,695 Long-term derivative asset 20,696 18,664 Short-term derivative liability (820,255) (240,735) Long-term derivative liability (281,622) (184,580) Total commodity derivative position $ (1,065,461) $ (401,956) |
Schedule of Net Gain (Loss) on Derivatives | The following table presents the gain and loss recognized in net loss on natural gas, oil and NGL derivatives in the accompanying consolidated statements of operations for the Successor Quarter and Predecessor Quarter (in thousands): Net loss on derivative instruments Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Natural gas derivatives - fair value losses $ (619,319) $ (25,538) Natural gas derivatives - settlement (losses) gains (111,157) 125 Total losses on natural gas derivatives (730,476) (25,413) Oil derivatives - fair value losses (29,853) (1,731) Oil derivatives - settlement losses (8,144) — Total losses on oil derivatives (37,997) (1,731) NGL derivatives - fair value losses (14,333) (2,834) NGL derivatives - settlement losses (5,745) — Total losses on NGL derivatives (20,078) (2,834) Total losses on natural gas, oil and NGL derivatives $ (788,551) $ (29,978) |
Schedule of Recognized Derivative Assets | The following tables present 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 (in thousands): Successor As of March 31, 2022 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 36,416 $ (36,416) $ — Derivative liabilities $ (1,101,877) $ 36,416 $ (1,065,461) Successor As of December 31, 2021 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 23,359 $ (20,265) $ 3,094 Derivative liabilities $ (425,315) $ 20,265 $ (405,050) |
Schedule of Recognized Derivative Liabilities | The following tables present 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 (in thousands): Successor As of March 31, 2022 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 36,416 $ (36,416) $ — Derivative liabilities $ (1,101,877) $ 36,416 $ (1,065,461) Successor As of December 31, 2021 Gross Assets (Liabilities) Gross Amounts Presented in the Subject to Master Net Consolidated Balance Sheets Netting Agreements Amount Derivative assets $ 23,359 $ (20,265) $ 3,094 Derivative liabilities $ (425,315) $ 20,265 $ (405,050) |
FAIR VALUE MEASUREMENTS (Tables
FAIR VALUE MEASUREMENTS (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Fair Value Disclosures [Abstract] | |
Schedule of Financial and Non-Financial Assets and Liabilities by Valuation Level | The following tables summarize the Company’s financial and non-financial assets and liabilities by valuation level as of March 31, 2022 and December 31, 2021 (in thousands): Successor March 31, 2022 Level 1 Level 2 Level 3 Assets: Derivative instruments $ — $ 36,416 $ — Contingent consideration arrangement — — 5,300 Total assets $ — $ 36,416 $ 5,300 Liabilities: Derivative instruments $ — $ 1,101,877 $ — Successor December 31, 2021 Level 1 Level 2 Level 3 Assets: Derivative instruments $ — $ 23,359 $ — Contingent consideration arrangement — — 5,800 Total assets $ — $ 23,359 $ 5,800 Liabilities: Derivative instruments $ — $ 425,315 $ — |
LEASES (Tables)
LEASES (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Leases [Abstract] | |
Schedule of Operating Lease Liability | Future amounts due under operating lease liabilities as of March 31, 2022 were as follows (in thousands): Remaining 2022 $ 137 2023 142 Total lease payments $ 279 Less: Imputed interest (6) Total $ 273 |
Schedule of Lease Cost | Lease costs incurred for the Successor Quarter and Predecessor Quarter consisted of the following (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Operating lease cost $ 50 $ 32 Variable lease cost — — Short-term lease cost 8,622 2,189 Total lease cost (1) $ 8,672 $ 2,221 _____________________ (1) The majority of the Company's total lease cost was capitalized to the full cost pool, and the remainder was included in either lease operating expenses or general and administrative expenses in the accompanying consolidated statements of operations. Supplemental cash flow information related to leases was as follows (in thousands): Successor Predecessor Three Months Ended March 31, 2022 Three Months Ended March 31, 2021 Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 49 $ 31 |
