W&T Offshore, Inc. Reports Fourth Quarter and Full Year 2024 Financial Results and 2025 Guidance

W&T Offshore announced fourth quarter 2024 financial results, outlining production, operating expenses, debt management, and future guidance.

Quiver AI Summary

W&T Offshore, Inc. announced its operational and financial results for the fourth quarter and full year of 2024, highlighting a total production of 33.3 MBoe/d (43% oil) for the year. Despite challenges from hurricanes and operational downtime, the company met its production guidance and reported year-end proved reserves of 127.0 MMBoe, a 39% increase in oil reserves. Fourth quarter revenue was $120.3 million, with a net loss of $23.4 million. The company generated $44.9 million in free cash flow while successfully refinancing its debt, lowering interest costs, and maintaining liquidity with $109 million in cash. Guidance for 2025 anticipates increased production as fields come back online, while capital expenditures for the year are expected to be between $34 million and $42 million. W&T declared a quarterly dividend of $0.01 per share for Q1 2025, continuing its commitment to shareholder returns.

Potential Positives

• Reported a significant increase in proved reserves, reaching 127.0 MMBoe with a 39% increase in oil reserves compared to the previous year.
• Generated Free Cash Flow of $44.9 million for the year, highlighting effective cash management despite operational challenges.
• Successfully refinanced higher-interest debt, reducing the interest rate on Senior Second Lien Notes by 100 basis points, thus improving the company's financial stability.
• Declared a dividend for the first quarter of 2025, maintaining a commitment to return value to shareholders amidst challenging market conditions.

Potential Negatives

• Reported a net loss of $87.1 million for the full year 2024, contrasting with a net income of $15.6 million in 2023, indicating a significant decline in financial performance.
• Year-over-year revenue decreased from $532.7 million in 2023 to $525.3 million in 2024, reflecting challenges in maintaining sales despite increased production of oil.
• Average realized prices for oil and natural gas declined in 2024 compared to 2023, contributing to lower overall revenues and indicating vulnerability to market fluctuations.

FAQ

What were W&T Offshore's production figures for 2024?

W&T Offshore delivered a production of 33.3 MBoe/d in 2024, with 43% being oil.

What is the status of W&T's dividend for Q1 2025?

The dividend for the first quarter of 2025 is set at $0.01 per share, payable on March 24, 2025.

How did W&T Offshore's financial performance in 2024 compare to 2023?

W&T reported a net loss of $87.1 million for 2024, compared to a net income of $15.6 million in 2023.

What were the key operational highlights for W&T in 2024?

Key highlights included a 39% increase in oil reserves and replacement of 219% of production with new reserves.

How did W&T Offshore manage its debt in 2024?

W&T successfully refinanced its debt, lowering interest rates and reducing gross debt by approximately $39 million.

Disclaimer: This is an AI-generated summary of a press release distributed by GlobeNewswire. The model used to summarize this release may make mistakes. See the full release here.

$WTI Hedge Fund Activity

We have seen 56 institutional investors add shares of $WTI stock to their portfolio, and 99 decrease their positions in their most recent quarter.

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• AMERIPRISE FINANCIAL INC added 3,104,484 shares (+427.0%) to their portfolio in Q4 2024, for an estimated $5,153,443
• JACOBS LEVY EQUITY MANAGEMENT, INC added 968,552 shares (+inf%) to their portfolio in Q4 2024, for an estimated $1,607,796
• CITADEL ADVISORS LLC removed 891,733 shares (-61.0%) from their portfolio in Q4 2024, for an estimated $1,480,276
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• MORGAN STANLEY removed 592,986 shares (-43.4%) from their portfolio in Q4 2024, for an estimated $984,356
• BLACKROCK, INC. removed 591,566 shares (-6.9%) from their portfolio in Q4 2024, for an estimated $981,999
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Full Release

HOUSTON, March 03, 2025 (GLOBE NEWSWIRE) -- W&T Offshore, Inc. (NYSE: WTI) (“W&T,” the “Company” or “us”) today reported operational and financial results for the fourth quarter and full year 2024, including the Company’s year-end 2024 reserve report. Detailed guidance for the first quarter of 2025 and full year 2025 was also provided, and W&T announced its dividend for the first quarter of 2025.

