Gulfport Energy Corporation

05/06/2026 | Press release | Distributed by Public on 05/06/2026 11:34

Quarterly Report for Quarter Ending March 31, 2026 (Form 10-Q)

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Introduction
Management's Discussion and Analysis of Financial Condition and Results of Operations (MD&A) is intended to provide the reader of the financial statements with a narrative from the perspective of management on the financial condition, results of operations, liquidity and certain other factors that may affect the Company's operating results. MD&A should be read in conjunction with the financial statements and related Notes included in Part I, Item 1 of this Quarterly Report on Form 10-Q.
The following information updates the discussion of Gulfport's financial condition provided in its Annual Report on Form 10-K for the year ended December 31, 2025 ("2025 Form 10-K"), and analyzes the changes in the results of operations between the periods of January 1, 2026 through March 31, 2026 and January 1, 2025 through March 31, 2025. For definitions of commonly used natural gas and oil terms found in this Quarterly Report on Form 10-Q, please refer to the "Definitions" provided in this report.
Overview
Gulfport is an independent natural gas-weighted exploration and production company with assets primarily located in the Appalachia and Anadarko basins. Our principal operations target the Utica and Marcellus formations in eastern Ohio and the SCOOP Woodford and Springer formations in central Oklahoma. Our strategy is to develop our assets in a safe, environmentally responsible manner, while generating sustainable cash flow, improving margins and operating efficiencies and returning capital to shareholders. To accomplish these goals, we generally allocate capital to projects we believe offer the highest rate of return and we deploy leading drilling and completion techniques and technologies in our development efforts.
Recent Developments
Resignation of John Reinhart, as President, Chief Executive Officer and Director
On March 6, 2026, our President, Chief Executive Officer ("CEO") and Director, John Reinhart, elected to depart the Company and resigned from our Board of Directors, effective immediately. Following his departure, our Board of Directors established an Office of the Chairman to assume executive oversight while we conduct a search for a permanent CEO. The Office of the Chairman is led by Timothy J. Cutt, Chairman of the Board and former CEO from May 2021 through January 2023, and includes Michael Hodges, Executive Vice President and Chief Financial Officer; Matthew Rucker, Executive Vice President and Chief Operating Officer; and Patrick Craine, Executive Vice President and Chief Legal and Administrative Officer.
Credit Facility
On May 1, 2026, the Company completed its semi-annual borrowing base redetermination under its Credit Facility during which the borrowing base was reaffirmed at $1.1 billion and elected commitments were increased to $1.1 billion.
Share Repurchase Program
During the three months ended March 31, 2026, the Company repurchased 866,279 shares for $172.8 million at a weighted average price of $199.45 per share. As of March 31, 2026, the Company repurchased 8.2 million shares for $1.1 billion at a weighted average price of $133.02 per share since the inception of the Repurchase Program.
Tariffs and Trading Relationships
In 2025 and 2026, the U.S. government threatened, announced and, in certain cases, rescinded, tariffs on several foreign jurisdictions and imports into the United States, which led, and may continue to lead, to the imposition of retaliatory tariffs and other measures taken by foreign jurisdictions. There is significant uncertainty as to the scope and durability of existing and future tariff measures, as well as the ultimate effects of the tariffs on economic conditions.
Geopolitical and Market Conditions
Ongoing geopolitical instability, including the conflict involving Iran and heightened tensions in the Middle East, has contributed to increased volatility in global energy markets. While the Company does not have operations or assets in the affected regions, these events may impact commodity prices, global supply and demand dynamics, and overall market conditions. As of the date of this filing, the Company has not experienced any material direct impacts to its operations, liquidity, or financial condition as a result of these developments.
2026 Operational and Financial Highlights
During the first quarter of 2026, we had the following notable achievements:
•Reported total net production of 996.8 MMcfe per day.
•Turned to sales five gross (4.96 net) operated wells.
•Generated $292.9 million of operating cash flows.
•Repurchased 866,279 shares for $172.8 million at a weighted average price of $199.45 per share.
•Exited the quarter with total liquidity of $772.2 million.