SUBSEQUENT EVENTS (Tables)
SUBSEQUENT EVENTS (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Subsequent Events [Abstract] | |
Schedule of Natural Gas Basis Swap Positions | In addition, the Company entered into natural gas basis swap positions. As of March 31, 2022, the Company had the following natural gas swap positions open: Gulfport Pays Gulfport Receives Daily Volume Weighted Average Fixed Spread Natural Gas (MMBtu/d) ($/MMBtu) 2023 Rex Zone 3 NYMEX Plus Fixed Spread 20,000 $ (0.21) Type of Derivative Instrument Index Daily Volume Weighted Natural Gas (MMBtu/d) ($/MMBtu) January 2023 - December 2023 Fixed price swap NYMEX Henry Hub 10,000 $5.17 January 2023 - December 2023 Costless collar NYMEX Henry Hub 200,000 $3.00 / $5.00 January 2023 - December 2023 Call option NYMEX Henry Hub (100,000) $2.90 January 2024 - December 2024 Fixed price swap NYMEX Henry Hub 10,000 $4.16 January 2024 - December 2024 Call option NYMEX Henry Hub 40,000 $4.65 January 2025 - October 2025 Call option NYMEX Henry Hub 40,000 $4.65 Oil (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap NYMEX WTI 1,000 $87.62 NGL (Bbl/d) ($/Bbl) January 2023 - December 2023 Fixed price swap Mont Belvieu C3 1,000 $44.10 |
BASIS OF PRESENTATION - Schedul
BASIS OF PRESENTATION - Schedule of Accounts Payable and Accrued Liabilities (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Accounting Policies [Abstract] | ||
Accounts payable and other accrued liabilities | $ 183,786 | $ 143,938 |
Revenue payable and suspense | 173,285 | 180,857 |
Accrued contract rejection damages and shares held in reserve | 40,996 | 69,216 |
Total accounts payable and accrued liabilities | $ 398,067 | $ 394,011 |
BASIS OF PRESENTATION - Company
BASIS OF PRESENTATION - Company's consolidated statements of operations (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Accounting Policies [Abstract] | ||
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 | $ 0 | $ 38,721 |
BASIS OF PRESENTATION - Narrati
BASIS OF PRESENTATION - Narrative (Details) $ in Millions | 3 Months Ended |
Mar. 31, 2022USD ($) | |
Accounting Policies [Abstract] | |
Noninterest income | $ 11.5 |
BASIS OF PRESENTATION - Supplem
BASIS OF PRESENTATION - Supplemental Cash and Non Cash Information (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Supplemental disclosure of cash flow information: | ||
Cash paid for reorganization items, net | $ 0 | $ 21,367 |
Interest payments | 2,110 | 4,763 |
Changes in operating assets and liabilities: | ||
Decrease (increase) in accounts receivable - oil and natural gas sales | 25,985 | (14,117) |
Increase in accounts receivable - joint interest and other | (17,722) | (478) |
Increase in accounts payable and accrued liabilities | 2,135 | 15,555 |
Decrease in prepaid expenses | 6,811 | 26,356 |
Increase in other assets | (17) | (655) |
Total changes in operating assets and liabilities | 17,192 | 26,661 |
Supplemental disclosure of non-cash transactions: | ||
Capitalized stock-based compensation | 597 | 630 |
Asset retirement obligation capitalized | 16 | 483 |
Release of common stock held in reserve | 28,220 | 0 |
Foreign currency translation gain on equity method investments | $ 0 | $ 2,570 |
PROPERTY AND EQUIPMENT - Schedu
PROPERTY AND EQUIPMENT - Schedule of Property and Equipment (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Property, Plant and Equipment [Abstract] | ||
Proved oil and natural gas properties | $ 2,030,289 | $ 1,917,833 |
Unproved properties | 203,678 | 211,007 |
Other depreciable property and equipment | 5,034 | 4,943 |
Land | 386 | 386 |
