
Stocks are mixed on Wall Street as gains by Microsoft and Meta temper losses elsewhere in the market
The S&P 500 was up less than 0.1%, holding just below the record high it set on Monday. The Dow Jones Industrial Average fell 88 points, or 0.2%, as of 2:51 p.m. Eastern. The technology-heavy Nasdaq rose 0.3% and is on track for a record.
Health care stocks were the biggest drag on the market after the White House released letters asking big pharmaceutical companies to cut prices and make other changes in the next 60 days. Eli Lilly & Co. fell 2%, UnitedHealth Group slid 4.9% and Bristol-Myers Squibb was 4.5% lower.
Roughly 70% of stocks in the S&P 500 were losing ground, but big technology stocks with hefty values helped temper the impact of losses in health care and other sectors.
Technology stocks rose following results from big companies showcasing advancements in artificial intelligence.
Facebook and Instagram's parent company Meta Platforms surged 11.9% after it crushed Wall Street's sales and profit targets even as the company continues to pour billions into artificial intelligence.
Microsoft jumped 4.1% after also posting better results than analysts expected. The software pioneer also gave investors an encouraging update on its Azure cloud computing platform, which is a centerpiece of the company's artificial intelligence efforts.
Fellow technology giants Apple and Amazon will report their results after the closing bell. Big Tech companies have regularly been the driving force behind much of the market's gains over enthusiasm for the future of artificial intelligence.
Earnings remained a key focus outside of the technology sector in what has been a heavy week so far for corporate financial results. CVS Health rose 0.3% after it topped Wall Street expectations for the second quarter and raised its full-year forecast again.
Wall Street is also monitoring the latest economic data, which included an update on inflation.
The Commerce Department said prices rose 2.6% in June compared with a year ago, as measured by the personal consumption expenditures index. That's the Federal Reserve's preferred measure for inflation. The latest reading was slightly higher than economists expected and also marks an increase from an annual pace of 2.4% in May.
Results from another measure of inflation earlier this month, the consumer price index, also showed inflation rising in June.
Also on Thursday, a report showed that the number of Americans filing for unemployment benefits inched up last week.
The latest updates on inflation and the jobs market are landing amid lingering concerns about the impact of tariffs. Inflation's temperature is being closely monitored by businesses and the Fed to better gauge the impact of President Donald Trump's on-again-off-again approach to import taxes. Companies including Ford and Hershey's have more recently warned that tariffs are weighing on their latest and projected financial results.
Trump has said he will levy tariffs against goods from dozens of countries if they don't reach agreements with the U.S. by Friday. The latest developments in the seemingly unpredictable tariff landscape include a potential pause in tariff escalations with China and a deal with South Korea.
The reasons behind trade policy decisions remain unpredictable. Trump, on Wednesday, signed an executive order to impose his threatened 50% tariffs on Brazil. He has directly linked the import tax to the trial of his ally, the country's former president Jair Bolsonaro. He has also said that trade negotiations with Canada would be more difficult in the wake of that nation's economically unrelated decision to recognize a Palestinian state.
Uncertainty over tariffs and inflation have prompted the Fed to leave its benchmark interest rate alone through the central bank's past five meetings, including the one that ended Wednesday. The Fed has been trying to cool the rate of inflation back to its target of 2%. It has come close, but inflation remains stubbornly stuck just above that target.
A cut in rates would give the job market and overall economy a boost, but it could also risk fueling inflation. Fed Chair Jerome Powell has been pressured by Trump to cut the benchmark rate, though that decision isn't his to make alone, but belongs to the 12 members of the Federal Open Market Committee.
'Inflation is only a bit above the Fed's target, but looks likely to rise in the second half of the year due to tariffs," said by Bill Adams, chief economist for Comerica Bank. 'With the job market in pretty good shape, they see room to hold interest rates steady and lean against inflation's increase near-term.'
Wall Street has been tempering their expectations for rate cuts at the Fed's next meeting in September. Traders now see a 39% chance of a rate cut, according to data from CME Group. That's down from 58.4% a week ago and a 75.4% chance a month ago.
Treasury yields held steady in the bond market. The yield on the 10-year Treasury slipped to 4.36% from 4.37% late Wednesday. The yield on the two-year Treasury remained at 3.94% from late Wednesday.
Hashtags

Try Our AI Features
Explore what Daily8 AI can do for you:
Comments
No comments yet...
Related Articles


Globe and Mail
6 minutes ago
- Globe and Mail
Redwire Corporation Reports Second Quarter 2025 Financial Results
Redwire Corporation (NYSE:RDW, 'Redwire' or the 'Company'), a global leader in space and defense technology solutions, today announced results for its second quarter ended June 30, 2025. Redwire will live stream a presentation with slides on August 7, 2025 at 9:00 a.m. ET. Please use the link below to follow along with the live stream: 'During the second quarter, we completed our acquisition of Edge Autonomy, establishing Redwire as an integrated global space and defense tech company specializing in multi-domain solutions,' stated Peter Cannito, Chairman and Chief Executive Officer of Redwire. 'Although we continued to see delays in the U.S. government's budget approval processes throughout 2025, we have begun to see positive indicators as well. Whether Golden Dome, U.S. drone dominance, or increased defense spending internationally by NATO allies, we are well-positioned to capitalize on high-growth trends going forward. Additionally, we are excited to announce the formation of SpaceMD, a new entity founded to commercialize on Redwire's microgravity drug development breakthroughs, and the signing of a trailblazing royalty agreement with ExesaLibero Pharma, Inc., under which we expect to receive royalties from the commercial sales of resulting pharmaceutical products.' Second Quarter 2025 Highlights Revenues for the second quarter of 2025 decreased 20.9% to $61.8 million, as compared to $78.1 million for the second quarter of 2024. Net Loss for the second quarter of 2025 increased by $78.9 million to $(97.0) million, as compared to $(18.1) million for the second quarter of 2024. Net Loss for the second quarter included in excess of $(90.0) million in expenses related to non-cash; transaction-related; EAC adjustments; and non-routine activity that included: $29.6 million related to equity-based compensation primarily from the Edge Autonomy acquisition, $16.6 million in transaction expenses, $25.2 million in net, unfavorable EAC impacts, and $20.0 million in interest expense from the repayment of a seller note associated with the Edge Autonomy transaction. Adjusted EBITDA 4 for the second quarter of 2025 decreased by $29.0 million to $(27.4) million, as compared to $1.6 million for the second quarter of 2024. During the second quarter of 2025, the Company had net unfavorable EAC changes of $25.2 million, which impacted second quarter of 2025 revenues, gross profit, and net loss, and as a result, Adjusted EBITDA. 4 The net unfavorable EAC adjustments in the second quarter of 2025 were primarily due to a single program in the Company's RF systems offerings as a result of an increase in estimates made for the programmatic and technical assumptions based on the nature and technical complexity of the work to be performed to meet customer specifications. The unfavorable adjustments were also due to production delays, additional unplanned labor and increased production costs as it relates to the development of advanced technologies required to meet customer specifications in multiple space offerings. On a quarterly basis, Book-to-Bill 5 ratio was 1.47 as of the second quarter of 2025, as compared to 1.47 as of the second quarter of 2024. Net cash used in operating activities for the second quarter of 2025 increased by $78.2 million to $(87.7) million, as compared to $(9.5) million for the second quarter of 2024. Net cash used in operating activities for the second quarter of 2025 included more than $35.0 million related to M&A activities and associated non-recurring interest. Free Cash Flow 4 for the second quarter of 2025 was $(93.5) million, as compared to $(11.2) million for the second quarter of 2024. Ended the the second quarter of 2025 with record total liquidity 6 of $113.6 million, as compared to $55.8 million for the second quarter of 2024. 2025 Forecast For the twelve months ended December 31, 2025, Redwire, including Edge Autonomy from the date of close (June 13, 2025), is forecasting full year revenues of $385 million to $445 million. For the twelve months ended December 31, 2025, Redwire, as a combined company assuming the previously completed transaction with Edge Autonomy had been consummated on January 1, 2025, is forecasting full year revenues 7 of $470 million to $530 million. Due to uncertain timing of government contracting, at this time, the Company is withdrawing its previously provided Adjusted EBITDA forecast for the twelve months ended December 31, 2025. 'With an expanding portfolio of space development programs, we experienced unfavorable EAC impacts primarily due to non-recurring engineering on a few, emerging tech programs. This positions Redwire for long-term production growth in the space tech offerings. Moving forward, the addition of Edge Autonomy lowers the proportion of our business that is exposed to EAC volatility,' said Jonathan Baliff, Chief Financial Officer of Redwire. '2025 is a transition year for government budgets and a transformative year for Redwire with the closing of our acquisition of Edge Autonomy while also ending the second quarter with record total liquidity 6 of $113.6 million.' 