# W&T Offshore Inc: Form 10-Q for the period ended Mar 31, 2025

- Company: [W&T Offshore Inc](/companies/wti.md) (CIK 1288403)
- Form: 10-Q
- Filed: 2025-05-07
- Accepted by EDGAR: May 7, 2025, 07:00 ET
- Period: 2025-03-31
- Accession: 0001558370-25-006597
- Inline XBRL: yes
- Main document: https://www.sec.gov/Archives/edgar/data/1288403/000155837025006597/wti-20250331x10q.htm
- All documents and exhibits: https://www.sec.gov/Archives/edgar/data/1288403/000155837025006597/

## Figures reported in this filing

Standardized XBRL line items for the period ended 2025-03-31.

| Line item | Period | Value | XBRL concept |
| --- | --- | ---: | --- |
| Revenue | 3 months, 2025-01-01 to 2025-03-31 | $129.9m | us-gaap:RevenueFromContractWithCustomerExcludingAssessedTax |
| Operating income | 3 months, 2025-01-01 to 2025-03-31 | −$8.2m | us-gaap:OperatingIncomeLoss |
| Income tax | 3 months, 2025-01-01 to 2025-03-31 | −$4.6m | us-gaap:IncomeTaxExpenseBenefit |
| Net income | 3 months, 2025-01-01 to 2025-03-31 | −$30.6m | us-gaap:NetIncomeLoss |
| Diluted EPS | 3 months, 2025-01-01 to 2025-03-31 | −$0.21 | us-gaap:EarningsPerShareDiluted |
| Basic EPS | 3 months, 2025-01-01 to 2025-03-31 | −$0.21 | us-gaap:EarningsPerShareBasic |
| Diluted shares (weighted) | 3 months, 2025-01-01 to 2025-03-31 | 147,598,000 shares | us-gaap:WeightedAverageNumberOfDilutedSharesOutstanding |
| Operating cash flow | 3 months, 2025-01-01 to 2025-03-31 | −$3.2m | us-gaap:NetCashProvidedByUsedInOperatingActivities |
| Dividends paid | 3 months, 2025-01-01 to 2025-03-31 | $1.5m | us-gaap:PaymentsOfDividendsCommonStock |
| Cash and equivalents | at 2025-03-31 | $105.9m | us-gaap:CashAndCashEquivalentsAtCarryingValue |
| Current assets | at 2025-03-31 | $221.9m | us-gaap:AssetsCurrent |
| Total assets | at 2025-03-31 | $1.02bn | us-gaap:Assets |
| Current liabilities | at 2025-03-31 | $187.9m | us-gaap:LiabilitiesCurrent |
| Long-term debt | at 2025-03-31 | $349.5m | us-gaap:LongTermDebtNoncurrent |
| Current portion of debt | at 2025-03-31 | $566.0k | us-gaap:LongTermDebtCurrent |
| Shareholders' equity | at 2025-03-31 | −$82.8m | us-gaap:StockholdersEquity |

## Management's discussion and analysis

As filed, 36,800 characters.

Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) should be read in conjunction with the unaudited condensed consolidated financial statements and the related notes included in Part I, Item 1. *Financial Statements*, of this Quarterly Report, as well as our audited consolidated financial statements and the notes thereto in the 2024 Annual Report and the related MD&A included in Part II, Item 7, *Management’s Discussion and Analysis of Financial Condition and Results of Operations*, of our 2024 Annual Report. Unless otherwise indicated or the context otherwise requires, references in this Quarterly Report to “us,” “we” and “our” are to W&T Offshore, Inc. and its wholly owned subsidiaries.

### CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

The information in this Quarterly Report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact included in this Quarterly Report, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. These forward-looking statements are based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate under the circumstances. Although we believe that these forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are made in light of information currently available to us. If the risks or uncertainties materialize or the assumptions prove incorrect, our results may differ materially from those expressed or implied by such forward-looking statements and assumptions. When used in this Quarterly Report, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “forecast,” “may,” “objective,” “plan,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date hereof. We assume no obligation, nor do we intend, to update these forward-looking statements, unless required by law.

The information included in this Quarterly Report includes forward-looking statements that involve risks and uncertainties that could materially affect our expected results of operations, liquidity, cash flows and business prospects. Such statements specifically include our expectations as to our future financial position, liquidity, cash flows, results of operations and business strategy, potential acquisition opportunities, other plans and objectives for operations, capital for sustained production levels, expected production and operating costs, reserves, hedging activities, capital expenditures, return of capital, improvement of recovery factors and other guidance. Actual results may differ from anticipated results, sometimes materially, and reported results should not be considered an indication of future performance. For any such forward-looking statement that includes a statement of the assumptions or bases underlying such forward-looking statement, we caution that, while we believe such assumptions or bases to be reasonable and make them in good faith, assumed facts or bases almost always vary from actual results, sometimes materially. Known material risks that may affect our financial condition and results of operations are discussed in Part I, Item 1A. *Risk Factors,* and market risks are discussed in Part II, Item 7A. *Quantitative and Qualitative Disclosures About Market Risk*, of our 2024 Annual Report, and may be discussed or updated from time to time in subsequent reports filed with the SEC.