This press release includes non-GAAP financial measures, including Adjusted Net Loss, Adjusted EBITDA, Free Cash Flow, Net Debt and PV-10 which are described and reconciled to the most comparable GAAP measures below in the accompanying tables under “Non-GAAP Information.”

Key highlights for the fourth quarter of 2024, the full year 2024 and since year end 2024 include:

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  Delivered production in full year 2024 of 33.3 thousand barrels of oil equivalent per day (“MBoe/d”) (43% oil), or 12.2 million barrels of oil equivalent (“MMBoe”). This production was within the Company’s guidance range despite impacts from three hurricanes in the Gulf of America (“GOA”) and other downtime which was mainly related to the Cox acquisition (as defined below);
  
  
  
  
  
  
  
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    Achieved mid-point of the guidance for annual oil production and increased it by 4% year-over-year;
    
  
  
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    Produced 32.1 MBoe/d (43% oil) or 3.0 MMBoe in fourth quarter 2024, within W&T’s guidance range;
    
  
  
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    Announced the Main Pass 108 and 98 fields as well as the West Delta 73 field are expected to come back online in the second quarter of 2025;
    
  
  
  
  


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  Increased year-end 2024 proved reserves at SEC pricing to 127.0 MMBoe, with oil reserves increasing 39%;
  
  
  
  
  
  
  
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    Reported a standardized measure of discounted future net cash flows of $740.1 million and a present value of estimated future oil and natural gas revenues, minus direct expenses, discounted at a 10% annual rate (“PV-10”) of $1.2 billion, a 14% increase compared to PV-10 for year-end 2023, despite lower SEC pricing;
    
  
  
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    Benefited from acquisitions totaling 21.7 MMBoe, along with positive well performance and technical revisions of 5.0 MMBoe, partially offset by 10.5 MMBoe of negative price revisions and 12.2 MMBoe of production for the year, resulting in replacement of 219% of 2024 production with new reserves;
    
  
  
  
  


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  Incurred lease operating expenses (“LOE”) of $281.5 million in full year 2024, at the low end of the Company’s full year guidance range and $64.3 million in fourth quarter 2024, 12% below the low end of the Company’s fourth quarter guidance;
  


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  Acquired six shallow water GOA fields in January 2024 (“the Cox acquisition”), all of which are 100% working interest and located adjacent to existing W&T operations, for $77.3 million, which was funded with cash on hand;
  


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  Sold a non-core interest in Garden Banks Blocks 385 and 386 in January 2025, which included latest net production of approximately 195 barrels of oil equivalent per day (“Boe/d”) (72% oil) for $11.9 million (the “Garden Banks Disposition”), or over $60,000 per flowing barrel, after customary closing adjustments;
  


• 
  Received $58.5 million in cash for an insurance settlement (the “Insurance Settlement”) related to the Mobile Bay 78-1 well, in first quarter of 2025, which further bolsters W&T’s balance sheet;
  


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  Successfully refinanced the Company’s $275.0 million 11.75% Senior Second Lien Notes due 2026 (the “11.75% Notes”) and $114.2 million outstanding amount under the term loan provided by Munich Re Risk Financing, Inc., as lender (the “MRE Term Loan”) with proceeds from the issuance of new $350.0 million of 10.75% Senior Second Lien Notes due 2029 (the “10.75% Notes”) in January 2025 and available cash on hand;
  
  
  
  
  
  
  
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    Paid down and effectively reduced gross debt by around $39.0 million;
    
  
  
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    Eliminated principal payments of $27.6 million in 2025, $25.4 million in 2026, $22.9 million in 2027 and $38.3 million in 2028;
    
  
  
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    Lowered interest rate on the Senior Second Lien Notes by 100 basis points;
    
  
  
  
  


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  Entered into a new credit agreement in the first quarter 2025 for a $50 million revolving credit facility which matures in July 2028, that is undrawn and replaces the previous credit facility provided by Calculus Lending, LLC;
  


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  Reported net loss for full year 2024 of $87.1 million, or $(0.59) per diluted share and net loss of $23.4 million, or $(0.16) per diluted share for fourth quarter 2024;
  
  
  
  
  
  
  
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    Adjusted Net Loss totaled $67.6 million, or $(0.46) per diluted share for full year 2024, and $26.2 million, or $(0.18) per diluted share, for fourth quarter 2024, which primarily excludes the net unrealized gain on outstanding derivative contracts, non-ARO plugging and abandonment (“P&A”) costs, other costs and the related tax effect;
    