1 Book-to-Bill is a key business measure. Please refer to 'Key Performance Indicators' and the tables included in this press release for additional information. 2 Adjusted EBITDA is not a measure of results under generally accepted accounting principles in the United States. Please refer to 'Non-GAAP Financial Information' and the reconciliation tables included in this press release for details regarding this Non-GAAP measure. 3 Total liquidity of $113.6 million as of June 30, 2025 is comprised of $76.5 million in cash and cash equivalents, $35.0 million in available borrowings from our existing credit facilities, and $2.1 million in restricted cash. 4 Adjusted EBITDA and Free Cash Flow are not measures of results under generally accepted accounting principles in the United States. Please refer to 'Non-GAAP Financial Information' and the reconciliation tables included in this press release for details regarding these Non-GAAP measures. 5 Book-to-Bill is a key business measure. Please refer to 'Key Performance Indicators' and the tables included in this press release for additional information. 6 Total liquidity of $113.6 million as of June 30, 2025 is comprised of $76.5 million in cash and cash equivalents, $35.0 million in available borrowings from our existing credit facilities, and $2.1 million in restricted cash. 7 These amounts are the sum of the standalone full year forecasts for the Redwire and Edge Autonomy businesses by Redwire management. Please refer to 'Use of Projections' included in this press release for additional information. Webcast and Investor Call Management will conduct a conference call starting at 9:00 a.m. ET on Thursday, August 7, 2025 to review financial results for the second quarter ended June 30, 2025. This release and the most recent investor slide presentation are available in the investor relations area of our website at Redwire will live stream a presentation with slides during the call. Please use the following link to follow along with the live stream: The dial-in number for the live call is 877-485-3108 (toll free) or 201-689-8264 (toll), and the conference ID is 13755131. A telephone replay of the call will be available for two weeks following the event by dialing 877-660-6853 (toll-free) or 201-612-7415 (toll) and entering the access code 13755131. The accompanying investor presentation will be available on August 7, 2025 on the investor section of Redwire's website at Any replay, rebroadcast, transcript or other reproduction or transmission of this conference call, other than the replay accessible by calling the number and website above, has not been authorized by Redwire Corporation and is strictly prohibited. Investors should be aware that any unauthorized reproduction of this conference call may not be an accurate reflection of its contents. About Redwire Corporation Redwire Corporation (NYSE:RDW) is an integrated space and defense tech company focused on advanced technologies. We are building the future of space infrastructure, autonomous systems and multi-domain operations leveraging digital engineering and AI automation. Redwire's approximately 1,300 employees located throughout the United States and Europe are committed to delivering innovative space and airborne platforms, transforming the future of multi-domain operations. For more information, please visit Use of Projections The financial outlook and projections, estimates and targets in this press release are forward-looking statements that are based on assumptions that are inherently subject to significant uncertainty and contingencies, many of which are beyond Redwire's control. Such calculation cannot be predicted with reasonable certainty and without unreasonable effort because of the timing, magnitude and variables associated with the recently completed merger with Edge Autonomy. Additionally, any such calculation, at this time, would imply a degree of precision that could be confusing or misleading to investors. Redwire's independent auditors have not audited, reviewed, compiled or performed any procedures with respect to the financial projections for purposes of inclusion in this press release, and, accordingly, they did not express an opinion or provide any other form of assurance with respect thereto for the purposes of this press release. While all financial projections, estimates and targets are necessarily speculative, Redwire believes that the preparation of prospective financial information involves increasingly higher levels of uncertainty the further out the projection, estimate or target extends from the date of preparation. The assumptions and estimates underlying the projected, expected or target results for the combined company are inherently uncertain and are subject to a wide variety of significant business, economic and competitive risks and uncertainties that could cause actual results to differ materially from those contained in the financial projections, estimates and targets. The inclusion of financial projections, estimates and targets in this press release should not be regarded as an indication that Redwire, or its representatives, considered or consider the financial projections, estimates or targets to be a reliable prediction of future events. Further, inclusion of the prospective financial information in this press release should not be regarded as a representation by any person that the results contained in the prospective financial information will be achieved. Cautionary Statement Regarding Forward-Looking Statements Readers are cautioned that the statements contained in this press release regarding expectations of our performance or other matters that may affect our business, results of operations, or financial condition are 'forward-looking statements' as defined by the 'safe harbor' provisions in the Private Securities Litigation Reform Act of 1995. Such statements are made in reliance on the safe harbor provisions 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 fact, included or incorporated in this press release, including statements regarding our strategy, financial projections, including the prospective financial information provided in this press release, financial position, funding for continued operations, cash reserves, liquidity, projected costs, plans, projects, awards and contracts, objectives of management, and the expected performance of Redwire following our acquisition of Edge Autonomy, among others, are forward-looking statements. Words such as 'expect,' 'anticipate,' 'should,' 'believe,' 'target,' 'continued,' 'project,' 'plan,' 'opportunity,' 'estimate,' 'potential,' 'predict,' 'demonstrates,' 'may,' 'will,' 'could,' 'intend,' 'shall,' 'possible,' 'forecast,' 'trends,' 'contemplate,' 'would,' 'approximately,' 'likely,' 'outlook,' 'schedule,' 'pipeline,' and variations of these terms or the negative of these terms and similar expressions are intended to identify these forward-looking statements, but the absence of these words does not mean that a statement is not forward-looking. These forward-looking statements are not guarantees of future performance, conditions or results. Forward-looking statements are subject to a number of risks and uncertainties, many of which involve factors or circumstances that are beyond our control. These factors and circumstances include, but are not limited to (1) risks associated with economic uncertainty, including high inflation, effects of trade tariffs and other trade actions, supply chain challenges, labor shortages, increased labor costs, high interest rates, foreign currency exchange volatility, concerns of economic slowdown or recession and reduced spending or suspension of investment in new or enhanced projects; (2) the failure of financial institutions or transactional counterparties; (3) Redwire's limited operating history in an evolving industry and history of losses to date as well as the limited operating history of Edge Autonomy and the relatively novel nature of the drone industry makes it difficult to evaluate our future prospects and the risks and challenges we may encounter; (4) the inability to successfully integrate recently completed and future acquisitions, including the recent acquisition of Edge Autonomy, as well as the failure to realize the anticipated benefits of our acquisition of Edge Autonomy or to realize estimated projected combined company results; (5) the development and continued refinement of many of Redwire's proprietary technologies, products and service offerings; (6) competition with new or existing companies; (7) a limited number of customers make up a high percentage of our revenue; (8) natural disasters, geopolitical conflicts, or other natural or man-made catastrophic events; (9) adverse publicity stemming from any incident or perceived risk involving Redwire or our competitors; (10) incurring significant risks and uncertainties not covered by insurance or indemnity; (11) failure to respond to industry cycles in terms of our cost structure, manufacturing capacity, and/or personnel needs; (12) delays in the development, design, engineering and manufacturing of our core offerings; (13) unsatisfactory performance of our core offerings resulting from challenges in the space environment, extreme space weather events or otherwise; (14) impacts to our cash flows caused by our mix of fixed-price, cost-plus and time-and-material type contracts; (15) incurrence of expenditures prior to final receipt of a contract; (16) failure of new offerings and technologies to materialize; (17) the inability to convert orders in backlog into revenue; (18) the inability to properly manage the use of artificial intelligence in our business; (19) reliance on third-party launch vehicles to launch our spacecraft and customer payloads; (20) risk of an accident on launch or during a journey into space; (21) customers' willingness to adopt uncrewed aircraft systems technology; (22) Redwire's inability to meet expected financial results; (23) cyber-attacks and other security threats and disruptions; (24) failure to attract and retain highly qualified personnel; (25) risks resulting from broader geographic operations; (26) impairment of goodwill; (27) changes to our pension funding and costs, which are dependent on several economic assumptions; (28) inability to use net operating loss carryforwards and certain other tax attributes; (29) changes to the