2026 Production and Drilling Activity
Production Volumes
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025
Natural gas (Mcf/day)
Utica & Marcellus 782,851 686,964
SCOOP 122,919 150,851
Total 905,770 837,816
Oil and condensate (Bbl/day)
Utica & Marcellus 2,533 3,861
SCOOP 1,205 1,420
Total 3,738 5,282
NGL (Bbl/day)
Utica & Marcellus 5,827 3,495
SCOOP 5,605 6,467
Total 11,432 9,962
Combined (Mcfe/day)
Utica & Marcellus 833,010 731,105
SCOOP 163,776 198,175
Total 996,786 929,280
Totals may not sum or recalculate due to rounding.
Our total net production averaged approximately 996.8 MMcfe per day during the three months ended March 31, 2026, as compared to 929.3 MMcfe per day during the three months ended March 31, 2025. Production per day increased primarily due to the timing of our 2025 and 2026 development programs.
Utica/Marcellus. We spud 9 gross (8.86 net) operated wells targeting the Utica and Marcellus formations and commenced sales from 5 gross (4.96 net) operated Utica wells during the three months ended March 31, 2026.
SCOOP. We spud 2 gross (1.60 net) operated wells in the SCOOP during the three months ended March 31, 2026.
RESULTS OF OPERATIONS
Comparison of the Three Month Periods Ended March 31, 2026 and 2025
Natural Gas, Oil and Condensate and NGL Production and Pricing (sales totals in thousands)
The following table summarizes our natural gas, oil and condensate and NGL production, and related pricing for the three months ended March 31, 2026 as compared to the three months ended March 31, 2025. Some totals below may not sum or recalculate due to rounding.
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025
Natural gas sales
Natural gas production volumes (MMcf) 81,519 75,403
Natural gas production volumes (MMcf) per day 906 838
Total sales $ 399,530 $ 281,506
Average price without the impact of derivatives ($/Mcf) $ 4.90 $ 3.73
Impact from settled derivatives ($/Mcf) $ (0.68) $ (0.12)
Average price, including settled derivatives ($/Mcf) $ 4.22 $ 3.61
Oil and condensate sales
Oil and condensate production volumes (MBbl) 336 475
Oil and condensate production volumes (MBbl) per day 4 5
Total sales $ 22,338 $ 31,259
Average price without the impact of derivatives ($/Bbl) $ 66.40 $ 65.76
Impact from settled derivatives ($/Bbl) $ (4.80) $ 1.06
Average price, including settled derivatives ($/Bbl) $ 61.60 $ 66.82
NGL sales
NGL production volumes (MBbl) 1,029 897
NGL production volumes (MBbl) per day 11 10
Total sales $ 31,477 $ 30,817
Average price without the impact of derivatives ($/Bbl) $ 30.59 $ 34.37
Impact from settled derivatives ($/Bbl) $ 0.75 $ (1.53)
Average price, including settled derivatives ($/Bbl) $ 31.34 $ 32.84
Natural gas, oil and condensate and NGL sales
Natural gas equivalents (MMcfe) 89,711 83,635
Natural gas equivalents (MMcfe) per day 997 929
Total sales $ 453,345 $ 343,582
Average price without the impact of derivatives ($/Mcfe) $ 5.05 $ 4.11
Impact from settled derivatives ($/Mcfe) $ (0.63) $ (0.12)
Average price, including settled derivatives ($/Mcfe) $ 4.42 $ 3.99
Production Costs:
Average lease operating expenses ($/Mcfe) $ 0.27 $ 0.24
Average taxes other than income ($/Mcfe) $ 0.10 $ 0.08
Average transportation, gathering, processing and compression ($/Mcfe) $ 1.01 $ 0.99
Total lease operating expenses, taxes other than income and midstream costs ($/Mcfe) $ 1.38 $ 1.31
Natural Gas, Oil and Condensate and NGL Sales (in thousands)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Natural gas $ 399,530 $ 281,506 42 %
Oil and condensate 22,338 31,259 (29) %
NGL 31,477 30,817 2 %
Natural gas, oil and condensate and NGL sales $ 453,345 $ 343,582 32 %
The increase in natural gas sales without the impact of derivatives when comparing the three months ended March 31, 2026, to the three months ended March 31, 2025 was due to a 31% increase in realized natural gas prices and an 8% increase in sales volumes. The realized price change was primarily driven by the increase in the average Henry Hub gas index from $3.65 per Mcf in the three months ended March 31, 2025, to $5.04 per Mcf during the three months ended March 31, 2026. The 8% increase in natural gas production was primarily due to the timing of our 2025 and 2026 development programs.