  
  
  
  


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  Generated Adjusted EBITDA of $153.6 million in full year 2024 and $31.6 million in the fourth quarter of 2024;
  


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  Produced net cash from operating activities of $59.5 million and Free Cash Flow of $44.9 million in full year 2024;
  


• 
  Reported cash and cash equivalents of $109.0 million, lowered total debt to $393.2 million and lowered Net Debt to $284.2 million at December 31, 2024;
  


• 
  Added costless collar hedges for 50,000 million British Thermal Units per day (“MMBtu/d”) of natural gas for the period of March through December 2025;
  


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  Paid fifth consecutive quarterly dividend of $0.01 per common share in November 2024; and
  
  
  
  
  
  
  
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    Declared first quarter 2025 dividend of $0.01 per share, which will be payable on March 24, 2025 to stockholders of record on March 17, 2025;
    
  
  
  
  

Tracy W. Krohn, W&T’s Chairman of the Board and Chief Executive Officer, commented, “We delivered solid results in 2024 thanks to our continued commitment to executing on our strategic vision focused on free cash flow generation, maintaining solid production and maximizing margins. We generated strong Adjusted EBITDA of $153.6 million and Free Cash Flow of $44.9 million for full year 2024. This was achieved despite limited contribution from the Cox acquisition as we continued to work on enhancing long-term value for these assets at the expense of deferring some near-term production. Some of this benefit is already reflected in our year-end reserves, which saw a 39% increase in oil reserves, and our PV-10 increased by almost $150 million, despite lower SEC pricing compared to year end 2023. We replaced production by over 200% with our positive revisions and acquisitions. Our focus on cost control and capturing synergies associated with our asset acquisitions contributed to our LOE coming in at the bottom end of our reduced guidance range. In addition, we are expecting further production uplift associated with the remaining fields from the Cox acquisition coming online in the second quarter of 2025 that have been shut in so that we could improve the facilities and transportation of production to enhance safety and efficiency of operations in the future.”

“In early 2025, we strengthened our balance sheet by closing the new 10.75% Notes, entered into a new revolving credit facility and added material cash through a non-core disposition and an insurance settlement. The new 10.75% Notes have an interest rate 100 basis points lower than our 11.75% Notes and received improved credit ratings from S&P and Moody’s, had a broad distribution including international investors and were significantly oversubscribed. We also received a $58.5 million cash insurance settlement payment related to a well loss event. Finally, we sold our non-core interests for $11.9 million after customary closing adjustments in Garden Banks 385 and 386 at over $60,000 per flowing barrel which is highly accretive to W&T. This further demonstrates the value of our assets and our ability to divest our properties at attractive multiples.”

Mr. Krohn concluded, “As we progress through 2025 with a stronger balance sheet, we remain poised to take advantage of potential acquisitions that will be accretive to our stakeholders. We remain committed to enhancing shareholder value and returning value to our shareholders through the quarterly dividend in place since November 2023. Our strategy has proven to be sustainable over the past 40 plus years, and we are well-positioned to continue to successfully execute it in the future.”

Production, Prices and Revenue:

Production for the fourth quarter of 2024 was 32.1 MBoe/d, within the Company’s fourth quarter guidance and up 4% compared with 31.0 MBoe/d for the third quarter of 2024 and down compared with 34.1 MBoe/d for the corresponding period in 2023. Production in the second half of 2024 was temporarily reduced mainly due to multiple named storms and third-party downtime. Fourth quarter 2024 production was comprised of 13.7 thousand barrels per day (“MBbl/d”) of oil (43%), 3.0 MBbl/d of natural gas liquids (“NGLs”) (9%), and 92.4 million cubic feet per day (“MMcf/d”) of natural gas (48%).

W&T’s average realized price per Boe before realized derivative settlements was $39.86 per Boe in the fourth quarter of 2024, a decrease of 5% from $41.92 per Boe in the third quarter of 2024 and a decrease of 4% from $41.55 per Boe in the fourth quarter of 2023. Fourth quarter 2024 oil, NGL and natural gas prices before realized derivative settlements were $68.71 per barrel of oil, $24.59 per barrel of NGL and $2.85 per Mcf of natural gas.