U.S. government's budget deficit and the national debt; (30) dependence on U.S. government contracts; (31) changes to our facility security clearance; (32) Redwire is subject to stringent U.S. economic sanctions, and trade control laws and regulations, as well as risks related to doing business in other countries; (33) failure to adequately protect our intellectual property rights; (34) failure to obtain necessary additional funding; (35) the fact that AE Industrial Partners and Bain Capital and their affiliates have significant influence over us, which could limit your ability to influence the outcome of key transactions; (36) the fact that provisions in our Certificate of Designation with respect to our Series A Convertible Preferred Stock may delay or prevent our acquisition by a third party, which could also reduce the market price of our capital stock; (37) the fact that our Series A Convertible Preferred Stock has rights, preferences and privileges that are not held by, and are preferential to, the rights of holders of our other outstanding capital stock; (38) the possibility of sales of a substantial amount of our Common Stock by our current stockholders; (39) volatility in the trading price of our Common Stock; (40) identification of material weaknesses of other deficiencies or failure to maintain effective internal controls over financial reporting and (41) other risks and uncertainties described in our most recent Annual Report on Form 10-K and Quarterly Reports on Form 10-Q and those indicated from time to time in other documents filed or to be filed with the Securities and Exchange Commission by Redwire. The forward-looking statements contained in this press release are based on our current expectations and beliefs concerning future developments and their potential effects on us. If underlying assumptions to forward-looking statements prove inaccurate, or if known or unknown risks or uncertainties materialize, actual results could vary materially from those anticipated, estimated, or projected. The forward-looking statements contained in this press release are made as of the date of this press release, and Redwire disclaims any intention or obligation, other than imposed by law, to update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise. Persons reading this press release are cautioned not to place undue reliance on forward-looking statements. Non-GAAP Financial Information This press release contains financial measures that have not been prepared in accordance with United States Generally Accepted Accounting Principles ('U.S. GAAP'). These financial measures include Adjusted EBITDA and Free Cash Flow. Non-GAAP financial measures are used to supplement the financial information presented on a U.S. GAAP basis and should not be considered in isolation or as a substitute for the relevant U.S. GAAP measures and should be read in conjunction with information presented on a U.S. GAAP basis. Because not all companies use identical calculations, our presentation of Non-GAAP measures may not be comparable to other similarly titled measures of other companies. We encourage investors and stockholders to review our financial statements and publicly-filed reports in their entirety and not to rely on any single financial measure. Adjusted EBITDA is defined as net income (loss) adjusted for interest expense, net, income tax expense (benefit), depreciation and amortization, impairment expense, transaction expenses, acquisition integration costs, acquisition earnout costs, purchase accounting fair value adjustment related to deferred revenue and inventory, severance costs, capital market and advisory fees, litigation-related expenses, write-off of long-lived assets, equity-based compensation, committed equity facility transaction costs, debt financing costs, gains on sale of joint ventures, net of costs incurred, and warrant liability change in fair value adjustments. Free Cash Flow is computed as net cash provided by (used in) operating activities less capital expenditures. We use Adjusted EBITDA to evaluate our operating performance, generate future operating plans, and make strategic decisions, including those relating to operating expenses and the allocation of internal resources. We use Free Cash Flow as an indicator of liquidity to evaluate our period-over-period operating cash generation that will be used to service our debt, and can be used to invest in future growth through new business development activities and/or acquisitions, among other uses. Free Cash Flow does not represent the total increase or decrease in our cash balance, and it should not be inferred that the entire amount of Free Cash Flow is available for discretionary expenditures, since we have mandatory debt service requirements and other non-discretionary expenditures that are not deducted from this measure. Key Performance Indicators Management uses Key Performance Indicators ('KPIs') to assess the financial performance of the Company, monitor relevant trends and support financial, operational and strategic decision-making. Management frequently monitors and evaluates KPIs against internal targets, core business objectives as well as industry peers and may, on occasion, change the mix or calculation of KPIs to better align with the business, its operating environment, standard industry metrics or other considerations. If the Company changes the method by which it calculates or presents a KPI, prior period disclosures are recast to conform to current presentation. June 30, 2025 December 31, 2024 Current assets: Cash, cash equivalents and restricted cash $ 78,559 $ 49,071 Accounts receivable, net 36,811 21,905 Contract assets 51,044 43,044 Inventory, net 58,835 2,239 Prepaid expenses and other current assets 19,273 9,666 Total current assets 244,522 125,925 Property, plant and equipment, net of accumulated depreciation of $12,615 and $9,628 47,511 17,837 Right-of-use assets 30,248 15,277 Intangible assets, net of accumulated amortization of $32,195 and $25,920 396,130 61,788 Goodwill 789,254 71,161 Other non-current assets 521 629 Total assets $ 1,508,186 $ 292,617 Liabilities, Convertible Preferred Stock and Equity (Deficit) Current liabilities: Accounts payable $ 38,885 $ 32,127 Notes payable to sellers 7,171 — Short-term debt, including current portion of long-term debt 5,280 1,266 Short-term operating lease liabilities 4,573 4,354 Short-term finance lease liabilities 540 473 Accrued expenses 33,380 24,192 Deferred revenue 65,343 67,201 Other current liabilities 12,257 19,730 Total current liabilities 167,429 149,343 Long-term debt, net 185,464 124,464 Long-term operating lease liabilities 28,320 13,444 Long-term finance lease liabilities 1,068 980 Warrant liabilities 23,014 55,285 Deferred tax liabilities 40,800 582 Other non-current liabilities 2,606 428 Total liabilities $ 448,701 $ 344,526 Convertible preferred stock, $0.0001 par value, 125,292.00 shares authorized; issued and outstanding: 2025—103,855.14 and 2024—108,649.30. Liquidation preference: 2025—$567,255 and 2024—$599,412 $ 151,893 $ 136,805 Shareholders' Equity (Deficit): Preferred stock, $0.0001 par value, 99,874,708 shares authorized; none issued and outstanding — — Common stock, $0.0001 par value, 500,000,000 shares authorized; issued and outstanding 2025—142,575,692 and 2024—67,002,370 14 7 Treasury stock, 2025—729,295 shares and 2024—728,739 shares, at cost (3,581 ) (3,573 ) Additional paid-in capital 1,392,204 161,619 Accumulated deficit (493,393 ) (348,106 ) Accumulated other comprehensive income (loss) 12,348 1,339 Total shareholders' equity (deficit) 907,592 (188,714 ) Total liabilities, convertible preferred stock and equity (deficit) $ 1,508,186 $ 292,617 REDWIRE CORPORATION Unaudited (In thousands of U.S. dollars, except share and per share data) Three Months Ended Six Months Ended June 30, 2025 June 30, 2024 June 30, 2025 June 30, 2024 Revenues $ 61,760 $ 78,111 $ 123,155 $ 165,903 Cost of sales 80,824 65,127 133,178 138,094 Gross profit (19,064 ) 12,984 (10,023 ) 27,809 Operating expenses: Selling, general and administrative expenses 54,464 18,088 73,210 35,450 Transaction expenses 16,643 278 20,442 278 Research and development 1,720 1,748 2,533 2,788 Operating income (loss) (91,891 ) (7,130 ) (106,208 ) (10,707 ) Interest expense, net 23,755 3,009 27,349 5,927 Other (income) expense, net 13,937 7,933 (844 ) 9,425 Income (loss) before income taxes (129,583 ) (18,072 ) (132,713 ) (26,059 ) Income tax expense (benefit) (32,604 ) 15 (32,786 ) 124 Net income (loss) (96,979 ) (18,087 ) (99,927 ) (26,183 ) Net income (loss) attributable to noncontrolling interests — 5 — 4 Net income (loss) attributable to Redwire Corporation (96,979 ) (18,092 ) (99,927 ) (26,187 ) Less: dividends on Convertible Preferred Stock 29,739 9,699 33,179 12,742 Net income (loss) available to common shareholders $ (126,718 ) $ (27,791 ) $ (133,106 ) $ (38,929 ) Net income (loss) per common share: Basic and diluted $ (1.41 ) $ (0.42 ) $ (1.66 ) $ (0.59 ) Weighted-average shares outstanding: Basic and diluted 89,554,940 65,701,704 80,424,270 65,636,995 Comprehensive income (loss): Net income (loss) attributable to Redwire Corporation $ (96,979 ) $ (18,092 ) $ (99,927 ) $ (26,187 ) Foreign currency translation gain (loss), net of tax 10,174 (78 ) 11,009 (750 ) Total other comprehensive income (loss), net of tax 10,174 (78 ) 11,009 (750 ) Total comprehensive income (loss) $ (86,805 ) $ (18,170 ) $ (88,918 ) $ (26,937 ) REDWIRE CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS Unaudited (In thousands of U.S. dollars) Six Months Ended June 30, 2025 June 30, 2024 Cash flows from operating activities: Net income (loss) $ (99,927 ) $ (26,183 ) Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: Depreciation and amortization expense 8,106 5,678 Amortization of debt issuance costs and discount 642 349 Equity-based compensation expense 35,598 4,453 (Gain) loss on sale of joint ventures — (1,303 ) (Gain) loss on change in fair value of warrants 2,692 10,052 Deferred provision (benefit) for income taxes (32,069 ) 112 Non-cash lease (benefit) expense (266 ) 22 Other (3,411 ) 690 Changes in assets and liabilities: (Increase) decrease in accounts receivable (3,468 ) 9,987 (Increase) decrease in contract assets (5,724 ) (6,449 ) (Increase) decrease in inventory 1,449 (314 ) (Increase) decrease in prepaid expenses and other assets (3,024 ) 274 Increase (decrease) in accounts payable and accrued expenses (5,586 ) 4,838 Increase (decrease) in deferred revenue (28,433 ) (8,497 ) Increase (decrease) in operating lease liabilities (55 ) (169 ) Increase (decrease) in other liabilities 732 (282 ) Net cash provided by (used in) operating activities (132,744 ) (6,742 ) Cash flows from investing activities: Acquisition of businesses, net of cash acquired (151,791 ) — Net proceeds from sale of joint ventures — 4,598 Purchases of property, plant and equipment (4,752 ) (2,475 ) Purchase of intangible assets (5,186 ) (1,579 ) Net cash provided by (used in) investing activities (161,729 ) 544 Cash flows from financing activities: Proceeds received from debt 190,327 15,000 Repayments of debt (125,876 ) (7,988 ) Payment of debt issuance fees (105 ) (322 ) Repayment of finance leases (227 ) (235 ) Repayments of third-party advances (7,820 ) — Proceeds from issuance of common stock 328,684 530 Shares repurchased for settlement of employee tax withholdings on share-based awards (8 ) (56 ) Repurchase of convertible preferred stock (61,486 ) — Net cash provided by (used in) financing activities 323,489 6,929 Effect of foreign currency rate changes on cash, cash equivalents and restricted cash 472 (177 ) Net increase (decrease) in cash, cash equivalents and restricted cash 29,488 554 Cash, cash equivalents and restricted cash at beginning of period 49,071 30,278 Cash, cash equivalents and restricted cash at end of period $ 78,559 $ 30,832 REDWIRE CORPORATION Supplemental Non-GAAP Information Unaudited Adjusted EBITDA During the third quarter of 2024, we changed the Supplemental Non-GAAP Information to present only Adjusted EBITDA, whereas prior period disclosures also presented Pro Forma Adjusted EBITDA. Management believes the presentation of Pro Forma Adjusted EBITDA no longer provides the same meaningful insights into the Company's performance as it did during the initial years of the Company's formation. Prior period disclosures were recast to conform to current presentation. There was no change in the calculation of Adjusted EBITDA. The following table presents the reconciliations of Adjusted EBITDA to net income (loss), computed in accordance with U.S. GAAP. Three Months Ended Six Months Ended (in thousands) June 30, 2025 June 30, 2024 June 30, 2025 June 30, 2024 Net income (loss) $ (96,979 ) $ (18,087 ) $ (99,927 ) $ (26,183 ) Interest expense, net 23,755 3,009 27,349 5,927 Income tax expense (benefit) (32,604 ) 15 (32,786 ) 124 Depreciation and amortization 5,060 2,925 8,106 5,678 Transaction expenses (i) 16,643 278 20,442 278 Acquisition integration costs (i) 457 — 457 — Purchase accounting fair value adjustment related to inventory (ii) 2,418 — 2,418 — Severance costs (iii) 1,999 159 2,176 167 Capital market and advisory fees (iv) 2,740 2,154 3,708 4,432 Litigation-related expenses (v) — 1,532 — 2,233 Equity-based compensation (vi) 32,686 1,918 35,598 4,453 Debt financing costs (vii) 105 — 105 — Gain on sale of joint ventures, net of costs incurred (viii) — (1,255 ) — (1,255 ) Warrant liability change in fair value adjustment (ix) 16,326 8,977 2,692 10,052 Adjusted EBITDA $ (27,394 ) $ 1,625 $ (29,662 ) $ 5,906 i. Redwire incurred acquisition costs including due diligence, integration costs and additional expenses related to pre-acquisition activity. Acquisition deal costs was reclassified as Transaction expenses to conform with current period presentation. ii. Redwire incurred adjustments to depreciate the purchase accounting fair value of inventory for Edge Autonomy. iii. Redwire incurred severance costs related to separation agreements entered into with former employees. iv. Redwire incurred capital market and advisory fees related to advisors assisting with transitional activities associated with becoming a public company, such as implementation of internal controls over financial reporting, and the internalization of corporate services, including, but not limited to, implementing enhanced enterprise resource planning systems. v. Redwire incurred expenses related to securities litigation. vi. Redwire incurred expenses related to equity-based compensation under Redwire's equity-based compensation plan and Edge Autonomy's incentive units. vii. Redwire incurred expenses related to debt financing agreements, including amendment related fees paid to third parties that are expensed in accordance with U.S. GAAP. viii. Redwire recognized a gain related to the sale of all its ownership in two joint ventures during 2024, presented net of transaction costs incurred. ix. Redwire adjusted the private warrant liability to reflect changes in fair value recognized as a gain or loss during the respective periods. Free Cash Flow The following table presents the reconciliation of Free Cash Flow to Net cash provided by (used in) operating activities, computed in accordance with U.S. GAAP. REDWIRE CORPORATION KEY PERFORMANCE INDICATORS Unaudited Book-to-Bill Our book-to-bill ratio was as follows for the periods presented: Three Months Ended Last Twelve Months (in thousands, except ratio) June 30, 2025 June 30, 2024 June 30, 2025 June 30, 2024 Contracts awarded $ 90,563 $ 114,437 $ 227,058 $ 374,269 Revenues 61,760 78,111 261,353 292,000 Book-to-bill ratio 1.47 1.47 0.87 1.28 Book-to-bill is the ratio of total contracts awarded to revenues recorded in the same period. The contracts awarded balance includes firm contract orders, including time-and-material contracts, awarded during the period and does not include unexercised contract options or potential orders under indefinite delivery/indefinite quantity contracts. Although the contracts awarded balance reflects firm contract orders, terminations, amendments, or contract cancellations may occur which could result in a reduction to the contracts awarded balance. We view book-to-bill as an indicator of future revenue growth potential. To drive future revenue growth, our goal is for the level of contracts awarded in a given period to exceed the revenue recorded, thus yielding a book-to-bill ratio greater than 1.0. Our book-to-bill ratio was 1.47 for the three months ended June 30, 2025, as compared to 1.47 for the three months ended June 30, 2024. For the three months ended June 30, 2025, $73.7 million of the contracts awarded balance relates to the Edge Autonomy acquisition and none of the contracts awarded balance relates to acquired contract value for the three months ended June 30, 2024. Our book-to-bill ratio was 0.87 for the Last Twelve Months ('LTM') ended June 30, 2025, as compared to 1.28 for the LTM ended June 30, 2024. For the LTM ended June 30, 2025, contracts awarded includes $95.7 million of acquired contract value from Edge Autonomy and Hera Systems acquisitions, which were completed in the second quarter of 2025 and third quarter of 2024, respectively. For the LTM ended June 30, 2024, none of the contracts awarded balance relates to acquired contract value. Backlog The following table presents our contracted backlog as of June 30, 2025 and December 31, 2024, and related activity for the six months ended June 30, 2025 as compared to the year ended December 31, 2024. (in thousands) June 30, 2025 December 31, 2024 Organic backlog, beginning balance $ 280,969 $ 372,790 Organic additions during the period 71,591 207,704 Organic revenue recognized during the period (106,334 ) (297,699 ) Foreign currency translation 8,844 (1,826 ) Organic backlog, ending balance 255,070 280,969 Acquisition-related contract value, beginning balance 15,683 — Acquisition-related contract value acquired during the period 73,716 21,940 Acquisition-related additions during the period 1,500 145 Acquisition-related revenue recognized during the period (16,821 ) (6,402 ) Foreign currency translation 335 — Acquisition-related backlog, ending balance 74,413 15,683 Contracted backlog, ending balance $ 329,483 $ 296,652 We view growth in backlog as a key measure of our business growth. Contracted backlog represents the estimated dollar value of firm funded executed contracts for which work has not been performed (also known as the remaining performance obligations on a contract). Our contracted backlog includes $86.9 million and $16.7 million in remaining contract value from contracts which recognize revenue at a point in time as of June 30, 2025 and as of December 31, 2024, respectively. Organic backlog change excludes backlog activity from acquisitions for the first four full quarters since the entities' acquisition date. Contracted backlog activity for the first four full quarters since the entities' acquisition date is included in acquisition-related contracted backlog change. After the completion of four fiscal quarters, acquired entities are treated as organic for current and comparable historical periods. Organic contract value includes the remaining contract value as of January 1 not yet recognized as revenue and additional orders awarded during the period for those entities treated as organic. Acquisition-related contract value includes remaining contract value as of the acquisition date not yet recognized as revenue and additional orders awarded during the period for entities not treated as organic. Organic revenue includes revenue earned during the period presented for those entities treated as organic, while acquisition-related revenue includes the same for all other entities, excluding any pre-acquisition revenue earned during the period. The acquisition-related backlog activity presented in the table above is related to the Edge Autonomy and Hera Systems acquisitions completed during the second quarter of 2025 and third quarter of 2024, respectively. Although contracted backlog reflects business associated with contracts that are considered to be firm, terminations, amendments or contract cancellations may occur, which could result in a reduction in our total backlog. In addition, some of our multi-year contracts are subject to annual funding. Management expects all amounts reflected in contracted backlog to ultimately be fully funded. Contracted backlog from foreign operations in Luxembourg and Belgium was $117.4 million and $70.5 million as of June 30, 2025 and December 31, 2024, respectively. These amounts are subject to foreign exchange rate translations from euros to U.S. dollars that could cause the remaining backlog balance to fluctuate with the foreign exchange rate at the time of measurement.