The decrease in oil and condensate sales without the impact of derivatives when comparing the three months ended March 31, 2026, to the three months ended March 31, 2025, was due to a 29% decrease in sales volumes, partially offset by a 2% increase in realized prices. The 29% decrease in oil and condensate production was primarily due to natural declines partially offset by our 2025 and 2026 development programs. The realized price change was primarily driven by the increase in the average WTI crude index from $71.42 per barrel in the three months ended March 31, 2025, to $71.93 per barrel during the three months ended March 31, 2026.
The increase in NGL sales without the impact of derivatives when comparing the three months ended March 31, 2026, to the three months ended March 31, 2025, was due to a 15% increase in NGL sales volumes, partially offset by an 11% decrease in realized prices. The 15% increase in NGL production was primarily due to commencement of sales on new wells targeting the Utica and Marcellus liquids windows.
Natural Gas, Oil and NGL Derivatives (in thousands)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025
Natural gas derivatives - fair value gains (losses) $ 57,593 $ (133,664)
Natural gas derivatives - settlement losses (55,906) (9,025)
Total gains (losses) on natural gas derivatives 1,687 (142,689)
Oil and condensate derivatives - fair value losses (9,880) (6)
Oil and condensate derivatives - settlement (losses) gains (1,616) 504
Total (losses) gains on oil and condensate derivatives (11,496) 498
NGL derivatives - fair value losses (6,772) (2,988)
NGL derivatives - settlement gains (losses) 768 (1,369)
Total losses on NGL derivatives (6,004) (4,357)
Total losses on natural gas, oil and NGL derivatives $ (15,813) $ (146,548)
We recognize fair value changes on our natural gas, oil and NGL derivative instruments in each reporting period. The changes in fair value resulted from new positions and settlements that occurred during each period, as well as the relationship between contract prices and the associated forward curves. The change in the total loss for the three months ended March 31, 2026 compared to the three months ended March 31, 2025, was primarily the result of changes in futures pricing for oil, natural gas, and NGLs during each period. See Note 10 of our consolidated financial statements for hedged volumes and pricing.
Lease Operating Expenses (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Lease operating expenses
Utica & Marcellus $ 19,316 $ 13,592 42 %
SCOOP 5,140 6,691 (23) %
Total lease operating expenses $ 24,456 $ 20,283 21 %
Lease operating expenses per Mcfe
Utica & Marcellus $ 0.26 $ 0.21 25 %
SCOOP 0.35 0.38 (7) %
Total lease operating expenses per Mcfe $ 0.27 $ 0.24 12 %
The increase in our total and per unit LOE for the three months ended March 31, 2026 compared to the three months ended March 31, 2025, was primarily the result of an increase in compression, water hauling and labor expenses.
Taxes Other Than Income (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Production taxes $ 5,890 $ 5,438 8 %
Property taxes 2,210 428 416 %
Other 1,084 760 43 %
Total taxes other than income $ 9,184 $ 6,626 39 %
Total taxes other than income per Mcfe $ 0.10 $ 0.08 29 %
The increase in total and per unit taxes other than income for the three months ended March 31, 2026 compared to the three months ended March 31, 2025, was primarily related to an increase in property taxes and an increase in natural gas sales as discussed above.
Transportation, Gathering, Processing and Compression (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Transportation, gathering, processing and compression $ 90,567 $ 82,870 9 %
Transportation, gathering, processing and compression per Mcfe $ 1.01 $ 0.99 2 %
Transportation, gathering, processing and compression for the three months ended March 31, 2026 compared to the three months ended March 31, 2025, increased on a total and per unit basis primarily as a result of a 7% increase in total production volumes.