Reserve engineering is a process of estimating underground accumulations of crude oil, NGLs and natural gas that cannot be measured in an exact manner. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data, and the price and cost assumptions made by reservoir engineers. In addition, the results of drilling, testing, and production activities, or changes in commodity prices, may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of crude oil, NGLs and natural gas that are ultimately recovered.

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

### BUSINESS OVERVIEW

We are an independent oil and natural gas producer, active in the exploration, development and acquisition of oil and natural gas properties in the Gulf of America. As of March 31, 2025, we hold working interests in 52 producing offshore fields in federal and state waters (which include 45 fields in federal waters and seven in state waters). We currently have under lease approximately 634,700 gross acres (496,900 net acres) spanning across the outer continental shelf off the coasts of Louisiana, Texas, Mississippi and Alabama, with approximately 5,600 gross acres in Alabama state waters, 487,200 gross acres on the conventional shelf and approximately 141,900 gross acres in the deepwater. A majority of our daily production is derived from wells we operate.

### Recent Developments

In January 2025, we received approximately $11.9 million for the sale of a non-core interest in our Garden Banks Blocks 385 and 386. In addition, we received $58.5 million related to the settlement of insurance claims from our Mobile Bay plant turnaround in February 2023. Because we use the full cost method of accounting, these amounts were included in our full cost pool at the time of receipt.

On May 6, 2025, we declared a regular quarterly dividend of $0.01 per share for the second quarter of 2025. We expect to pay the dividend on May 27, 2025 to stockholders of record as of the close of business on May 20, 2025.

### Debt Refinancing

#### Issuance of the 10.75% Notes

On January 28, 2025, we issued and sold $350.0 million in aggregate principal amounts of our 10.75% Notes. The 10.75% Notes mature on February 1, 2029 and interest is payable on each February 1 and August 1, commencing August 1, 2025. The 10.75% Notes are guaranteed by the Guarantors. The 10.75% Notes are secured by second priority liens (subject to permitted liens and certain other exceptions) on substantially all of our oil and natural gas properties, including those of the Guarantors.

We used the net proceeds from the issuance of the 10.75% Notes, along with cash on hand, to (i) purchase for cash such of our 11.75% Notes that were validly tendered pursuant to the terms of the Tender Offer; (ii) repay the $114.2 million of outstanding amounts under Term Loan; (iii) fund the full redemption amount for an August 1, 2025 redemption of the remaining 11.75% Notes not validly tendered and accepted for purchase in the Tender Offer; and (iv) pay any premiums, fees and expenses relating to these transactions.

#### Redemption of the 11.75% Notes

On January 13, 2025, we commenced the Tender Offer for any and all of our outstanding 11.75% Notes. On January 28, 2025, we accepted and purchased $269.7 million aggregate principal amount of the outstanding 11.75% Notes for a purchase price equal to $1,036.25 for each $1,000 principal amount of the Notes purchased. An additional $89,000 of Notes were tendered on February 12, 2025. We purchased these Notes for $89,905 plus accrued interest.

After giving effect to this purchase, an aggregate $5.2 million principal amount of the 11.75% Notes remained outstanding. We then effected a legal defeasance of the 11.75% Notes by purchasing $5.9 million of government securities to cover the principal and interest due for those remaining 11.75% Notes. This process released us from our remaining obligations under the indenture governing the 11.75% Notes.

#### Credit Agreement

On January 28, 2025, in conjunction with the issuance of the 10.75% Notes, we terminated our prior credit agreement and entered into a new credit agreement which provides us with a revolving credit and letter of credit facility with initial bank lending commitments of $50.0 million with a letter of credit sublimit of $10.0 million. The Credit Facility matures on July 28, 2028.

See Part I, Item 1. *Financial Statements – Note 4 – Debt* of this Quarterly Report and Part II, Item 8. *Financial Statements and Supplementary Data,* in our 2024 Annual Report for additional information about the above debt transactions.

### Regulatory Update

The change of Presidential administration in the early part of 2025 saw promising developments in the oil and natural gas regulatory environment. On January 20, 2025, President Trump issued Executive Order 14154, *Unleashing American Energy*. Section 3 of that Order directed heads of agencies to review existing regulations to identify agency actions that impose an undue burden on the identification, development, or use of domestic energy resources. The Trump administration also issued Executive Order 14156, *Declaring a National Energy Emergency*, stating that the United States’ insufficient energy production, transportation, refining and generation constituted an unusual and extraordinary threat to the nation’s economy, national security, and foreign policy. Furthermore, on February 3, 2025, Secretary Burgum issued Secretarial Order 3418, *Unleashing American Energy*. Section 4(b) of that Order directed agency officials to prepare an action plan that will include steps to suspend, revise, or rescind certain regulations.