Globe and Mail
6 minutes ago
- Globe and Mail
Vital Energy Reports Second-Quarter 2025 Financial and Operating Results
TULSA, OK, Aug. 06, 2025 (GLOBE NEWSWIRE) -- Vital Energy, Inc. (NYSE: VTLE) ("Vital Energy" or the "Company") today reported second-quarter 2025 financial and operating results. Supplemental slides have been posted to the Company's website and can be found at A conference call is planned for 7:30 a.m. CT, Thursday, August 7, 2025. A webcast will be available through the Company's website. Second-Quarter 2025 Highlights Reported a net loss of $582.6 million, Adjusted Net Income 1 of $76.1 million and cash flow from operating activities of $252.3 million Generated Consolidated EBITDAX 1 of $338.1 million and Adjusted Free Cash Flow 1 of $36.1 million Reported capital investments of $257.0 million, excluding non-budgeted acquisitions and leasehold expenditures, above guidance of $215-$245 million Reported lease operating expense ("LOE") of $107.8 million, below guidance of $112-$118 million Reported total general and administrative expenses ("G&A") of $23.8 million, below guidance of $24.6-$26.7 million Produced 137.9 thousand barrels of oil equivalent per day ("MBOE/d") and oil of 62.1 thousand barrels of oil per day ("MBO/d"), within guidance of 133.0-139.0 MBOE/d and 61.0-65.0 MBO/d, respectively Commenced production from the Company's first two J-Hook wells On schedule to TIL all 38 second-half 2025 wells by early October Divested 3,800 net non-core acres in Crane and Upton counties, Texas, for $6.5 million in July 2025, with proceeds allocated to debt reduction 1 Non-GAAP financial measure; please see supplemental reconciliations of GAAP to non-GAAP financial measures at the end of this release. "Our second quarter results demonstrate our ongoing efforts to lower costs and optimize our assets, with the ultimate goal of enhancing returns," stated Jason Pigott, President and CEO. "We have made substantial progress to sustainably reduce operating, personnel and corporate costs as we streamline our business and strengthen our balance sheet. Additionally, we continue to lead the industry in the application of optimized well designs, completing our first J-Hook wells and commencing drilling on a section to be fully developed with 12 horseshoe wells. We remain committed to the capital and cost discipline that will allow us to generate sustainable Adjusted Free Cash Flow from our high-quality asset base." Second-Quarter 2025 Financial and Operations Summary Financial Results. The Company had a net loss of $582.6 million, or $(15.43) per diluted share. Results were impacted by a non-cash pre-tax impairment loss on oil and gas properties of $427.0 million and a valuation allowance against the Company's federal net deferred tax asset of $237.9 million. Adjusted Net Income was $76.1 million, or $2.02 per adjusted diluted share. Cash flows from operating activities were $252.3 million and Consolidated EBITDAX was $338.1 million. The impairment was related to the full cost ceiling limitation, driven primarily by the decline in the trailing 12-month SEC mandated oil price calculation, and excludes the value of the Company's commodity derivative positions and only includes the 171 proved undeveloped locations in the Company's current proved reserves out of approximately 920 inventory locations at the beginning of the year, net of divestitures. Additionally, as a result of the full cost ceiling impairment and the expectation of future impairments, a valuation allowance against the Company's net deferred tax asset was recorded. Production. Vital Energy's total and oil production averaged 137,864 BOE/d and 62,140 BO/d, respectively. Weather and temporary curtailments related to the installation of additional production equipment negatively impacted average daily production by 780 BOE/d, 500 BO/d of which was oil. Capital Investments. Total capital investments, excluding non-budgeted acquisitions and leasehold expenditures, were $257 million, including approximately $13 million related to drilling cost overruns and $11 million to accelerate development activity into the second quarter. Second quarter investments included $216 million in drilling and completions, $27 million in infrastructure investments, $8 million in other capitalized costs and $6 million in land, exploration and data-related costs. Operating Expenses. LOE was 6% lower than the midpoint of guidance at $107.8 million, driven by lower than expected costs on the recently acquired Point Energy assets and ongoing cost optimization across the Midland and Delaware basins that reduced field power generation and chemicals costs. G&A Expenses. Total G&A expenses were 7% below the midpoint of guidance at $23.8 million as the Company continued to reduce employee and professional costs. Adjusted Free Cash Flow and Net Debt. Adjusted Free Cash Flow was $36 million, with sustainable expense reductions largely offsetting drilling outspend. Net Debt 1 increased by $8 million during the quarter as the Company's net changes in operating assets and liabilities decreased by $41 million. Liquidity. At June 30, 2025, the Company had $745 million outstanding on its $1.4 billion senior secured credit facility and cash and cash equivalents of $30 million. 1 Non-GAAP financial measure; please see supplemental reconciliations of GAAP to non-GAAP financial measures at the end of this release. 2025 Outlook Production. Planned completion of 38 wells in late third quarter/early fourth quarter is expected to meaningfully increase production volumes. Total and oil production ranges for full-year 2025 were narrowed to account for actual second-quarter 2025 volumes and are expected to be 136.5-139.5 MBOE/d and 63.3-65.3 MBO/d, respectively. Capital Investments. Vital Energy reduced expectations for third quarter investments by $25 million to $235-$265 million, in part reflecting the acceleration of capital into the second quarter. Guidance for the fourth quarter is unchanged. Full-year 2025 capital expectations were narrowed to $850-$900 million. Operating Expenses. The Company expects recent improvements in operating expenses to be sustainable. Third quarter LOE is expected to be $109-$115 million and decline to $107-$113 million in the fourth quarter of 2025. G&A Expenses. In June, Vital Energy reduced its combined employee and contractor headcount by approximately 10%, resulting in sustainably lower G&A expense. Total G&A for both the third and fourth quarters of 2025 is expected to decline approximately 12% from second-quarter 2025 to a range of $20.0-$22.0 million. Non-core Divestitures. In July 2025, Vital Energy closed on the sale of approximately 3,800 net acres in Crane and Upton counties for $6.5 million. The sale included five of the Company's inventory locations in the Barnett formation with no impact to production. Year-to-date, Vital Energy has closed on non-core asset sales totaling $27 million. Adjusted Free Cash Flow and Net Debt. For full-year 2025, the Company expects to generate approximately $305 million of Adjusted Free Cash Flow at current oil prices of ~$67 per barrel WTI, inclusive of hedging proceeds, and reduce Net Debt by approximately $310 million. The estimated Net Debt reduction includes proceeds from non-core asset sales and increases in debt from working capital changes and organizational restructuring expenses. Through the first half of 2025, Vital Energy reduced Net Debt by $125 million. The Company expects to reduce Net Debt by approximately $25 million in the third quarter of 2025 and approximately $160 million in the fourth quarter. Third-Quarter 2025 Guidance The table below reflects the Company's guidance for production and capital investments. 3Q-25E Total production (MBOE/d) 128.0 - 134.0 Oil production (MBO/d) 58.0 - 62.0 Capital investments, excluding non-budgeted acquisitions ($ MM) $235 - $265 The table below reflects the Company's guidance for select revenue and expense items. 