Total property and equipment | 2,239,387 | 2,134,169 |
Accumulated DD&A and impairment | (340,709) | (278,341) |
Total property and equipment, net | $ 1,898,678 | $ 1,855,828 |
PROPERTY AND EQUIPMENT - Narrat
PROPERTY AND EQUIPMENT - Narrative (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Property, Plant and Equipment [Abstract] | ||
Capitalized general and administrative costs | $ 4.7 | $ 5.5 |
PROPERTY AND EQUIPMENT - Summar
PROPERTY AND EQUIPMENT - Summary of Non-producing Properties Excluded from Amortization by Area (Details) $ in Thousands | Mar. 31, 2022USD ($) |
Property, Plant and Equipment [Line Items] | |
Total unproved properties | $ 203,678 |
Utica | |
Property, Plant and Equipment [Line Items] | |
Total unproved properties | 168,809 |
SCOOP | |
Property, Plant and Equipment [Line Items] | |
Total unproved properties | 34,865 |
Other | |
Property, Plant and Equipment [Line Items] | |
Total unproved properties | $ 4 |
PROPERTY AND EQUIPMENT - Sche_2
PROPERTY AND EQUIPMENT - Schedule of Asset Retirement Obligation (Details) - USD ($) $ in Thousands | 3 Months Ended | 5 Months Ended | ||
Mar. 31, 2022 | Mar. 31, 2021 | May 17, 2021 | Dec. 31, 2021 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||
Beginning balance | $ 28,264 | $ 63,566 | $ 63,566 | |
Liabilities incurred | 16 | 483 | ||
Accretion expense | 692 | 805 | ||
Ending balance | 28,972 | 64,854 | ||
Less: amounts reclassified to liabilities subject to compromise | 0 | (64,854) | ||
Total asset retirement obligation reflected as non-current liabilities | $ 28,972 | $ 0 | $ 28,264 |
LONG-TERM DEBT - Summary of Lon
LONG-TERM DEBT - Summary of Long-Term Debt (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Debt Instrument [Line Items] | ||
Net unamortized debt issuance costs | $ (1,004) | $ (1,054) |
Total debt, net | 573,996 | 712,946 |
Less: current maturities of long-term debt | 0 | 0 |
Long-term debt | 573,996 | 712,946 |
Credit Facility | Line of Credit | ||
Debt Instrument [Line Items] | ||
Long-term debt | 25,000 | 164,000 |
8.000% senior unsecured notes due 2026 | ||
Debt Instrument [Line Items] | ||
Long-term debt | $ 550,000 | $ 550,000 |
LONG-TERM DEBT - Narrative (Det
LONG-TERM DEBT - Narrative (Details) - USD ($) | Oct. 14, 2021 | Mar. 31, 2022 | Mar. 31, 2021 | Dec. 31, 2021 | May 17, 2021 |
Oil and Gas Properties | |||||
Debt Instrument [Line Items] | |||||
Interest capitalized | $ 0 | ||||
Senior Notes | Carrying Value | |||||
Debt Instrument [Line Items] | |||||
Carrying value of notes | $ 549,000,000 | ||||
Senior Notes | Fair Value | Level 1 | |||||
Debt Instrument [Line Items] | |||||
Carrying value of notes | 570,100,000 | ||||
8.000% senior unsecured notes due 2026 | |||||
Debt Instrument [Line Items] | |||||
Long-term debt | $ 550,000,000 | $ 550,000,000 | |||
8.000% senior unsecured notes due 2026 | Senior Notes | Fresh Start Adjustments | |||||
Debt Instrument [Line Items] | |||||
Debt instrument, amount | $ 550,000,000 | ||||
Stated interest rate | 8.00% | ||||
Revolving Credit Facility | Credit Facility | |||||
Debt Instrument [Line Items] | |||||
Aggregate maximum principal amount | $ 1,500,000,000 | ||||
Initial borrowing base amount | 850,000,000 | ||||
Line of credit facility, commitment fee amount | $ 700,000,000 | ||||
Unused capacity, commitment fee percentage | 0.50% | ||||
Weight average interest rate | 3.21% | ||||
Debt instrument net funded leverage ratio | 325.00% | ||||
Debt instrument current ratio | 100.00% | 100.00% | |||
Revolving Credit Facility | Credit Facility | Minimum | LIBOR | |||||
Debt Instrument [Line Items] | |||||
Variable interest rate | 2.75% | ||||
Revolving Credit Facility | Credit Facility | Minimum | Base Rate | |||||
Debt Instrument [Line Items] | |||||
Variable interest rate | 1.75% | ||||
Revolving Credit Facility | Credit Facility | Maximum | LIBOR | |||||
Debt Instrument [Line Items] | |||||