As it pertains to us, on April 8, 2025, pursuant to the above directives from the Trump administration, the Department of Interior, through a joint filing in the U.S. District Court for the Western District of Louisiana (Case no. 2:24-cv-00820), indicated that it will not seek supplemental financial assurance in the Gulf of America except in the case of (a) sole liability properties and (b) certain non-sole liability properties that do not have a financially strong co-owner or predecessor in title and meet other conditions.

While we view this as a positive development, the substance and timing of future legal and regulatory actions cannot be predicted at this time. Additionally, regardless of any changes that may come as a result of the Secretarial Order, the BOEM has the right to issue liability orders in the future, including if it determines there is a substantial risk of nonperformance of the interest holder’s decommissioning liabilities. For more information on the BOEM and financial assurance obligations to that agency, see *Business – Environmental, Health and Safety Matters and Government Regulations – Other Regulation of the Oil and Natural Gas Industry* under Part I, Item 1 of our 2024 Annual Report.

In addition, the Trump administration has issued a number of executive orders aimed at streamlining regulations and reducing the regulatory burden on oil and natural gas companies, increasing federal oil and natural gas leasing, including in the Gulf of America, and expediting U.S. natural resource development.

### Business Outlook

Our financial condition, cash flow and results of operations are significantly affected by the volume of our oil, NGLs and natural gas production and the prices that we receive for such production. Changes in the prices that we receive for our production impact all aspects of our business; most notably our cash flows from operations, revenues, capital allocation and budgeting decisions and our reserves volumes. Prices of oil, NGLs and natural gas have historically been volatile and can fluctuate significantly over short periods of time for many factors outside of our control, including changes in market supply and demand, which are impacted by weather conditions, pipeline capacity constraints, inventory storage levels, domestic production activities and political issues, and international geopolitical and economic events.

The Energy Information Administration (“EIA”) published its latest Short Term Energy Outlook in April 2025. Oil prices fell sharply in the first week of April 2025 as oil market participants assessed announcements that the United States would impose new tariffs and OPEC+ would accelerate production increases. These announcements increase the likelihood that global oil inventories will rise in the coming month and have the potential to put further downward pressure on oil prices. As a result, the EIA is forecasting that the spot price for WTI oil will fall from an average of $71.84 per barrel for the first quarter of 2025 to an average of $61.33 per barrel for the remainder of 2025 and then continue to fall to an average of $57.50 per barrel in 2026.

The EIA is forecasting that Henry Hub spot prices are expected to average more than $3.93 per MMBtu in the second quarter of 2025, an 88% increase compared with the second quarter of 2024. The EIA is also forecasting that

Henry Hub spot prices will average $4.27 per MMBtu in 2025 and $4.60 in 2026. The EIA is expecting natural gas prices to rise in 2025 as natural gas demand (consumption plus exports) in the United States will grow by 4% in 2025 compared with 2024, led by an 18% increase in exports of natural gas by pipeline and as liquified natural gas (“LNG”) and a 9% increase in residential and commercial consumption for space heating. The increase in natural gas exports is driven primarily by an increase in LNG exports as two new LNG export facilities ramp up operations.

Our average realized sales price for oil and natural gas differs from the WTI average price and the NYMEX Henry Hub average price, respectively, primarily due to premiums or discounts, quality adjustments, location adjustments and volume weighting (collectively referred to as differentials). Oil price differentials primarily represent the transportation costs in moving produced oil at the wellhead to a refinery and are based on the availability of pipeline, rail and other transportation. Natural gas price differentials are strongly impacted by local market fundamentals, availability of transportation capacity from producing areas and seasonal impacts. Prices and differentials for NGLs are related to the supply and demand for the products making up these liquids. Some of them more typically correlate to the price of oil while others are affected by natural gas prices as well as the demand for certain chemical products which are used as feedstock.

### RESULTS OF OPERATIONS

### Three Months Ended March 31, 2025 Compared to the Three Months Ended March 31, 2024

### Revenues

The following table presents information regarding our revenues, production volumes and average realized sales prices (which exclude the effect of hedging unless otherwise stated) for the three months ended March 31, 2025 and 2024 (in thousands, except average realized sales prices data):