Depreciation, Depletion and Amortization (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Depreciation, depletion and amortization of oil and gas properties $ 74,876 $ 65,090 15 %
Depreciation, depletion and amortization of other property and equipment 554 532 4 %
Total depreciation, depletion and amortization $ 75,430 $ 65,622 15 %
Depreciation, depletion and amortization per Mcfe $ 0.84 $ 0.78 7 %
The total and per unit depreciation, depletion and amortization for the three months ended March 31, 2026 compared to the three months ended March 31, 2025, increased primarily due to a higher depletion rate driven by our drilling and development activities subsequent to the first quarter of 2025.
General and Administrative Expenses (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
General and administrative expenses, gross $ 19,277 $ 19,199 - %
Reimbursed from third parties (4,046) (3,966) 2 %
Capitalized general and administrative expenses (5,523) (6,232) (11) %
General and administrative expenses, net $ 9,708 $ 9,001 8 %
General and administrative expenses, net per Mcfe $ 0.11 $ 0.11 1 %
The increase in total general and administrative expenses for the three months ended March 31, 2026 compared to March 31, 2025, was primarily driven by increases in employee compensation expenses, legal expenses primarily related to activity disclosed in Note 9 of our consolidated financial statements and expenses associated with the Chief Executive Officer search partially offset by a decrease in stock compensation expense related to the forfeitures of unvested restricted stock units and performance vesting restricted stock units due to the departure of the Company's Chief Executive Officer during the quarter. General and administrative expenses on a per unit basis remained consistent, as production volumes increased comparable to general and administrative expenses.
Interest Expense (in thousands, except per unit)
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025 % Change
Interest on 2026 Senior Notes $ - $ 514 (100) %
Interest on 2029 Senior Notes 10,969 10,969 - %
Interest expense on Credit Facility 4,283 1,685 154 %
Amortization of loan costs 1,338 1,300 3 %
Capitalized interest (1,425) (1,430) - %
Other 221 318 (31) %
Total interest expense $ 15,386 $ 13,356 15 %
Interest expense per Mcfe $ 0.17 $ 0.16 7 %
Total interest expense for the three months ended March 31, 2026, increased 15% compared to the three months ended March 31, 2025 which was primarily due to higher borrowings on our Credit Facility. See Note 4 of our consolidated financial statements for further details regarding our long-term debt.
Income Taxes
We recorded an income tax expense of $44.7 million for the three months ended March 31, 2026 compared to income tax benefit of $0.2 million for the three months ended March 31, 2025. See Note 14 of our consolidated financial statements for further discussion of our income tax expense.
Liquidity and Capital Resources
Overview. We strive to maintain sufficient liquidity to ensure financial flexibility, withstand commodity price volatility, fund our development projects, operations and capital expenditures and return capital to shareholders. We utilize derivative contracts to reduce the financial impact of commodity price volatility and provide a level of certainty to the Company's cash flows. We generally fund our operations, planned capital expenditures and any share repurchases with cash flow from our operating activities, cash on hand, and borrowings under our Credit Facility. Additionally, we may access debt and equity markets and sell properties to enhance our liquidity. There is no guarantee that the debt or equity capital markets will be available to us on acceptable terms or at all.
For the three months ended March 31, 2026, our primary sources of capital resources and liquidity have consisted of internally generated cash flows from operations and access to our Credit Facility, and our primary uses of cash have been for development of our oil and natural gas properties, share repurchases and interest payments.
We believe our annual free cash flow generation, borrowing capacity under the Credit Facility and cash on hand will provide sufficient liquidity to fund our operations, working capital, capital expenditures, interest expense and share repurchases during the next 12 months and the foreseeable future.
To the extent actual operating results, realized commodity prices or uses of cash differ from our assumptions, our liquidity could be adversely affected. See Note 4 of our consolidated financial statements for further discussion of our debt obligations, including the principal and carrying amounts of our senior notes.
As of March 31, 2026, we had $2.9 million of cash and cash equivalents, $182.0 million of outstanding borrowings under our Credit Facility, $48.7 million of letters of credit outstanding and $650.0 million of outstanding 2029 Senior Notes. Our total principal amount of funded debt as of March 31, 2026 was $832.0 million.
As of April 29, 2026 we had $2.5 million of cash and cash equivalents, $169.0 million in borrowings under our Credit Facility, $48.7 million of letters of credit outstanding and $650.0 million of outstanding 2029 Senior Notes.