Variable interest rate | 3.75% | ||||
Revolving Credit Facility | Credit Facility | Maximum | Base Rate | |||||
Debt Instrument [Line Items] | |||||
Variable interest rate | 2.75% | ||||
Revolving Credit Agreement | Credit Facility | |||||
Debt Instrument [Line Items] | |||||
Long-term debt | $ 25,000,000 | $ 164,000,000 | |||
Letters of credit outstanding, amount | $ 113,200,000 | ||||
Letter of Credit | Credit Facility | |||||
Debt Instrument [Line Items] | |||||
Aggregate maximum principal amount | $ 175,000,000 |
EQUITY AND MEZZANINE EQUITY - N
EQUITY AND MEZZANINE EQUITY - Narrative (Details) - USD ($) | May 17, 2021 | Mar. 31, 2022 | Mar. 31, 2021 | May 17, 2021 | Mar. 31, 2022 | Jan. 31, 2022 | Dec. 31, 2021 | Nov. 01, 2021 |
Class of Stock [Line Items] | ||||||||
Common stock, shares authorized (in shares) | 42,000,000 | 42,000,000 | 42,000,000 | 42,000,000 | ||||
Common stock, par value (in usd per share) | $ 0.0001 | $ 0.0001 | $ 0.0001 | $ 0.0001 | ||||
Temporary equity, shares authorized (in shares) | 110,000 | 110,000 | 110,000 | 110,000 | 110,000 | |||
Temporary equity, par or stated value (in usd per share) | $ 0.0001 | $ 0.0001 | $ 0.0001 | $ 0.0001 | $ 0.0001 | |||
Temporary equity, liquidation preference (in usd per share) | $ 1,000 | $ 1,000 | ||||||
Common stock, shares, issued (in shares) | 19,800,000 | 21,100,000 | 19,800,000 | 21,100,000 | 20,600,000 | |||
Authorized stock repurchase amount | $ 100,000,000 | $ 100,000,000 | $ 100,000,000 | |||||
Stock repurchased during period (in shares) | 438,082 | |||||||
Stock repurchased | $ 35,500,000 | |||||||
Shares repurchased weighted average price (in usd per share) | $ 81.06 | $ 81.06 | ||||||
Preferred stock issued (in shares) | 55,000 | 55,000 | ||||||
Preferred stock, dividend rate | 10.00% | |||||||
Preferred stock, dividend rate, percentage, pain-in-kind | 15.00% | |||||||
Preferred stock, convertible, conversion price (in usd per share) | $ 14 | $ 14 | ||||||
Anti-dilutive shares (in shares) | 0 | 0 | ||||||
Preferred stock, value, outstanding, payment period | 3 days | |||||||
Preferred stock, liquidation preference (in usd per share) | $ 1,000 | $ 1,000 | ||||||
Dividends, preferred stock, cash | $ 1,500,000 | |||||||
Series A Convertible Preferred Stock | ||||||||
Class of Stock [Line Items] | ||||||||
Anti-dilutive shares (in shares) | 4,100,000 | |||||||
Disputed Claims Reserve | Common Stock | ||||||||
Class of Stock [Line Items] | ||||||||
Plan of reorganization, number of shares issued (in shares) | 1,700,000 | 62,000 | 1,700,000 | 62,000 | 876,000 |
EQUITY AND MEZZANINE EQUITY - S
EQUITY AND MEZZANINE EQUITY - Schedule of Dividends (Details) | 3 Months Ended |
Mar. 31, 2022shares | |
Increase (Decrease) in Temporary Equity [Roll Forward] | |
Temporary equity, beginning shares outstanding (in shares) | 57,896 |
Conversion of New Preferred Stock (in shares) | (18) |
Temporary equity, ending shares outstanding (in shares) | 57,878 |
STOCK-BASED COMPENSATION - Narr
STOCK-BASED COMPENSATION - Narrative (Details) - USD ($) $ in Millions | 3 Months Ended | 5 Months Ended | 10 Months Ended | |||
Mar. 31, 2022 | Mar. 31, 2021 | May 17, 2021 | Mar. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Common stock, capital shares reserved for future issuance (in shares) | 62,000 | 62,000 | 938,000 | |||
2021 Stock Incentive Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Common stock, capital shares reserved for future issuance (in shares) | 2,800,000 | |||||
Restricted Stock Units | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Stock-based compensation cost | $ 3 | $ 1.8 | ||||
Capitalized stock-based compensation cost | $ 0.6 | $ 0.6 | ||||
Share-based compensation arrangement by share-based payment award (in shares) | 196,336 | 1,480,223 | 196,336 | 198,413 | 1,702,513 | |
Unrecognized compensation expense to be expected | $ 10 | $ 10 | ||||