| ​ ​ ​ Revenues: | ​ ​ ​ ​ | ​ ​ Three Months Ended March 31, 2025 ​ ​ | ​ ​ | ​ ​ 2024 ​ ​ | ​ ​ ​ | ​ ​ ​ ​ ​ Change ​ ​ |
| --- | --- | ---: | --- | ---: | --- | ---: |
| Oil | ​ | $87,716 | ​ | $107,015 | ​ | $(19,299) |
| NGLs | ​ | 4,772 | ​ | 7,469 | ​ | (2,697) |
| Natural gas | ​ | 35,109 | ​ | 21,616 | ​ | 13,493 |
| Other | ​ | 2,270 | ​ | 4,687 | ​ | (2,417) |
| Total revenues | ​ | $129,867 | ​ | $140,787 | ​ | $(10,920) |
| ​ | ​ | ​ ​ | ​ | ​ ​ | ​ | ​ ​ |
| **Production Volumes:** | ​ |  | ​ |  | ​ |  |
| Oil (MBbls) (1) | ​ | 1,230 | ​ | 1,400 | ​ | (170) |
| NGLs (MBbls) | ​ | 200 | ​ | 343 | ​ | (143) |
| Natural gas (MMcf) (2) | ​ | 7,884 | ​ | 8,733 | ​ | (849) |
| Total oil equivalent (MBoe) (3) | ​ | 2,744 | ​ | ​ 3,199 | ​ | ​ (455) |
| ​ | ​ | ​ ​ | ​ | ​ ​ | ​ | ​ ​ |
| Average daily equivalent sales (Boe/day) | ​ | ​ 30,489 | ​ | ​ 35,148 | ​ | ​ (4,659) |
| ​ | ​ | ​ ​ | ​ | ​ ​ | ​ | ​ ​ |
| **Average realized sales prices:** | ​ | ​ | ​ | ​ ​ | ​ | ​ ​ |
| Oil ($/Bbl) | ​ | $71.31 | ​ | $76.44 | ​ | $(5.13) |
| NGLs ($/Bbl) | ​ | 23.86 | ​ | 21.78 | ​ | 2.08 |
| Natural gas ($/Mcf) | ​ | 4.45 | ​ | 2.48 | ​ | 1.97 |
| Oil equivalent ($/Boe) | ​ | ​ 46.50 | ​ | ​ 42.55 | ​ | ​ 3.95 |
| Oil equivalent ($/Boe), including realized commodity derivatives | ​ | 45.17 | ​ | 42.97 | ​ | 2.20 |

(1) MBbls — thousands of barrels of oil, condensate or NGLs

(2) MMcf — million cubic feet

(3) MBoe — thousand barrels of oil equivalent

Changes in average sales prices and production volumes caused the following changes to our oil, NGL and natural gas revenues between the three months ended March 31, 2025 and 2024 (in thousands):

| ​ ​ | ​ ​ Price | ​ | ​ ​ Volume | ​ ​ | ​ ​ Total |
| --- | ---: | --- | ---: | --- | ---: |
| Oil | $(6,301) | ​ | $(12,998) | ​ | $(19,299) |
| NGLs | 412 | ​ | ​ (3,109) | ​ | (2,697) |
| Natural gas | 15,596 | ​ | ​ (2,103) | ​ | 13,493 |
| ​ | $9,707 | ​ | $(18,210) | ​ | $(8,503) |

Production volumes decreased by 0.5 MMBoe to 2.7 MMBoe during the three months ended March 31, 2025 compared to the same period in 2024 primarily related to deferred production of approximately 0.2 MMBoe at our Mobile Bay properties related to freezing weather and compressor issues and approximately 0.2 MMBoe from the shut-ins of our West Delta 73 field and our Main Pass 98 and 108 fields.

### Operating Expenses

The following table presents information regarding costs and expenses and selected average costs and expenses per Boe sold for the periods presented and corresponding changes (in thousands, except average data):

| ​ ​ ​ Operating expenses: | ​ ​ ​ | ​ ​ Three Months Ended March 31, 2025 ​ ​ | ​ ​ | ​ ​ 2024 ​ ​ | ​ ​ ​ | ​ ​ ​ ​ ​ Change ​ ​ |
| --- | --- | ---: | --- | ---: | --- | ---: |
| Lease operating expenses | ​ | $71,012 | ​ | $70,830 | ​ | $182 |
| Gathering, transportation and production taxes | ​ | ​ 5,659 | ​ | ​ 7,540 | ​ | ​ (1,881) |
| Depreciation, depletion and amortization |  | ​ 32,891 | ​ | ​ 33,937 |  | ​ (1,046) |
| Asset retirement obligations accretion expense |  | ​ 8,392 | ​ | ​ 7,969 |  | ​ 423 |
| General and administrative expenses | ​ | ​ 20,157 | ​ | ​ 20,515 | ​ | ​ (358) |
| Total operating expenses | ​ | $138,111 | ​ | $140,791 | ​ | $(2,680) |
| ​ | ​ | ​ ​ | ​ | ​ ​ | ​ | ​ ​ |
| **Average per Boe ($/Boe):** | ​ |  | ​ |  | ​ |  |
| Lease operating expenses | ​ | $25.88 | ​ | $22.14 | ​ | $3.74 |
| Gathering, transportation and production taxes | ​ | 2.06 | ​ | 2.36 | ​ | (0.30) |
| Depreciation, depletion and amortization | ​ | 11.99 | ​ | 10.61 | ​ | 1.38 |
| Asset retirement obligations accretion expense | ​ | ​ 3.06 | ​ | ​ 2.49 | ​ | ​ 0.57 |
| General and administrative expenses | ​ | 7.35 | ​ | 6.41 | ​ | 0.94 |
| Total operating expenses | ​ | $50.34 | ​ | $44.01 | ​ | $6.33 |