3Q-25E Average sales price realizations (excluding derivatives): Oil (% of WTI) 101% NGL (% of WTI) 21% Natural gas (% of Henry Hub) 23% Net settlements received (paid) for matured commodity derivatives ($ MM): Oil $11 NGL $5 Natural gas $20 Selected average costs & expenses: Lease operating expenses ($ MM) $109 - $115 Production and ad valorem taxes (% of oil, NGL and natural gas sales revenues) 6.40% Oil transportation and marketing expenses ($ MM) $10.7 - $11.7 Gas gathering, processing and transportation expenses ($ MM) $5.5 - $6.5 General and administrative expenses (excluding LTIP and transaction expenses, $ MM) $16.9 - $18.4 General and administrative expenses (LTIP cash, $ MM) $0.4 - $0.5 General and administrative expenses (LTIP non-cash, $ MM) $2.7 - $3.1 Depletion, depreciation and amortization ($ MM) $168 - $178 Conference Call Details Vital Energy plans to host a conference call at 7:30 a.m. CT on Thursday, August 7, 2025, to discuss its second-quarter 2025 financial and operating results. Supplemental slides will be posted to the Company's website. Interested parties are invited to listen to the call via the Company's website at under the tab for "Investor Relations | News & Presentations | Upcoming Events." About Vital Energy Vital Energy, Inc. is an independent energy company with headquarters in Tulsa, Oklahoma. Vital Energy's business strategy is focused on the acquisition, exploration and development of oil and natural gas properties in the Permian Basin of West Texas. Additional information about Vital Energy may be found on its website at Forward-Looking Statements This press release and any oral statements made regarding the contents of this release, including in the conference call referenced herein, contain forward-looking statements as defined under 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, that address activities that Vital Energy assumes, plans, expects, believes, intends, projects, indicates, enables, transforms, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements are based on management's current belief, based on currently available information, as to the outcome and timing of future events. Such statements are not guarantees of future performance and involve risks, assumptions and uncertainties. General risks relating to Vital Energy include, but are not limited to: the volatility of oil, NGL and natural gas prices, including the Company's area of operation in the Permian Basin; changes, uncertainty and instability in domestic and global production, supply and demand for oil, NGL and natural gas, and actions by the Organization of the Petroleum Exporting Countries members and other oil exporting nations ("OPEC+"); changes in general economic, business or industry conditions and market volatility, including as a result of slowing growth, inflationary pressures, monetary policy, tariffs, trade barriers, price and exchange controls and other regulatory requirements, including such changes that may be implemented by the United States ("U.S.") and foreign governments; the Company's ability to execute its strategies, including its ability to successfully identify and consummate strategic acquisitions at purchase prices that are accretive to its financial results and to successfully integrate acquired businesses, assets and properties; the Company's ability to optimize spacing, drilling and completions techniques in order to maximize its rate of return, cash flows from operations and stockholder value; the ongoing instability and uncertainty in the U.S. and international energy, financial and consumer markets that could adversely affect the liquidity available to the Company and its customers and the demand for commodities, including oil, NGL and natural gas; competition in the oil and gas industry; the Company's ability to discover, estimate, develop and replace oil, NGL and natural gas reserves and inventory; insufficient transportation capacity in the Permian Basin and challenges associated with such constraint, and the availability and costs of sufficient gathering, processing, storage and export capacity; a decrease in production levels which may impair the Company's ability to meet its contractual obligations and ability to retain its leases; risks associated with the uncertainty of potential drilling locations and plans to drill in the future; the inability of significant customers to meet their obligations; revisions to the Company's reserve estimates as a result of changes in commodity prices, decline curves and other uncertainties; the availability and costs of drilling and production equipment, supplies, labor and oil and natural gas processing and other services; ongoing war and political instability in Ukraine, Israel and the Middle East and the effects of such conflicts on the global hydrocarbon market and supply chains; risks related to the geographic concentration of the Company's assets; the Company's ability to hedge commercial risk, including commodity price volatility, and regulations that affect the Company's ability to hedge such risks; the Company's ability to continue to maintain the borrowing capacity under its Senior Secured Credit Facility or access other means of obtaining capital and liquidity, especially during periods of sustained low commodity prices; the Company's ability to comply with restrictions contained in its debt agreements, including its Senior Secured Credit Facility and the indentures governing its senior unsecured notes, as well as debt that could be incurred in the future; the Company's ability to generate sufficient cash to service its indebtedness, fund its capital requirements and generate future profits; drilling and operating risks, including but not limited to, risks related to hydraulic fracturing, securing sufficient electricity to produce its wells without limitation, natural disasters and other matters beyond the Company's control; U.S. and international economic conditions and legal, tax, political and administrative developments, including the effects of energy, trade and environmental policies and existing and future laws and government regulations; the Company's ability to comply with federal, state and local regulatory requirements, including the One Big Beautiful Bill Act (the "OBBB Act") and any impact thereon by the OBBB Act taxes, tariffs and international trade; the impact of repurchases, if any, of securities from time to time; the Company's ability to maintain the health and safety of, as well as recruit and retain, qualified personnel, including senior management or other key personnel, necessary to operate its business; evolving cybersecurity risks such as those involving unauthorized access, denial-of-service attacks, third-party service provider failures, malicious software, data privacy breaches by employees, insiders or others with authorized access, cyber or phishing attacks, ransomware, social engineering, physical breaches or other actions; and the Company's belief that the outcome of any current legal proceedings will not materially affect its financial results and operations, and other factors, including those and other risks described in its Annual Report on Form 10-K for the year ended December 31, 2024 (the "2024 Annual Report"), subsequent Quarterly Reports on Form 10-Q and those set forth from time to time in other filings with the Securities and Exchange Commission ("SEC"). These documents are available through Vital Energy's website at under the tab "Investor Relations" or through the SEC's Electronic Data Gathering and Analysis Retrieval System at Any of these factors could cause Vital Energy's actual results and plans to differ materially from those in the forward-looking statements. Therefore, Vital Energy can give no assurance that its future results will be as estimated. Any forward-looking statement speaks only as of the date on which such statement is made. Vital Energy does not intend to, and disclaims any obligation to, correct, update or revise any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. This press release and any accompanying disclosures include financial measures that are not in accordance with generally accepted accounting principles ("GAAP"), such as Adjusted Free Cash Flow, Adjusted Net Income, Net Debt and Consolidated EBITDAX. While management believes that such measures are useful for investors, they should not be used as a replacement for financial measures that are in accordance with GAAP. For a reconciliation of such non-GAAP financial measures to the nearest comparable measure in accordance with GAAP, please see the supplemental financial information at the end of this press release. Unless otherwise specified, references to "average sales price" refer to average sales price excluding the effects of the Company's derivative transactions. All amounts, dollars and percentages presented in this press release are rounded and therefore approximate. Vital Energy, Inc. Selected operating data Three months ended June 30, Six months ended June 30, 2025 2024 2025 2024 (unaudited) (unaudited) Sales volumes: Oil (MBbl) 5,655 5,388 11,495 10,715 NGL (MBbl) 3,573 3,173 7,057 6,107 Natural gas (MMcf) 19,908 19,264 39,650 37,798 Oil equivalent (MBOE) (1) 12,546 11,771 25,160 23,121 Average daily oil equivalent sales volumes (BOE/d) (1) 137,864 129,356 139,005 127,038 Average daily oil sales volumes (Bbl/d) (1) 62,140 59,209 63,509 58,872 Average sales prices (1): Oil ($/Bbl) (2) $ 64.65 $ 81.97 $ 68.55 $ 80.03 NGL ($/Bbl) (2) $ 14.29 $ 12.57 $ 15.98 $ 14.24 Natural gas ($/Mcf) (2) $ 0.53 $ (0.28) $ 0.96 $ 0.34 Average sales price ($/BOE) (2) $ 34.06 $ 40.45 $ 37.31 $ 41.40 Oil, with commodity derivatives ($/Bbl) (3) $ 74.12 $ 76.90 $ 74.96 $ 75.93 NGL, with commodity derivatives ($/Bbl) (3) $ 14.93 $ 12.33 $ 16.00 $ 14.05 Natural gas, with commodity derivatives ($/Mcf) (3) $ 1.73 $ 0.70 $ 1.62 $ 1.05 Average sales price, with commodity derivatives ($/BOE) (3) $ 40.40 $ 39.66 $ 41.29 $ 40.61 Selected average