Debt. As of March 31, 2026, we were in compliance with all financial covenants and had approximately $769.3 million of availability under the Credit Facility. The Credit Facility is subject to semi-annual borrowing base redeterminations primarily based on projected future cash flows.
See Note 4 of our consolidated financial statements for additional discussion of our outstanding debt.
Dividends on Preferred Stock. We redeemed the remaining outstanding balance of our preferred stock on September 5, 2025. During the three months ended March 31, 2025, the Company paid $0.9 million of cash dividends to holders of our preferred stock.
Supplemental Guarantor Financial Information. The 2029 Senior Notes are guaranteed on a senior unsecured basis by Gulfport and certain of Gulfport's wholly owned subsidiaries (collectively, the "2029 Senior Notes Guarantors" and, together with the 2026 Senior Notes Guarantors, the "Guarantors") and certain future subsidiaries of Gulfport that become borrowers or guarantors under any credit agreement with an aggregate principal amount outstanding or commitment amount in excess of $15 million. The 2029 Senior Notes Guarantors are 100% owned by the Parent, and the guarantees are full, unconditional, joint and several. There are no significant restrictions on the ability of the Parent or the 2029 Senior Notes Guarantors to obtain funds from each other in the form of a dividend or loan. The guarantees rank (i) senior in right of payment to any future subordinated indebtedness of Gulfport Operating or the 2029 Senior Notes Guarantors, (ii) pari passu in right of payment with all existing and future unsecured senior indebtedness of Gulfport Operating or the 2029 Senior Notes Guarantors, (iii) effectively junior to any secured indebtedness of Gulfport Operating or the 2029 Senior Notes Guarantors, including indebtedness under the credit agreement, to the extent of the value of the collateral securing such indebtedness, and (iv) structurally subordinated in right of payment to all indebtedness and other liabilities of Gulfport Operating's subsidiaries that are not 2029 Senior Notes Guarantors.
SEC Regulation S-X Rule 13-01 requires the presentation of "Summarized Financial Information" to replace the "Condensed Consolidating Financial Information" required under Rule 3-10. Rule 13-01 allows the omission of Summarized Financial Information if assets, liabilities and results of operations of the Guarantors are not materially different than the corresponding amounts presented in our consolidated financial statements. The Parent and Guarantor subsidiaries comprise our material operations. Therefore, we concluded that the presentation of the Summarized Financial Information is not required as our Summarized Financial Information of the Guarantors is not materially different from our consolidated financial statements.
Derivatives and Hedging Activities. Our results of operations and cash flows are impacted by changes in market prices for natural gas, oil and NGL. To mitigate a portion of the exposure to adverse market changes, we have entered into various derivative instruments. Our natural gas, oil and NGL derivative activities, when combined with our sales of natural gas, oil and NGL, allow us to predict with greater certainty the total revenue we will receive. See Item 3 "Quantitative and Qualitative Disclosures About Market Risk" for further discussion on the impact of commodity price risk on our financial position. Additionally, see Note 10 of our consolidated financial statements for further discussion of derivatives and hedging activities.
Capital Expenditures. Our capital expenditures have historically been related to the execution of our drilling and completion activities in addition to certain lease acquisition activities. Our capital investment strategy is focused on prudently developing our existing properties to generate sustainable cash flow considering current and forecasted commodity prices. For the three months ended March 31, 2026, the Company's incurred capital expenditures totaled $161.2 million related to operated activities, of which $117.9 million related to drilling and completion activities, $3.9 million related to maintenance land and seismic investments and $39.5 million related to discretionary acreage acquisitions.
Our operated drilling and completion capital expenditures for 2026 are currently estimated to be in the range of $365 million to $390 million. Also, we currently expect to spend approximately $35 million to $40 million in 2026 for maintenance land and seismic investments, primarily focused on near-term drilling programs and facilitating increases in our working interests and lateral footage in units we plan to drill in 2026, 2027 and 2028. We expect this capital program to result in approximately 1.030 to 1.055 Bcfe per day of production in 2026.