*Lease operating expenses –* Lease operating expenses include the expense of operating and maintaining our wells, platforms and other infrastructure primarily in the Gulf of America. These operating costs are comprised of several components including direct or base lease operating expenses, insurance premiums, workover costs and facility maintenance expenses. Our lease operating costs, which depend in part on the type of commodity produced, the level of workover activity and the geographical location of the properties, were relatively flat during the three months ended March 31, 2025 compared to the same period in 2024. On a per Boe basis, lease operating expenses increased to $25.88 per Boe during the three months ended March 31, 2025 compared to $22.14 per Boe during the three months ended March 31, 2024. On a component basis, base lease operating expenses decreased $3.4 million, workover expenses decreased $1.0 million and facilities maintenance expense increased $4.5 million.

Expenses for direct labor, materials, supplies, repair, third-party costs and insurance comprise the most significant portion of our base lease operating expense. Base lease operating expenses decreased primarily due to higher contract processing credits at Heidelberg due to a new platform processor and reduced operating expenses related to the decrease in production volumes.

Workover and facilities maintenance expenses consist of costs associated with major remedial operations on completed wells to restore, maintain or improve the well’s production. Since these remedial operations are not regularly scheduled, workover and maintenance expense are not necessarily comparable from period to period. The decrease in workover expenses and the increase in facilities maintenance expenses were due to the timing and mix of projects undertaken.

*Gathering, transportation and production taxes –* Gathering and transportation consist of costs incurred in the post-production shipping of oil, NGLs and natural gas to the point of sale. Production taxes consist of severance taxes levied by the Alabama Department of Revenue , the Louisiana Department of Revenue and the Texas Department of Revenue on production of oil and natural gas from land or water bottoms within the boundaries of each state. Gathering, transportation and production taxes decreased $1.9 million for the three months ended March 31, 2025 compared to the three months ended March 31, 2024 primarily due to decreases of $1.7 million in gathering and transportation expenses and $0.2 million in production taxes. Gathering and transportation expenses decreased primarily due to lower production volumes in the three months ended March 31, 2025 and higher processing fees for our Mobile Bay production that had to be re-routed to a different processing plant due to the shut-in of our Mobile Bay processing plant in the three months ended March 31, 2024.

*Depreciation, depletion and amortization –* Depreciation, depletion and amortization expense (“DD&A”) is the expensing of the capitalized costs incurred to acquire, explore and develop oil and natural gas reserves. We use the full cost method of accounting for oil and natural gas activities. DD&A decreased $1.0 million for the three months ended March 31, 2025 as compared to the three months ended March 31, 2024 primarily due to $5.3 million from the decrease in production partially offset by $4.2 million from an increase in the depletion rate per Mcfe. The DD&A rate increased to $11.99 per Boe for the three months ended March 31, 2025 from $10.61 per Boe for the three months ended March 31, 2024. The DD&A rate per Boe increased primarily as a result of increases in future development costs and capitalized ARO, partially offset by a lower depreciable base and decreased proved reserves. The lower depreciable base is due to the $58.5 million in insurance proceeds and $11.9 million of proceeds from the sale of oil and natural gas properties that were included in our full cost pool.

*Asset retirement obligations accretion expense –* Accretion expense is the expensing of the changes in value of our ARO as a result of the passage of time over the estimated productive life of the related assets as the discounted liabilities are accreted to their expected settlement values. Accretion expense increased $0.4 million in the three months ended March 31, 2025 compared to the same period in 2024 primarily due to the increase in our ARO liability as a result of revisions to the estimates used in calculating the liability.

*General and administrative expenses –* General and administrative (“G&A”) expenses generally consist of costs incurred for overhead, including payroll and benefits for our corporate staff, costs of maintaining our headquarters, costs of managing our production operations, bad debt expense, share-based compensation costs, audit and other fees for professional services and legal compliance. G&A expenses decreased $0.4 million for the three months ended March 31, 2025 compared to the three months ended March 31, 2024. The decrease is primarily due to decreases of (i) $0.9 million in share-based compensation costs and (ii) $0.9 million in employee benefit costs due to lower medical claims costs, partially offset by a $1.6 million increase in legal fees related to various litigation issues, such as our sureties litigation.