Unrecognized compensation expense expected to be recognized | 2 years 7 months 17 days | |||||
Restricted Stock Units | Employee | 2021 Stock Incentive Plan | Minimum | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 1 year | |||||
Restricted Stock Units | Employee | 2021 Stock Incentive Plan | Maximum | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 4 years | |||||
Restricted Stock Units | Employee | 2019 Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 3 years | |||||
Restricted Stock Units | Director | 2021 Stock Incentive Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 4 years | |||||
Restricted Stock Units | Director | 2019 Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Vesting period | 1 year | |||||
Performance Stock Units | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Share-based compensation arrangement by share-based payment award (in shares) | 153,138 | 840,595 | 153,138 | 153,138 | 840,595 | |
Unrecognized compensation expense to be expected | $ 5.7 | $ 5.7 | ||||
Percent of target based award, minimum | 0.00% | |||||
Percent of target based award, maximum | 200.00% | |||||
Performance Stock Units | 2021 Stock Incentive Plan | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Unrecognized compensation expense expected to be recognized | 2 years 1 month 17 days | |||||
Percent of target based award, minimum | 0.00% | |||||
Percent of target based award, maximum | 200.00% |
STOCK-BASED COMPENSATION - Rest
STOCK-BASED COMPENSATION - Restricted Stock Award and Unit Activity (Details) - $ / shares | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Restricted Stock Units | ||
Number of Unvested Restricted Shares | ||
Beginning balance (in shares) | 198,413 | 1,702,513 |
Granted (in shares) | 2,154 | 0 |
Vested (in shares) | (3,074) | (202,583) |
Forfeited/canceled (in shares) | (1,157) | (19,707) |
Ending balance (in shares) | 196,336 | 1,480,223 |
Weighted Average Grant Date Fair Value | ||
Beginning balance (in usd per share) | $ 66.04 | $ 4.74 |
Granted (in usd per share) | 73.83 | 0 |
Vested (in usd per share) | 65.75 | 8.32 |
Forfeited/canceled (in usd per share) | 66.89 | 3.61 |
Ending balance (in usd per share) | $ 67.16 | $ 4.26 |
Performance Stock Units | ||
Number of Unvested Restricted Shares | ||
Beginning balance (in shares) | 153,138 | 840,595 |
Granted (in shares) | 0 | 0 |
Vested (in shares) | 0 | 0 |
Forfeited/canceled (in shares) | 0 | 0 |
Ending balance (in shares) | 153,138 | 840,595 |
Weighted Average Grant Date Fair Value | ||
Beginning balance (in usd per share) | $ 48.54 | $ 4.07 |
Granted (in usd per share) | 0 | 0 |
Vested (in usd per share) | 0 | 0 |
Forfeited/canceled (in usd per share) | 0 | 0 |
Ending balance (in usd per share) | $ 48.54 | $ 4.07 |
EARNINGS PER SHARE (Details)
EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||
Anti-dilutive shares (in shares) | 0 | 0 |
Net (loss) income | $ (491,975) | $ 8,780 |
Dividends on preferred stock | (1,447) | 0 |
Participating securities - preferred stock | 0 | 0 |
Net (loss) income attributable to common stockholders, basic | (493,422) | 8,780 |
Net (loss) income attributable to common stockholders, diluted | $ (493,422) | $ 8,780 |
Basic shares (in shares) | 21,242,000 | 160,813,000 |
Basic (in usd per share) | $ (23.23) | $ 0.05 |
Diluted (in usd per share) | $ (23.23) | $ 0.05 |
Series A Convertible Preferred Stock | ||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||
Anti-dilutive shares (in shares) | 4,100,000 | |
Restricted Stock | ||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||
Anti-dilutive shares (in shares) | 100,000 |
COMMITMENTS AND CONTINGENCIES_2
COMMITMENTS AND CONTINGENCIES (Schedule of Firm Transportation Contracts) (Details) - Transportation Commitment $ in Thousands | Mar. 31, 2022USD ($) |
Other Commitments [Line Items] | |
Remaining 2022 | $ 180,807 |
2023 | 229,733 |
2024 | 220,708 |
2025 | 139,706 |
2026 | 136,235 |