Revenues for the fourth quarter of 2024 were $120.3 million, which were slightly lower than the third quarter of 2024 revenues of $121.4 million driven by lower realized prices for oil. Fourth quarter 2024 revenues were approximately 9% lower than $132.3 million of revenues in the fourth quarter of 2023 due to lower average realized prices and lower production volumes.

Lease Operating Expenses:

LOE, which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance expenses, was $64.3 million in the fourth quarter of 2024, which was 12% below the low end of the previously provided guidance range of $73.0 to $81.0 million. LOE came in lower than expected as the Company continued to realize synergies from asset acquisitions in late 2023 and early 2024. LOE for the fourth quarter of 2024 was approximately 11% lower compared to $72.4 million in the third quarter of 2024 primarily due to favorable audit adjustments, an increase in royalty credits and lower repairs and maintenance costs. LOE for the fourth quarter of 2024 was essentially flat compared to $64.6 million for the corresponding period in 2023. On a component basis for the fourth quarter of 2024, base LOE and insurance premiums were $53.5 million, workovers were $0.9 million, and facilities maintenance and other expenses were $9.9 million. On a unit of production basis, LOE was $21.76 per Boe in the fourth quarter of 2024. This compares to $25.37 per Boe for the third quarter of 2024 and $20.61 per Boe for the fourth quarter of 2023, reflecting a decrease in production in the periods.

Gathering, Transportation Costs and Production Taxes:

Gathering, transportation costs and production taxes totaled $5.9 million ($2.00 per Boe) in the fourth quarter of 2024, compared to $6.1 million ($2.15 per Boe) in the third quarter of 2024 and $6.6 million ($2.11 per Boe) in the fourth quarter of 2023. Gathering, transportation costs and production taxes decreased in the fourth quarter of 2024 from the prior quarter due to lower processing and transportation fees offset by increased production taxes.

Depreciation, Depletion and Amortization (“DD&A”):

DD&A was $12.94 per Boe in the fourth quarter of 2024. This compares to $11.99 per Boe and $10.73 per Boe for the third quarter of 2024 and the fourth quarter of 2023, respectively.

Asset Retirement Obligations Accretion:

Asset retirement obligations accretion was $2.76 per Boe in the fourth quarter of 2024. This compares to $2.75 per Boe and $2.35 per Boe for the third quarter of 2024 and the fourth quarter of 2023, respectively.

General & Administrative Expenses (“G&A”):

G&A was $20.8 million for the fourth quarter of 2024, which increased from $19.7 million in the third quarter of 2024 primarily due to higher quarter over quarter accrual for non-cash long-term incentives and increased from $18.3 million in the fourth quarter of 2023 primarily due to higher quarter over quarter accruals for short-term incentives and non-cash long term incentives. On a unit of production basis, G&A was $7.04 per Boe in the fourth quarter of 2024 compared to $6.91 per Boe in the third quarter of 2024 and $5.82 per Boe in the corresponding period of 2023. These differences are primarily related to production variances.

Derivative (Gain) Loss, net:

In the fourth quarter of 2024, W&T recorded a net loss of $2.1 million with commodity derivative contracts comprised of $2.6 million of realized losses and $0.5 million of unrealized gains related to the increase in fair value of open contracts. W&T recognized a net gain of $3.2 million in the third quarter of 2024 and a net gain of $13.2 million in the fourth quarter of 2023 related to commodity derivative activities.

To take advantage of the recent uptick in prices for natural gas, W&T recently added Henry Hub costless collars for 50,000 MMBtu/d of natural gas for the period of March through December 2025 with a floor of $3.88 per MMBtu and a ceiling of $5.125 per MMBtu.

A summary of the Company’s outstanding derivative positions is provided in the investor presentation posted on W&T’s website.

Interest Expense:

Net interest expense in the fourth quarter of 2024 was $10.2 million compared to $10.0 million in the third quarter of 2024 and $9.7 million in the fourth quarter of 2023.

Other Expense:



During 2021 and 2022, as a result of the declaration of bankruptcy by a third party that is the indirect successor in title to certain offshore interests that were previously divested by the Company, W&T recorded a contingent loss accrual related to anticipated non-ARO P&A costs. During the fourth quarter of 2024, the Company reassessed its existing obligations and recorded a $2.8 million decrease in the contingent loss accrual.