### Other Income and Expense Items

The following table presents the components of other income and expense items for the periods presented and corresponding changes (in thousands):

| ​ ​ ​ | ​ ​ | ​ ​ Three Months Ended March 31, 2025 | ​ | ​ ​ 2024 | ​ ​ | ​ ​ ​ ​ ​ Change |
| --- | --- | --- | --- | --- | --- | --- |
| Interest expense, net | ​ | $9,492 | ​ | $10,072 | ​ | $(580) |
| Loss on extinguishment of debt | ​ | ​ 15,015 | ​ | ​ — | ​ | ​ 15,015 |
| Derivative loss (gain), net |  | ​ 2,757 | ​ | ​ (4,877) |  | ​ 7,634 |
| Other (income) expense, net |  | ​ (316) | ​ | ​ 5,230 |  | ​ (5,546) |
| Income tax (benefit) expense |  | ​ (4,615) | ​ | ​ 1,045 |  | ​ (5,660) |

*Interest expense, net –* Interest expense, net, decreased $0.6 million for the three months ended March 31, 2025 compared to the same period in 2024 primarily due to a decrease of $7.6 million from the redemption of the 11.75% Notes and the repayment of the Term Loan in late January 2025, partially offset by $6.6 million incurred on the 10.75% Notes issued in late January 2025.

*Loss on extinguishment of debt –* During the three months ended March 31, 2025, we recorded a loss on extinguishment of debt related to our January 2025 refinancing. The loss consisted of (i) $9.8 million of premiums paid on the redemption of the tendered 11.75% Notes; (ii) $4.6 million related to the write-off of unamortized debt issuance costs; (iii) $0.5 million of fees related to the refinancing; and (iv) $0.2 million related to the legal defeasance of the untendered 11.75% Notes.

*Derivative loss (gain), net –* During the three months ended March 31, 2025, we recorded a $2.7 million derivative loss for our natural gas derivative contracts consisting of $0.9 million of unrealized gain from the increase in the fair value of our open natural gas contracts offset by $3.6 million of realized losses. During the three months ended March 31, 2024, we recorded a $4.9 million derivative gain for our natural gas derivative contracts consisting of $1.1 million of unrealized gains from the increase in the fair value of our open natural gas contracts and $3.8 million of realized gains.

*Other (income) expense, net –* Other (income) expense, net increased $5.5 million for the three months ended March 31, 2025 compared to the same period in 2024 primarily related to a decrease in the accrual of additional expenses for net abandonment obligations pertaining to a number of legacy Gulf of America properties.

*Income tax (benefit) expense –* Our effective tax rates for the three months ended March 31, 2025 and 2024 was 13.1% and (10.0)%, respectively. The difference between the effective tax rate and the federal statutory rate was primarily due to the impact of nondeductible compensation and adjustments to the valuation allowance.

### Liquidity and Capital Resources

### Liquidity Overview

Our primary liquidity needs are to fund capital and operating expenditures and strategic acquisitions to allow us to replace our oil and natural gas reserves, repay and service outstanding borrowings, operate our properties and satisfy our ARO. We have funded such activities in the past with cash on hand, net cash provided by operating activities, sales of property, securities offerings and bank and other borrowings, and expect to continue to do so in the future.

We expect to support our business requirements primarily with cash on hand and cash generated from operations. As of March 31, 2025, we had $105.9 million of unrestricted cash on hand and $50.0 million available under our New Credit Agreement. We also have up to approximately $83.0 million of availability through our “at-the-market” equity offering program, pursuant to which we may offer and sell shares of our common stock from time to time. Based on our current financial condition and current expectations of future market conditions, we believe our cash on hand, cash flows from operating activities and access to the equity markets from our “at-the-market” equity offering program will provide us with additional liquidity to continue our growth and will allow us to meet our cash requirements for at least the next 12 months and beyond.

We continuously review our liquidity and capital resources. If market conditions were to change, for instance due to uncertainty created by geopolitical events, a pandemic or a significant decline in oil and natural gas prices, and our revenue was reduced significantly or operating costs were to increase significantly, our cash flows and liquidity could be negatively impacted.

### Cash Flow Information

The following table summarizes cash flows provided by (used in) by type of activity for the following periods (in thousands):

| ​ ​ ​ | ​ ​ ​ | ​ ​ Three Months Ended March 31, 2025 | ​ ​ | ​ ​ 2024 | ​ ​ ​ | ​ ​ ​ ​ ​ Change |
| --- | --- | ---: | --- | ---: | --- | ---: |
| Operating activities | ​ | $(3,196) | ​ | $11,642 | ​ | $(14,838) |
| Investing activities | ​ | 63,267 | ​ | (87,619) | ​ | 150,886 |
| Financing activities | ​ | (63,141) | ​ | (2,539) | ​ | (60,602) |

#### Operating Activities

Our largest source of operating cash is collecting cash from customers and joint interest partners from sales of our products. The primary use of operating cash is to pay our suppliers, employees and others for a wide range of goods and services.