Thereafter | 889,674 |
Total | $ 1,796,863 |
COMMITMENTS AND CONTINGENCIES_3
COMMITMENTS AND CONTINGENCIES (Narrative) (Details) - TC Energy Corporation and Rover Pipeline LLC v. Gulfport Energy Corporation - USD ($) $ in Millions | Oct. 07, 2021 | May 17, 2021 | Feb. 28, 2022 |
Commitments And Contingencies [Line Items] | |||
Litigation amount settlement | $ 43.8 | $ 11.5 | |
Loss contingency, damages sought | $ 64 |
DERIVATIVE INSTRUMENTS (Schedul
DERIVATIVE INSTRUMENTS (Schedule of Derivative Instruments) (Details) | 3 Months Ended |
Mar. 31, 2022MMBTU$ / MMBTU$ / bblbbl | |
NYMEX Henry Hub - Remaining 2022 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 190,145 |
Weighted average price (in usd per MMBtu or Bbl) | 2.90 |
NYMEX Henry Hub - Remaining 2022 | Call option | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 152,675 |
Weighted average price (in usd per MMBtu or Bbl) | 2.90 |
NYMEX Henry Hub - 2023 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 155,014 |
Weighted average price (in usd per MMBtu or Bbl) | 3.54 |
NYMEX Henry Hub - 2023 | Call option | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 507,925 |
Weighted average price (in usd per MMBtu or Bbl) | 2.90 |
NYMEX Henry Hub - 2024 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 24,973 |
Weighted average price (in usd per MMBtu or Bbl) | 3.62 |
NYMEX Henry Hub - 2024 | Call option | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 162,000 |
Weighted average price (in usd per MMBtu or Bbl) | 3 |
NYMEX WTI - Remaining 2022 | |
Derivative [Line Items] | |
Daily Volume (Bbl/d) | bbl | 2,335 |
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 66.17 |
NYMEX WTI - 2023 | |
Derivative [Line Items] | |
Daily Volume (Bbl/d) | bbl | 2,000 |
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 67.89 |
Mont Belvieu C3 - Remaining 2022 | |
Derivative [Line Items] | |
Daily Volume (Bbl/d) | bbl | 3,502 |
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 35.62 |
Mont Belvieu C3 - 2023 | |
Derivative [Line Items] | |
Daily Volume (Bbl/d) | bbl | 2,000 |
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 35.05 |
NYMEX Henry Hub - Remaining 2022 Index1 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 431,391 |
Weighted average floor price (in usd per MMBtu) | 2.56 |
Weighted average ceiling price (in usd per MMBtu) | 3.07 |
NYMEX Henry Hub Index 1 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 85,000 |
Weighted average floor price (in usd per MMBtu) | 2.75 |
Weighted average ceiling price (in usd per MMBtu) | 4.25 |
NYMEX WTI 2022 Index 1 | |
Derivative [Line Items] | |
Daily Volume (Bbl/d) | bbl | 1,500 |
Weighted average floor price (in usd per MMBtu) | $ / bbl | 55 |
Weighted average ceiling price (in usd per MMBtu) | $ / bbl | 60 |
Basis Swap, Rex Zone 3 - 2022 | |
Derivative [Line Items] | |
Daily volume (in MMBtu) | MMBTU | 20,000 |
Weighted average price (in usd per MMBtu or Bbl) | (0.21) |
DERIVATIVE INSTRUMENTS (Derivat
DERIVATIVE INSTRUMENTS (Derivative Instruments in Financial Position) (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Derivatives, Fair Value [Line Items] | ||
Short-term derivative asset | $ 15,720 | $ 4,695 |
Long-term derivative asset | 20,696 | 18,664 |
Short-term derivative liability | (820,255) | (240,735) |
Long-term derivative liability | (281,622) | (184,580) |
Commodity Contracts | ||
Derivatives, Fair Value [Line Items] | ||
Short-term derivative asset | 15,720 | 4,695 |
Long-term derivative asset | 20,696 | 18,664 |
Short-term derivative liability | (820,255) | (240,735) |
Long-term derivative liability | (281,622) | (184,580) |
Total net (liability) asset derivative position | $ (1,065,461) | $ (401,956) |
DERIVATIVE INSTRUMENTS (Gain an
DERIVATIVE INSTRUMENTS (Gain and Loss on Derivative Instruments) (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Derivative [Line Items] | ||