Income Tax (Benefit) Expense:

W&T recognized an income tax benefit of $1.8 million in the fourth quarter of 2024. This compares to the recognition of an income tax benefit of $4.5 million and an income tax expense of $1.9 million for the quarters ended September 30, 2024 and December 31, 2023, respectively.

Capital Expenditures and Asset Retirement Settlements:

Capital expenditures on an accrual basis (excluding acquisitions) in the fourth quarter of 2024 were $12.2 million, and asset retirement settlement costs totaled $19.3 million. For the year ended December 31, 2024, capital expenditures on an accrual basis (excluding acquisitions) totaled $28.6 million and asset retirements costs were $39.7 million. Investments related to acquisitions in the year ended December 31, 2024 totaled $80.6 million, which included $77.3 million for the Cox acquisition and $3.3 million of final purchase price adjustments related to W&T’s acquisition of properties in September 2023.

Balance Sheet and Liquidity:

As of December 31, 2024, W&T had available liquidity of $159.0 million comprised of $109.0 million in unrestricted cash and cash equivalents and $50.0 million of borrowing availability under W&T’s first priority secured revolving facility provided by Calculus Lending LLC. As of December 31, 2024, the Company had total debt of $393.2 million and Net Debt of $284.2 million. As of December 31, 2024, Net Debt to trailing twelve months (“TTM”) Adjusted EBITDA was 1.8x.

Debt Refinance:

On January 28, 2025 W&T closed an offering of the 10.75% Notes at par in a private offering that was exempt from registration under the Securities Act of 1933, as amended. The Company used a portion of the proceeds from the 10.75% Notes offering, along with cash on hand to, (i) purchase for cash pursuant to a tender offer, such of the Company’s outstanding 11.75% Notes that were validly tendered pursuant to the terms thereof, (ii) repay $114.2 million outstanding under the 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 premiums, fees and expenses related to these transactions. On the closing date of the offering of the 10.75% Notes, the Company completed all actions necessary to satisfy and discharge the indenture governing the 11.75% Notes.

Pro forma for the debt refinance, the Garden Banks Disposition and the Insurance Settlement, as of December 31, 2024, W&T’s cash and cash equivalents would have been approximately $104.3 million, total debt would have been approximately $349.5 million and Net Debt would have been approximately $245.2 million. As of December 31, 2024, the pro forma Net Debt to TTM Adjusted EBITDA would have been 1.6x.

In conjunction with the issuance of the 10.75% Notes, the Company entered into a new credit agreement which provides the Company with a revolving credit and letter of credit facility, with initial lending commitments of $50 million with a letter of credit sublimit of $10 million. The Credit Facility matures on July 28, 2028.

Accretive Acquisition of Producing Properties in the GOA:

In January 2024, W&T was the successful bidder for six fields in the GOA, including Eugene Island 64, Main Pass 61, Mobile 904, Mobile 916, South Pass 49 and West Delta 73, all of which include a 100% working interest and an average 82% net revenue interest. They are located in water depths ranging between approximately 15 and 400 feet. Their proximity to W&T’s areas of existing operations provides the ability for W&T to capture synergies regarding personnel, well optimization, gathering and transport. The final purchase price for the assets was $77.3 million, after closing costs and other transaction costs, which were funded from the Company’s cash on hand. Key highlights of the transaction included:

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  Added significant year-end 2024 reserves of 21.7 MMBoe (62% liquids), even after excluding 1.3 MMBoe of production during 2024;
  


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  Based on the cash consideration paid of $77.3 million, this equates to a price of $3.38 per Boe of 2024 SEC reserves booked, when adding back 2024 production of 1.3 MMBoe;
  


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  Multiple fields were immediately shut-in while improvements were made to bring them up to W&T’s standards for safety and efficiency. Those fields are expected to come back online in the first half of 2025;
  
  
  
  
  
  
  
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    The Main Pass 108 and 98 fields as well as the West Delta 73 field are expected to return to production in the second quarter of 2025; and
    
  
  
  
  


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  The Company believes that it can further increase production on these properties through workovers, recompletions and ongoing facility upgrades.
  
  
  

Non-Core Asset Disposition

In early 2025, W&T sold a non-core interest in Garden Banks Blocks 385 and 386, which included net production of approximately 195 Boe/d, for $11.9 million after normal purchase price adjustments. The effective date of the sale was December 1, 2024, and the transaction closed in January 2025. The impact to W&T’s reserves for year-end 2024 were minimal at about 0.12 MMBoe.