costs and expenses per BOE sold (1): Lease operating expenses $ 8.59 $ 9.66 $ 8.40 $ 9.49 Production and ad valorem taxes 2.10 2.30 2.37 2.50 Oil transportation and marketing expenses 0.85 1.04 0.83 0.95 Gas gathering, processing and transportation expenses 0.43 0.43 0.48 0.32 General and administrative (excluding LTIP and transaction expenses) 1.68 1.67 1.62 1.89 Total selected operating expenses $ 13.65 $ 15.10 $ 13.70 $ 15.15 General and administrative (LTIP): LTIP cash $ (0.01) $ 0.03 $ (0.01) $ 0.10 LTIP non-cash $ 0.23 $ 0.30 $ 0.24 $ 0.29 Depletion, depreciation and amortization $ 14.86 $ 14.81 $ 14.96 $ 14.72 _______________________________________________________________________________ (1) The numbers presented are calculated based on actual amounts and may not recalculate using the rounded numbers presented in the table above. (2) Price reflects the average of actual sales prices received when control passes to the purchaser/customer adjusted for quality, certain transportation fees, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the delivery point. (3) Price reflects the after-effects of the Company's commodity derivative transactions on its average sales prices. The Company's calculation of such after-effects includes settlements of matured commodity derivatives during the respective periods. Vital Energy, Inc. Consolidated balance sheets (in thousands, except share data) June 30, 2025 December 31, 2024 (unaudited) Assets Current assets: Cash and cash equivalents $ 30,194 $ 40,179 Accounts receivable, net 242,956 299,698 Derivatives 129,444 101,474 Other current assets 27,836 25,205 Total current assets 430,430 466,556 Property and equipment: Oil and natural gas properties, full cost method: Evaluated properties 14,136,321 13,587,040 Unevaluated properties not being depleted 176,117 242,792 Less: accumulated depletion and impairment (9,915,495) (8,966,200) Oil and natural gas properties, net 4,396,943 4,863,632 Midstream and other fixed assets, net 122,022 134,265 Property and equipment, net 4,518,965 4,997,897 Derivatives 33,165 34,564 Operating lease right-of-use assets 82,049 104,329 Deferred income taxes 3,396 239,685 Other noncurrent assets, net 32,446 35,915 Total assets $ 5,100,451 $ 5,878,946 Liabilities and stockholders' equity Current liabilities: Accounts payable and accrued liabilities $ 158,125 $ 185,115 Accrued capital expenditures 109,844 95,593 Undistributed revenue and royalties 172,415 187,563 Operating lease liabilities 45,778 73,143 Other current liabilities 59,341 59,725 Total current liabilities 545,503 601,139 Long-term debt, net 2,321,294 2,454,242 Derivatives 19,466 5,814 Asset retirement obligations 75,620 82,941 Operating lease liabilities 27,941 26,733 Other noncurrent liabilities 5,049 7,506 Total liabilities 2,994,873 3,178,375 Commitments and contingencies Stockholders' equity: Preferred stock, $0.01 par value, 50,000,000 shares authorized and zero issued and outstanding as of June 30, 2025 and December 31, 2024 — — Common stock, $0.01 par value, 80,000,000 shares authorized, and 38,687,645 and 38,144,248 issued and outstanding as of June 30, 2025 and December 31, 2024, respectively 387 381 Additional paid-in capital 3,829,651 3,823,241 Accumulated deficit (1,724,460) (1,123,051) Total stockholders' equity 2,105,578 2,700,571 Total liabilities and stockholders' equity $ 5,100,451 $ 5,878,946 Vital Energy, Inc. Consolidated statements of operations Three months ended June 30, Six months ended June 30, (in thousands, except per share data) 2025 2024 2025 2024 (unaudited) (unaudited) Revenues: Oil sales $ 365,605 $ 441,667 $ 787,937 $ 857,451 NGL sales 51,046 39,870 112,785 86,945 Natural gas sales 10,631 (5,371) 37,969 12,874 Other operating revenues 2,345 205 3,116 1,440 Total revenues 429,627 476,371 941,807 958,710 Costs and expenses: Lease operating expenses 107,750 113,742 211,235 219,470 Production and ad valorem taxes 26,356 27,079 59,581 57,693 Oil transportation and marketing expenses 10,649 12,199 20,769 22,032 Gas gathering, processing and transportation expenses 5,380 5,088 12,136 7,464 General and administrative 23,791 23,573 46,471 52,929 Organizational restructuring expenses 4,627 — 4,627 — Depletion, depreciation and amortization 186,424 174,298 376,324 340,405 Impairment expense 427,046 — 585,287 — Other operating expenses, net 2,263 2,593 4,176 3,611 Total costs and expenses 794,286 358,572 1,320,606 703,604 Gain (loss) on disposal of assets, net 1,255 36 1,365 166 Operating income (loss) (363,404) 117,835 (377,434) 255,272 Non-operating income (expense): Gain (loss) on derivatives, net 68,993 7,658 113,164 (144,489) Interest expense (49,854) (40,690) (100,234) (84,111) Loss on extinguishment of debt, net — (40,301) — (66,115) Other income (expense), net 863 2,609 1,216 4,674 Total non-operating income (expense), net 20,002 (70,724) 14,146 (290,041) Income (loss) before income taxes (343,402) 47,111 (363,288) (34,769) Income tax benefit (expense) (239,170) (10,409) (238,121) 5,340 Net income (loss) (582,572) 36,702 (601,409) (29,429) Preferred stock dividends — (303) — (652) Net income (loss) available to common stockholders $ (582,572) $ 36,399 $ (601,409) $ (30,081) Net income (loss) per common share: Basic $ (15.43) $ 1.00 $ (15.97) $ (0.84) Diluted $ (15.43) $ 0.98 $ (15.97) $ (0.84) Weighted-average common shares outstanding: Basic 37,761 36,381 37,670 35,973 Diluted 37,761 37,605 37,670 35,973 Vital Energy, Inc. Three months ended June 30, Six months ended June 30, (in thousands) 2025 2024 2025 2024 (unaudited) (unaudited) Cash flows from operating activities: Net income (loss) $ (582,572) $ 36,702 $ (601,409) $ (29,429) Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: Share-settled equity-based compensation, net 3,233 3,934 6,837 7,435 Depletion, depreciation and amortization 186,424 174,298 376,324 340,405 Impairment expense 427,046 — 585,287 — Mark-to-market on derivatives: (Gain) loss on derivatives, net (68,993) (7,658) (113,164) 144,489 Settlements received (paid) for matured derivatives, net 79,558 (9,262) 100,245 (18,262) Loss on extinguishment of debt, net — 40,301 — 66,115 Deferred income tax (benefit) expense 238,100 9,347 236,289 (7,577) Other, net 10,319 7,027 19,870 12,429 Changes in operating assets and liabilities: Accounts receivable, net 11,387 65,137 56,742 13,662 Other current assets (3,078) (1,961) (3,068) (7,607) Other noncurrent assets, net (675) 1,906 (4,309) 1,549 Accounts payable and accrued liabilities (5,236) (7,803) (26,990) (16,867) Undistributed revenue and royalties (20,760) 29,133 (15,148) 16,268 Other current liabilities (15,081) 964 1,018 (20,383) Other noncurrent liabilities (7,331) (3,664) (15,198) (5,236) Net cash provided by (used in) operating activities 252,341 338,401 603,326 496,991 Cash flows from investing activities: Acquisitions of oil and natural gas properties, net — (299) (1,636) (4,679) Capital expenditures: Oil and natural gas properties (258,929) (222,334) (488,541) (417,706) Midstream and other fixed assets (2,850) (4,093) (4,675) (9,178) Proceeds from dispositions of capital assets, net of selling costs 1,245 55 22,289 180 Other investing activities 1,233 — 1,140 (952) Net cash provided by (used in) investing activities (259,301) (226,671) (471,423) (432,335) Cash flows from financing activities: Borrowings on Senior Secured Credit Facility 215,000 275,000 365,000 405,000 Payments on Senior Secured Credit Facility (205,000) (450,000) (500,000) (450,000) Issuance of senior unsecured notes — 201,500 — 1,001,500 Extinguishment of debt — (498,696) — (952,214) Stock exchanged for tax withholding (33) (9) (3,956) (3,420) Payments for debt issuance costs — (4,564) — (20,285) Other, net (1,462) (1,722) (2,932) (2,734) Net cash provided by (used in) financing activities 8,505 (478,491) (141,888) (22,153) Net increase (decrease) in cash and cash equivalents 1,545 (366,761) (9,985) 42,503 Cash and cash equivalents, beginning of period 28,649 423,325 40,179 14,061 Cash and cash equivalents, end of period $ 30,194 $ 56,564 $ 30,194 $ 56,564 Vital Energy, Inc. Supplemental reconciliations of GAAP to non-GAAP financial measures Non-GAAP financial measures The non-GAAP financial measures of Adjusted Free Cash Flow, Adjusted Net Income, Consolidated EBITDAX, Net Debt and Net Debt to Consolidated EBITDAX, as defined by the Company, may not be comparable to similarly titled measures used by other companies. Furthermore, these non-GAAP financial measures should not be considered in isolation or as a substitute for GAAP measures of liquidity or financial performance, but rather should be considered in conjunction with GAAP measures, such as net income or loss, operating income or loss or cash flows from operating activities. Adjusted Free Cash Flow Adjusted Free Cash Flow is a non-GAAP financial measure that the Company defines as net cash provided by (used in) operating activities (GAAP) before net changes in operating assets and liabilities