Sources and Uses of Cash
The following table presents the major changes in cash and cash equivalents (in thousands):
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025
Net cash provided by operating activities $ 292,918 $ 177,280
Additions to oil and natural gas properties (137,833) (108,231)
Debt activity, net 35,000 (3,000)
Repurchases of common stock (169,752) (57,809)
Dividends on preferred stock - (862)
Shares exchanged for tax withholdings (18,644) (2,962)
Other (581) (547)
Net change in cash and cash equivalents $ 1,108 $ 3,869
Cash and cash equivalents at end of period $ 2,921 $ 5,342
Net cash provided by operating activities. Net cash provided by operating activities was $292.9 million for the three months ended March 31, 2026, as compared to $177.3 million for the three months ended March 31, 2025.
Additions to oil and natural gas properties. During the three months ended March 31, 2026, we spud nine gross (8.86 net) operated wells and commenced sales from five gross (4.96 net) operated wells targeting the Utica and Marcellus formations for a total incurred cost of approximately $105.0 million. During the three months ended March 31, 2026, we spud 2 gross (1.60 net) operated wells in the SCOOP for a total incurred cost of approximately $12.8 million.
Drilling and completion costs discussed above reflect incurred costs while drilling and completion costs presented in the table below reflect cash payments for drilling and completions. Incurred capital expenditures and cash capital expenditures may vary from period to period due to the cash payment cycle. Cash capital expenditures were as follows (in thousands):
Three Months Ended March 31, 2026 Three Months Ended March 31, 2025
Oil and Natural Gas Property Cash Expenditures:
Drilling and completion costs $ 83,470 $ 90,859
Leasehold and seismic acquisitions 43,372 11,207
Other 10,991 6,165
Total oil and natural gas property expenditures $ 137,833 $ 108,231
Debt activity, net. In the three months ended March 31, 2026, the Company had $575.0 million and $540.0 million in borrowings and repayments, respectively, on its Credit Facility. As of April 29, 2026 the Company had $169.0 million in borrowings outstanding on its Credit Facility.
Repurchases of common stock. During the three months ended March 31, 2026, the Company repurchased 866,279 shares for approximately $172.8 million under the Repurchase Program at a weighted average price of $199.45 per share. For the same period in 2025, the Company repurchased 340,664 shares for $60.0 million at a weighted average price of $176.13 per share.
Dividends on preferred stock. During the three months ended March 31, 2025, the Company paid $0.9 million of cash dividends to holders of our preferred stock. We redeemed the remaining outstanding balance of our preferred stock on September 5, 2025.
Shares exchanged for tax withholdings. During the three months ended March 31, 2026, the Company paid $18.6 million of shares exchanged for tax withholdings compared to $3.0 million in the three months ended March 31, 2025. The increase in shares traded for taxes was primarily due to the vesting of certain performance vesting restricted stock units, as discussed in Note 7 of our consolidated financial statements.
Contractual and Commercial Obligations
We have various contractual obligations in the normal course of our operations and financing activities, as discussed in Note 9 of our consolidated financial statements. There have been no other material changes to our contractual obligations from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2025.
Off-balance Sheet Arrangements
We may enter into off-balance sheet arrangements and transactions that can give rise to material off-balance sheet obligations. As of March 31, 2026, our material off-balance sheet arrangements and transactions include $48.7 million in letters of credit outstanding against our Credit Facility and $45.3 million in surety bonds issued. Both the letters of credit and surety bonds are being used as financial assurance, primarily for certain firm transportation agreements. Additionally, the Company entered into various contractual commitments to purchase inventory and other material to be used in future activities. The Company's commitment to purchase these materials exists through 2026, with approximately $8.8 million remaining. There are no other transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect our liquidity or availability of our capital resources. See Note 9 of our consolidated financial statements for further discussion of the various financial guarantees we have issued.
Critical Accounting Policies and Estimates
As of March 31, 2026, there have been no significant changes in our critical accounting policies from those disclosed in our 2025 Annual Report on Form 10-K.
Gulfport Energy Corporation published this content on May 06, 2026, and is solely responsible for the information contained herein. Distributed via EDGAR on May 06, 2026 at 17:34 UTC. If you believe the information included in the content is inaccurate or outdated and requires editing or removal, please contact us at [email protected]