Full Year-End 2024 Financial Review

W&T reported a net loss for the full year 2024 of $87.1 million, or $(0.59) per diluted share, and Adjusted Net Loss of $67.6 million, or $(0.46) per diluted share. For the full year 2023, the Company reported net income of $15.6 million, or $0.11 per diluted share, and Adjusted Net Loss of $21.7 million, or $(0.15) per diluted share. W&T generated Adjusted EBITDA of $153.6 million for the full year 2024 compared to $183.2 million in 2023. The year-over-year decrease was primarily driven by lower oil and natural gas prices and decreased production. Revenues totaled $525.3 million for 2024 compared with $532.7 million in 2023. Net cash provided by operating activities for the year ended December 31, 2024 was $59.5 million compared with $115.3 million for the same period in 2023. Free Cash Flow totaled $44.9 million in 2024 compared with $63.3 million in 2023.

Production for 2024 averaged 33.3 MBoe/d for a total of 12.2 MMBoe, comprised of 5.3 MMBbl of oil, 1.2 MMBbl of NGLs and 34.3 Bcf of natural gas. Full year 2023 production averaged 34.9 MBoe/d or 12.7 MMBoe in total and was comprised of 5.1 MMBbl of oil, 1.4 MMBbl of NGLs and 37.6 Bcf of natural gas.

For the full year 2024, W&T’s average realized sales price per barrel of crude oil was $75.28 and $23.08 per barrel of NGLs and $2.65 per Mcf of natural gas. While the realized pricing for oil and natural gas were down year-over-year, the production mix was more weighted toward oil in 2024, thus the equivalent sales price for 2024 was $42.23 per Boe, which was 3% higher than the equivalent price of $41.16 per Boe realized in 2023.  For 2023, the Company’s realized crude oil sales price was $75.52 per barrel, NGL sales price was $22.93 per barrel, and natural gas price was $2.93 per Mcf.

For the full year 2024, LOE was $281.5 million compared to $257.7 million in 2023. While LOE increased year-over-year in 2024 due to increased workover and facility investments, higher oil production and costs from the acquisition of additional properties in January 2024 and September 2023, W&T’s LOE for 2024 was 10% below the midpoint guidance for LOE as the Company was able to mitigate some of these increased costs through synergies from the asset acquisitions.

Gathering, transportation, and production taxes totaled $28.2 million in 2024, an increase from the $26.3 million in 2023.

For the full year 2024, G&A was $82.4 million, which was a 9% increase over the $75.5 million reported in 2023. The increase year-over-year is primarily due to increased salary and benefits costs and non-recurring legal fees that were somewhat offset by lower accruals for short-term incentives. On a per unit basis, G&A per Boe was $6.76 in 2024, up from $5.93 per Boe in 2023.  G&A increased on a per Boe basis primarily due to lower production.

OPERATIONS UPDATE

Well Recompletions and Workovers

During the fourth quarter of 2024, the Company performed two workovers and two recompletions that positively impacted production for the quarter. W&T plans to continue performing these low cost and low risk short payout operations that impact both production and revenue.

Year-End 2024 Proved Reserves

The Company’s year-end 2024 SEC proved reserves were 127.0 MMBoe, compared with 123.0 MMBoe at year-end 2023. In 2024, W&T recorded positive performance revisions of 5.0 MMBoe, and acquisitions of reserves of 21.7 MMBoe, which were offset by 10.5 MMBoe of negative price revisions and 12.2 MMBoe of production for the year.  During 2024, W&T continued to focus on reducing Net Debt while identifying and executing attractive acquisitions.  Successful workovers, operational excellence and acquisitions allowed W&T to replace 219% of production with new reserves.

The SEC twelve-month first day of the month average spot prices used in the preparation of the report for year-end 2024 were $76.32 per barrel of oil and $2.13 per MMBtu of natural gas. Comparable prices used for the prior year report were $78.21 per barrel of oil and $2.64 per MMBtu of natural gas. The PV-10 of W&T’s proved reserves at year-end 2024 increased 14% to $1.2 billion from $1.1 billion at year-end 2023, driven primarily by an increase in oil reserves due to the acquisition in January 2024 and by positive reserve performance revisions which were somewhat offset by lower SEC pricing.