Net cash provided by operating activities decreased $14.8 million in the three months ended March 31, 2025 compared to the corresponding period in 2024. This was primarily due to decreases of $12.4 million in net loss adjusted for certain noncash items and $2.4 million in operating cash flows from changes in operating assets and liabilities. The decrease in net loss adjusted for certain noncash items was primarily related to a $10.9 million decrease in revenues and a $7.9 million unfavorable change in derivative settlements and receipts, partially offset by decreases in cash operating expenses. The decrease in operating assets and liabilities is primarily related to higher accounts receivable offset by lower accounts payable and accrued liabilities balances in the current period.

#### Investing Activities

Our principal recurring investing activity is the funding of acquisitions and investments in oil and natural gas properties to support and generate revenues from operations. Cash flows provided by (used in) investing activities were $63.3 million and $(87.6) million, respectively. During the three months ended March 31, 2024, we paid $80.5 million related to our January 2024 acquisition and our September 2023 acquisition. Investments in oil and natural gas properties were $6.7 million and $7.1 million during the three months ended March 31, 2025 and 2024, respectively. During the three months ended March 31, 2025, we also received $58.5 million in insurance proceeds and $11.9 million in proceeds from the sale of oil and natural gas properties. As we use the full cost method of accounting for our oil and natural gas properties, these proceeds were recorded in our full cost pool.

#### Financing Activities

Cash flows used in financing activities were $63.1 million and $2.5 million for three months ended March 31, 2025 and 2024, respectively. In connection with our debt refinancing in January 2025, we received $350.0 million in proceeds from the issuance of our 10.75% Notes and used these proceeds, along with cash on hand, to (i) purchase for cash, pursuant to the Tender Offer, $269.8 million of our 11.75% Notes; (ii) repay $114.2 million of amount outstanding under our Term Loan; (iii) purchase $5.9 million of government securities to be used in the legal defeasance of the remaining principal of our 11.75% Notes not validly tendered and accepted for purchase in the Tender Offer; and (iv) pay $21.3 million in premiums, fees and debt issuance costs.

We also paid dividends of $1.5 million in both the three months ended March 31, 2025 and 2024.

### Capital Expenditures

The level of our investment in oil and natural gas properties changes from time to time depending on numerous factors, including the prices of oil, NGLs and natural gas, acquisition opportunities, liquidity and financing options and the results of our exploration and development activities.

The following table presents our capital expenditures for exploration, development, acquisitions and other leasehold costs (in thousands):

| ​ ​ ​ Exploration and development | ​ ​ ​ | ​ ​ Three Months Ended March 31, 2025 ​ ​ | ​ ​ | ​ ​ 2024 ​ ​ |
| --- | --- | ---: | --- | ---: |
| Conventional shelf (1) | ​ | $5,447 | ​ | $2,122 |
| Deepwater | ​ | ​ 2,108 | ​ | ​ 900 |
| Acquisitions of interests | ​ | 400 | ​ | 80,515 |
| Seismic and other | ​ | 917 | ​ | 134 |
| Investments in oil and gas property/equipment – accrual basis | ​ | $8,872 | ​ | $83,671 |

(1) Includes exploration and development capital expenditures in Alabama state waters.

As of March 31, 2025, we expect to incur an additional $25.0 million to $33.0 million of capital expenditures in the remainder of 2025, which excludes acquisitions. In our view of the outlook for the remainder of 2025, we believe this level of capital expenditure will leave us with sufficient liquidity to operate our business, while providing liquidity to make strategic acquisitions. At current pricing levels, we expect our cash flows to cover our liquidity requirements, and we expect additional financing sources to be available if needed. If our liquidity becomes stressed from significant or prolonged reductions in realized prices, we have flexibility in our capital expenditure budget to reduce investments. We strive to maintain flexibility in our capital expenditure projects and if commodity prices improve, we may increase our investments.

### Acquisitions

We have grown by making strategic acquisitions of producing properties in the Gulf of America. We seek opportunities where we can exploit additional drilling projects and reduce costs.

Any future acquisitions are subject to the completion of satisfactory due diligence, the negotiation and resolution of significant legal issues, the negotiation, documentation and completion of mutually satisfactory definitive agreements among the parties, the consent of our lenders, our ability to finance the acquisition and approval of our board of directors. We cannot guarantee that any such potential transaction would be completed on acceptable terms, if at all.

### Asset Retirement Obligations

We have obligations to plug and abandon wells, remove platforms, pipelines, facilities and equipment and restore the land or seabed at the end of oil and natural gas production operations. Through the three months ended March 31, 2025, we have paid $3.8 million related to these obligations. Our ARO estimates as of March 31, 2025 and December 31, 2024 were $561.9 million and $548.8 million, respectively. As our ARO estimates are for work to be performed in the future, and in the case of our non-current ARO, extend from one to many years in the future, actual expenditures could be substantially different than our estimates. See Part I, Item 1A. *Risk Factors*, of our 2024 Annual Report for additional information.