Gain (loss) on derivative instruments, net, pretax | $ (788,551) | $ (29,978) |
Total losses on natural gas derivatives | ||
Derivative [Line Items] | ||
Fair value (losses) gains | (619,319) | (25,538) |
Settlement (losses) gains | (111,157) | 125 |
Gain (loss) on derivative instruments, net, pretax | (730,476) | (25,413) |
Total losses on oil derivatives | ||
Derivative [Line Items] | ||
Fair value (losses) gains | (29,853) | (1,731) |
Settlement (losses) gains | (8,144) | 0 |
Gain (loss) on derivative instruments, net, pretax | (37,997) | (1,731) |
Total losses on NGL derivatives | ||
Derivative [Line Items] | ||
Fair value (losses) gains | (14,333) | (2,834) |
Settlement (losses) gains | (5,745) | 0 |
Gain (loss) on derivative instruments, net, pretax | $ (20,078) | $ (2,834) |
DERIVATIVE INSTRUMENTS (Sched_2
DERIVATIVE INSTRUMENTS (Schedule of Offsetting) (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
General Discussion of Derivative Instruments and Hedging Activities [Abstract] | ||
Derivative asset, gross asset | $ 36,416 | $ 23,359 |
Derivative asset, netting adjustment | (36,416) | (20,265) |
Derivative asset, net | 0 | 3,094 |
Derivative liability, gross liability | (1,101,877) | (425,315) |
Derivative liability, netting adjustment | 36,416 | 20,265 |
Derivative liability, net | $ (1,065,461) | $ (405,050) |
FAIR VALUE MEASUREMENTS (Assets
FAIR VALUE MEASUREMENTS (Assets and Liabilities Valuation Level) (Details) - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Assets: | ||
Contingent consideration arrangement | $ 5,300 | |
Level 1 | ||
Assets: | ||
Derivative instruments | 0 | $ 0 |
Contingent consideration arrangement | 0 | 0 |
Total assets | 0 | 0 |
Liabilities: | ||
Derivative instruments | 0 | 0 |
Level 2 | ||
Assets: | ||
Derivative instruments | 36,416 | 23,359 |
Contingent consideration arrangement | 0 | 0 |
Total assets | 36,416 | 23,359 |
Liabilities: | ||
Derivative instruments | 1,101,877 | 425,315 |
Level 3 | ||
Assets: | ||
Derivative instruments | 0 | 0 |
Contingent consideration arrangement | 5,300 | 5,800 |
Total assets | 5,300 | 5,800 |
Liabilities: | ||
Derivative instruments | $ 0 | $ 0 |
FAIR VALUE MEASUREMENTS (Narrat
FAIR VALUE MEASUREMENTS (Narrative) (Details) $ in Millions | 3 Months Ended |
Mar. 31, 2022USD ($) | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Contingent consideration arrangement | $ 5.3 |
Contingent consideration, gain (loss) due to change in value | 0.1 |
Prepaid Expenses and Other Current Assets | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Contingent consideration arrangement | 0.8 |
Other Noncurrent Assets | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Contingent consideration arrangement | $ 4.5 |
REVENUE FROM CONTRACTS WITH C_2
REVENUE FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Dec. 31, 2021 | |
Disaggregation of Revenue [Line Items] | ||
Performance obligation period | 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 | |
Receivables from customers | $ 206,869 | $ 232,854 |
Maximum | ||
Disaggregation of Revenue [Line Items] | ||
Performance obligation period | 30 days |
LEASES (Narrative) (Details)
LEASES (Narrative) (Details) | Mar. 31, 2022 |
Lessee, Lease, Description [Line Items] | |
Weighted average remaining lease term | 1 year 6 months 21 days |
Weighted-average discount rate - operating leases | 2.38% |
Minimum | |
Lessee, Lease, Description [Line Items] | |
Lease term | 1 year |
Maximum | |
Lessee, Lease, Description [Line Items] | |
Lease term | 5 years |
LEASES (Maturities of Lease Lia
LEASES (Maturities of Lease Liabilities) (Details) $ in Thousands | Mar. 31, 2022USD ($) |
Leases [Abstract] | |
Remaining 2022 | $ 137 |
2023 | 142 |
Total lease payments | 279 |
Less: Imputed interest | (6) |
Total | $ 273 |
LEASES (Lease Cost) (Details)
LEASES (Lease Cost) (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Leases [Abstract] | ||
Operating lease cost | $ 50 | $ 32 |