Approximately 51% of year-end 2024 proved reserves were liquids (41% crude oil and 10% NGLs) and 49% natural gas. The reserves were classified as 52% proved developed producing, 31% proved developed non-producing, and 17% proved undeveloped. W&T’s reserve life ratio at year-end 2024, based on year-end 2024 proved reserves and 2024 production, was 10.4 years.

⁽¹⁾

PV-10 for this presentation excludes any provisions for asset retirement obligations or income taxes.

In accordance with guidelines established by the SEC, estimated proved reserves as of December 31, 2024 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average of the first-day-of-the-month price for the year ended December 31, 2024. The WTI spot price and the Henry Hub spot price were utilized as the reference prices and after adjusting for quality, transportation, fees, energy content, and regional price differentials, the average realized prices were $74.69 per barrel for oil, $22.98 per barrel for NGLs, and $2.58 per Mcf for natural gas. In determining the estimated realized price for NGLs, a ratio was computed for each field of the NGLs realized price compared to the crude oil realized price. This ratio was then applied to the crude price using SEC guidance. Such prices were held constant throughout the estimated lives of the reserves. Future estimated production and development costs are based on year-end costs with no escalations.

The standardized measure of future net cash flows was $740.1 million at December 31, 2024, which is calculated as the PV-10 of $1,229.5 million less discounted cash outflows of $334.6 million associated with asset retirement obligations and $154.8 million associated with income taxes. At December 31, 2023, the standardized measure was $683.2 million, which is calculated as the PV-10 of $1,080.9 million less discounted cash outflows of $246.7 million associated with asset retirement obligations and $151.0 million associated with income taxes.

First Quarter and Full Year 2025 Production and Expense Guidance

The guidance for the first quarter and full year 2025 in the table below represents the Company’s current expectations. Please refer to the section entitled “Forward-Looking and Cautionary Statements” below for risk factors that could impact guidance.

In the first quarter of 2025, there have been several planned facility and pipeline maintenance projects as well as unplanned downtime at several fields due to multiple winter freezes in the first quarter of 2025 that temporarily reduced production. Full year 2025 production reflects the West Delta 73 field returning to production in the second quarter as well as the other fields that were temporarily shut-in during the first quarter of 2025. First quarter 2025 LOE is expected to be higher than the prior quarter due to increased maintenance and repair costs and facility upgrades; full year 2025 LOE is expected to be modestly higher than 2024.

W&T expects substantially all income taxes in 2025 to be deferred.

2025 Capital Investment Program

W&T’s capital expenditure budget for 2025 is expected to be in the range of $34.0 million to $42.0 million, which excludes potential acquisition opportunities.  Included in this range are planned expenditures related to asset integrations as well as ongoing costs related to the acquisitions for facilities, leasehold, seismic, and recompletions.

Plugging and abandonment expenditures are expected to be in the range of $27.0 million to $37.0 million.  The Company spent approximately $40 million on these costs in 2024.

Conference Call Information:

W&T will hold a conference call to discuss its financial and operational results on Tuesday, March 4, 2025 at 9:00 a.m. Central Time (10:00 a.m. Eastern Time). Interested parties may dial 1-844-739-3797. International parties may dial 1-412-317-5713. Participants should request to connect to the “W&T Offshore Conference Call.” This call will also be webcast and available on W&T’s website at

www.wtoffshore.com

under “Investors.” An audio replay will be available on the Company’s website following the call.

About W&T Offshore

W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of America and has grown through acquisitions, exploration and development. As of December 31, 2024, the Company had working interests in 52 fields in federal and state waters (which include 45 fields in federal waters and seven in state waters). The Company has under lease approximately 646,200 gross acres (502,300 net acres) spanning across the outer continental shelf off the coasts of Louisiana, Texas, Mississippi and Alabama, with approximately 493,000 gross acres on the conventional shelf, approximately 147,700 gross acres in the deepwater and 5,500 gross acres in Alabama state waters. A majority of the Company’s daily production is derived from wells it operates. For more information on W&T, please visit the Company’s website at

www.wtoffshore.com

.