### Debt

As of March 31, 2025, we have $359.7 million in aggregate principal amount of long-term debt outstanding, with $1.1 million in aggregate principal coming due over the next twelve months.

For additional information about our long-term debt, see Part I, Item 1. *Financial Statements – Note 3 – Debt* of this Quarterly Report and Part II, Item 8. *Financial Statements and Supplementary Data,* in our 2024 Annual Report.

#### Dividends

During the three months ended March 31, 2025, we paid a cash dividend of approximately $1.5 million to holders of our common stock. The amount and frequency of future dividends is subject to the discretion of our board of directors and primarily depends on earnings, capital expenditures, debt covenants and various other factors.

## Market risk

As filed, 1,673 characters.

Our major market risk exposure is the fluctuation of prices for oil, NGL and natural gas. These fluctuations have a direct impact on our revenues, earnings and cash flow. For example, assuming a 10% decline in our average realized oil, NGL and natural gas sales prices in the three months ended March 31, 2025 and assuming no other items had changed, our revenue would have decreased by approximately $12.8 million in the three months ended March 31, 2025. This amount would be representative of the effect on operating cash flows under these price change assumptions.

We have attempted to mitigate commodity price risk and stabilize cash flows associated with our forecasted sales of natural gas production through the use of swaps, purchased calls and purchased puts. Our derivatives will not mitigate all the commodity price risks of our forecasted sales of natural gas production and, as a result, we will be subject to commodity price risks on our remaining forecasted production.

The following table summarizes the historical results of our natural gas derivatives:

| ​ ​ ​ Natural Gas ($/Mcf) | ​ ​ ​ ​ | ​ ​ Three Months Ended March 31, 2025 | ​ ​ ​ | ​ ​ 2024 |
| --- | --- | ---: | --- | ---: |
| Average realized sales price, before the effects of derivative settlements | ​ | $4.45 | ​ | $2.48 |
| Effects of realized commodity derivatives | ​ | (0.46) | ​ | 0.43 |
| Average realized sales price, including realized commodity derivatives | ​ | $3.99 | ​ | $2.91 |

Our exposure to interest rate risk has not changed materially from the disclosures in Part II, Item 7A. *Quantitative and Qualitative Disclosures About Market Risk,* of our 2024 Annual Report.

## Controls and procedures

As filed, 2,113 characters.

We have established disclosure controls and procedures designed to ensure that material information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified by the SEC and that any material information relating to us is accumulated and communicated to our management, including our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate to allow timely decisions regarding required disclosures. In designing and evaluating our disclosure controls and procedures, our management recognizes that controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving desired control objectives. In reaching a reasonable level of assurance, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

As required by Exchange Act Rule 13a-15(b), our CEO and CFO performed an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of the end of the period covered by this Quarterly Report. Based on that evaluation, our CEO and CFO have each concluded that as of March 31, 2025, our disclosure controls and procedures are effective to ensure that information we are required to disclose in reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that our controls and procedures are designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

During the quarter ended March 31, 2025, there was no change in our internal control over financial reporting that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

## Risk factors

As filed, 2,516 characters.

In addition to the information set forth in this Quarterly Report and risk factors below, investors should carefully consider the risk factors and other cautionary statements included under Part I, Item 1A. *Risk Factors,* in our 2024 Annual Report, together with all of the other information included in this Quarterly Report, and in our other public filings, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

***Changes in U.S. trade policy and the impact of tariffs may have a negative effect on our business, financial condition and results of operations.***

Our business and results of operations may be adversely affected by uncertainty and changes in U.S. trade policies, including tariffs, trade agreements or other trade restrictions imposed by the U.S. or other governments. For example, on April 2, 2025, the U.S. government announced a 10% tariff on product imports from almost all countries and individualized higher tariffs on certain other countries. Several tariff announcements have been followed by announcements of limited exemptions and temporary pauses. Increased tariffs by the U.S. have led and may continue to lead to substantial uncertainty and volatility in financial markets and result in retaliatory measures on U.S. goods. Current uncertainties about tariffs, their effects on trading relationships and any retaliatory measures could result in decreased demand and price for the commodities that we produce, increase our operating costs and contribute to inflation in the markets in which we operate.

Changes in tariffs and trade restrictions can be announced with little or no advance notice. The adoption and expansion of tariffs or other trade restrictions, increasing trade tensions, or other changes in governmental policies related to taxes, tariffs, trade agreements or policies, are difficult to predict, which makes attendant risks difficult to anticipate and mitigate. Although we are continuing to monitor the economic effects of such announcements, as well as opportunities to mitigate their related impacts, costs and other effects associated with the tariffs remain uncertain. If we are unable to navigate further changes in U.S. or international trade policy, it could have a material adverse impact on our business and results of operations.

Filed May 7, 2025.
Source: SEC EDGAR, the filing index for accession 0001558370-25-006597. Last ingested by Listed: Oct 29, 2026, 19:28 ET. No prices; not investment advice.