Variable lease cost | 0 | 0 |
Short-term lease cost | 8,622 | 2,189 |
Total lease cost | $ 8,672 | $ 2,221 |
LEASES (Other Information) (Det
LEASES (Other Information) (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Leases [Abstract] | ||
Operating cash flows from operating leases | $ 49 | $ 31 |
INCOME TAXES (Details)
INCOME TAXES (Details) $ in Millions | 3 Months Ended |
Mar. 31, 2022USD ($) | |
Income Tax Disclosure [Abstract] | |
Effective tax rate | 0.00% |
Federal tax rate | 21.00% |
Reorganization, chapter 11 bankruptcy proceedings, the estimated in equity values of CODI | $ 661 |
SUBSEQUENT EVENTS (Details)
SUBSEQUENT EVENTS (Details) | May 02, 2022USD ($) | Oct. 14, 2021USD ($) | Apr. 25, 2022MMBTU$ / MMBTU$ / bblbbl | Mar. 31, 2022USD ($)MMBTU$ / bbl$ / MMBTUbbl | Apr. 30, 2022USD ($) | Nov. 01, 2021USD ($) |
Subsequent Event [Line Items] | ||||||
Authorized stock repurchase amount | $ | $ 100,000,000 | $ 100,000,000 | ||||
Revolving Credit Facility | Credit Facility | ||||||
Subsequent Event [Line Items] | ||||||
Initial borrowing base amount | $ | $ 850,000,000 | |||||
Line of credit facility, commitment fee amount | $ | $ 700,000,000 | |||||
Debt instrument current ratio | 100.00% | 100.00% | ||||
Subsequent Event | ||||||
Subsequent Event [Line Items] | ||||||
Authorized stock repurchase amount | $ | $ 200,000,000 | |||||
Subsequent Event | Revolving Credit Facility | Credit Facility | ||||||
Subsequent Event [Line Items] | ||||||
Initial borrowing base amount | $ | $ 1,000,000,000 | |||||
Debt instrument current ratio | 125.00% | |||||
NYMEX Henry Hub - 2023 | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 155,014 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 3.54 | |||||
NYMEX Henry Hub - 2023 | Subsequent Event | Fixed price swap | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 10,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 5.17 | |||||
NYMEX Henry Hub - 2023 | Subsequent Event | Costless collar | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 200,000 | |||||
NYMEX Henry Hub - 2023 | Subsequent Event | Costless collar | Minimum | ||||||
Subsequent Event [Line Items] | ||||||
Weighted average price (in usd per MMBtu or Bbl) | 3 | |||||
NYMEX Henry Hub - 2023 | Subsequent Event | Costless collar | Maximum | ||||||
Subsequent Event [Line Items] | ||||||
Weighted average price (in usd per MMBtu or Bbl) | 5 | |||||
NYMEX Henry Hub - 2023 | Subsequent Event | Call option | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 100,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 2.90 | |||||
NYMEX Henry Hub - 2024 | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 24,973 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 3.62 | |||||
NYMEX Henry Hub - 2024 | Subsequent Event | Fixed price swap | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 10,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 4.16 | |||||
NYMEX Henry Hub - 2024 | Subsequent Event | Call option | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 40,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 4.65 | |||||
NYMEX Henry Hub 2025 | Subsequent Event | Call option | ||||||
Subsequent Event [Line Items] | ||||||
Daily volume (in MMBtu) | MMBTU | 40,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | 4.65 | |||||
NYMEX WTI - 2023 | ||||||
Subsequent Event [Line Items] | ||||||
Daily Volume (Bbl/d) | bbl | 2,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 67.89 | |||||
NYMEX WTI - 2023 | Subsequent Event | Fixed price swap | ||||||
Subsequent Event [Line Items] | ||||||
Daily Volume (Bbl/d) | bbl | 1,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 87.62 | |||||
Mont Belvieu C3 Swap 2023 | Subsequent Event | Fixed price swap | ||||||
Subsequent Event [Line Items] | ||||||
Daily Volume (Bbl/d) | bbl | 1,000 | |||||
Weighted average price (in usd per MMBtu or Bbl) | $ / bbl | 44.10 |