Forward-Looking and Cautionary Statements

This press release contains 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. All statements other than statements of historical facts included in this release, including those regarding the Company’s financial position, operating and financial performance, business strategy, plans and objectives of management for future operations, projected costs, industry conditions, potential acquisitions, sustainability initiatives, the impact of and integration of acquired assets, and indebtedness are forward-looking statements. When used in this release, forward-looking statements are generally accompanied by terms or phrases such as “estimate,” “project,” “predict,” “believe,” “expect,” “continue,” “anticipate,” “target,” “could,” “plan,” “intend,” “seek,” “goal,” “will,” “should,” “may” or other words and similar expressions that convey the uncertainty of future events or outcomes, although not all forward-looking statements contain such identifying words. Items contemplating or making assumptions about actual or potential future production and sales, prices, market size, and trends or operating results also constitute such forward-looking statements.

These forward-looking statements are based on the Company’s current expectations and assumptions about future events and speak only as of the date of this release. While management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond the Company’s control. Accordingly, you are cautioned not to place undue reliance on these forward-looking statements, as results actually achieved may differ materially from expected results described in these statements. The Company does not undertake, and specifically disclaims, any obligation to update any forward-looking statements to reflect events or circumstances occurring after the date of such statements, unless required by law.

Forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially including, among other things, the regulatory environment, including availability or timing of, and conditions imposed on, obtaining and/or maintaining permits and approvals, including those necessary for drilling and/or development projects; the impact of current, pending and/or future laws and regulations, and of legislative and regulatory changes and other government activities, including those related to permitting, drilling, completion, well stimulation, operation, maintenance or abandonment of wells or facilities, managing energy, water, land, greenhouse gases or other emissions, protection of health, safety and the environment, or transportation, marketing and sale of the Company’s products; inflation levels; global economic trends, geopolitical risks and general economic and industry conditions, such as the global supply chain disruptions and the government interventions into the financial markets and economy in response to inflation levels and world health events; volatility of oil, NGL and natural gas prices; the global energy future, including the factors and trends that are expected to shape it, such as concerns about climate change and other air quality issues, the transition to a low-emission economy and the expected role of different energy sources; supply of and demand for oil, natural gas and NGLs, including due to the actions of foreign producers, importantly including OPEC and other major oil producing companies (“OPEC+”) and change in OPEC+’s production levels; disruptions to, capacity constraints in, or other limitations on the pipeline systems that deliver the Company’s oil and natural gas and other processing and transportation considerations; inability to generate sufficient cash flow from operations or to obtain adequate financing to fund capital expenditures, meet the Company’s working capital requirements or fund planned investments; price fluctuations and availability of natural gas and electricity; the Company’s ability to use derivative instruments to manage commodity price risk; the Company’s ability to meet the Company’s planned drilling schedule, including due to the Company’s ability to obtain permits on a timely basis or at all, and to successfully drill wells that produce oil and natural gas in commercially viable quantities; uncertainties associated with estimating proved reserves and related future cash flows; the Company’s ability to replace the Company’s reserves through exploration and development activities; drilling and production results, lower–than–expected production, reserves or resources from development projects or higher–than–expected decline rates; the Company’s ability to obtain timely and available drilling and completion equipment and crew availability and access to necessary resources for drilling, completing and operating wells; changes in tax laws; effects of competition; uncertainties and liabilities associated with acquired and divested assets; the Company’s ability to make acquisitions and successfully integrate any acquired businesses; asset impairments from commodity price declines; large or multiple customer defaults on contractual obligations, including defaults resulting from actual or potential insolvencies; geographical concentration of the Company’s operations; the creditworthiness and performance of the Company’s counterparties with respect to its hedges; impact of derivatives legislation affecting the Company’s ability to hedge; failure of risk management and ineffectiveness of internal controls; catastrophic events, including tropical storms, hurricanes, earthquakes, pandemics and other world health events; environmental risks and liabilities under U.S. federal, state, tribal and local laws and regulations (including remedial actions); potential liability resulting from pending or future litigation; the Company’s ability to recruit and/or retain key members of the Company’s senior management and key technical employees; information technology failures or cyberattacks; and governmental actions and political conditions, as well as the actions by other third parties that are beyond the Company’s control, and other factors discussed in W&T Offshore’s most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q found at www.sec.gov or at the Company’s website at www.wtoffshore.com under the Investor Relations section.

(1)   MBoe is determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. The realized prices presented above are volume-weighted for production in the respective period.