and transaction expenses related to non-budgeted acquisitions, less capital investments, excluding non-budgeted acquisition costs. Management believes Adjusted Free Cash Flow is useful to management and investors in evaluating operating trends in its business that are affected by production, commodity prices, operating costs and other related factors. There are significant limitations to the use of Adjusted Free Cash Flow as a measure of performance, including the lack of comparability due to the different methods of calculating Adjusted Free Cash Flow reported by different companies. This release also includes certain forward-looking non-GAAP measures. Due to the forward-looking nature of such measures, no reconciliations of these non-GAAP measures to their respective most directly comparable GAAP measure are available without unreasonable efforts. This is due to the inherent difficulty of forecasting the timing or amount of various reconciling items that would impact the most directly comparable forward-looking GAAP financial measure, that have not yet occurred, are out of the Company's control and/or cannot be reasonably predicted. Accordingly, such reconciliations are excluded from this release. Forward-looking non-GAAP financial measures provided without the most directly comparable GAAP financial measures may vary materially from the corresponding GAAP financial measures. The following table presents a reconciliation of net cash provided by (used in) operating activities (GAAP) to Adjusted Free Cash Flow (non-GAAP) for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2025 2024 2025 2024 (unaudited) (unaudited) Net cash provided by (used in) operating activities $ 252,341 $ 338,401 $ 603,326 $ 496,991 Less: Net changes in operating assets and liabilities (40,774) 83,712 (6,953) (18,614) General and administrative (transaction expenses) — (15) — (347) Cash flows from operating activities before net changes in operating assets and liabilities and transaction expenses related to non-budgeted acquisitions 293,115 254,704 610,279 515,952 Less capital investments, excluding non-budgeted acquisition costs: Oil and natural gas properties (1) 254,195 205,521 505,459 418,786 Midstream and other fixed assets (1) 2,830 4,489 4,237 9,124 Total capital investments, excluding non-budgeted acquisition costs 257,025 210,010 509,696 427,910 Adjusted Free Cash Flow (non-GAAP) $ 36,090 $ 44,694 $ 100,583 $ 88,042 (1) Includes capitalized share-settled equity-based compensation and asset retirement costs. Adjusted Net Income Adjusted Net Income is a non-GAAP financial measure that the Company defines as net income or loss (GAAP) plus adjustments for mark-to-market on derivatives, premiums paid or received for commodity derivatives that matured during the period, organizational restructuring expenses, impairment expense, gains or losses on disposal of assets, income taxes, other non-recurring income and expenses and adjusted income tax expense. Management believes Adjusted Net Income helps investors in the oil and natural gas industry to measure and compare the Company's performance to other oil and natural gas companies by excluding from the calculation items that can vary significantly from company to company depending upon accounting methods, the book value of assets and other non-operational factors. The following table presents a reconciliation of net income (loss) (GAAP) to Adjusted Net Income (non-GAAP) for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands, except per share data) 2025 2024 2025 2024 (unaudited) (unaudited) Net income (loss) $ (582,572) $ 36,702 $ (601,409) $ (29,429) Plus: Mark-to-market on derivatives: (Gain) loss on derivatives, net (68,993) (7,658) (113,164) 144,489 Settlements received (paid) for matured derivatives, net 79,558 (9,262) 100,245 (18,262) Organizational restructuring expenses 4,627 — 4,627 — Impairment expense 427,046 — 585,287 — (Gain) loss on disposal of assets, net (1,255) (36) (1,365) (166) Loss on extinguishment of debt, net — 40,301 — 66,115 Income tax (benefit) expense 239,170 10,409 238,121 (5,340) General and administrative (transaction expenses) — 15 — 347 Adjusted income before adjusted income tax expense 97,581 70,471 212,342 157,754 Adjusted income tax expense (1) (21,468) (15,504) (46,715) (34,706) Adjusted Net Income (non-GAAP) $ 76,113 $ 54,967 $ 165,627 $ 123,048 Net income (loss) per common share: Basic $ (15.43) $ 1.00 $ (15.97) $ (0.84) Diluted $ (15.43) $ 0.98 $ (15.97) $ (0.84) Adjusted Net Income per common share: Basic $ 2.02 $ 1.51 $ 4.40 $ 3.42 Diluted $ 2.02 $ 1.46 $ 4.40 $ 3.42 Adjusted diluted $ 2.02 $ 1.46 $ 4.39 $ 3.30 Weighted-average common shares outstanding: Basic 37,761 36,381 37,670 35,973 Diluted 37,761 37,605 37,670 35,973 Adjusted diluted 37,762 37,605 37,749 37,264 (1) Adjusted income tax expense is calculated by applying a statutory tax rate of 22% for each of the periods ended June 30, 2025 and 2024. Consolidated EBITDAX Consolidated EBITDAX is a non-GAAP financial measure defined in the Company's Senior Secured Credit Facility as net income or loss (GAAP) plus adjustments for share-settled equity-based compensation, depletion, depreciation and amortization, impairment expense, organizational restructuring expenses, gains or losses on disposal of assets, mark-to-market on derivatives, accretion expense, interest expense, income taxes and other non-recurring income and expenses. Consolidated EBITDAX provides no information regarding a company's capital structure, borrowings, interest costs, capital expenditures, working capital movement or tax position. Consolidated EBITDAX does not represent funds available for future discretionary use because it excludes funds required for debt service, capital expenditures, working capital, income taxes, franchise taxes and other commitments and obligations. However, management believes Consolidated EBITDAX is useful to an investor because this measure: is used by investors in the oil and natural gas industry to measure a company's operating performance without regard to items that can vary substantially from company to company depending upon accounting methods, the book value of assets, capital structure and the method by which assets were acquired, among other factors; helps investors to more meaningfully evaluate and compare the results of the Company's operations from period to period by removing the effect of the Company's capital structure from the Company's operating structure; and is used by management for various purposes, including (i) as a measure of operating performance, (ii) as a measure of compliance under the Senior Secured Credit Facility, (iii) in presentations to the board of directors and (iv) as a basis for strategic planning and forecasting. There are significant limitations to the use of Consolidated EBITDAX as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect the Company's net income or loss and the lack of comparability of results of operations to different companies due to the different methods of calculating Consolidated EBITDAX, or similarly titled measures, reported by different companies. The Company is subject to financial covenants under the Senior Secured Credit Facility, one of which establishes a maximum permitted ratio of Net Debt, as defined in the Senior Secured Credit Facility, to Consolidated EBITDAX. See Note 7 in the 2024 Annual Report for additional discussion of the financial covenants under the Senior Secured Credit Facility. Additional information on Consolidated EBITDAX can be found in the Company's Eleventh Amendment to the Senior Secured Credit Facility, as filed with the SEC on September 13, 2023. The following table presents a reconciliation of net income (loss) (GAAP) to Consolidated EBITDAX (non-GAAP) for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2025 2024 2025 2024 (unaudited) (unaudited) Net income (loss) $ (582,572) $ 36,702 $ (601,409) $ (29,429) Plus: Share-settled equity-based compensation, net 3,233 3,934 6,837 7,435 Depletion, depreciation and amortization 186,424 174,298 376,324 340,405 Impairment expense 427,046 — 585,287 — Organizational restructuring expenses 4,627 — 4,627 — (Gain) loss on disposal of assets, net (1,255) (36) (1,365) (166) Mark-to-market on derivatives: (Gain) loss on derivatives, net (68,993) (7,658) (113,164) 144,489 Settlements received (paid) for matured derivatives, net 79,558 (9,262) 100,245 (18,262) Accretion expense 977 1,036 2,011 2,056 Interest expense 49,854 40,690 100,234 84,111 Loss extinguishment of debt, net — 40,301 — 66,115 Income tax (benefit) expense 239,170 10,409 238,121 (5,340) General and administrative (transaction expenses) — 15 — 347 Consolidated EBITDAX (non-GAAP) $ 338,069 $ 290,429 $ 697,748 $ 591,761 The following table presents a reconciliation of net cash provided by (used in) operating activities (GAAP) to Consolidated EBITDAX (non-GAAP) for the periods presented: Three months ended June 30, Six months ended June 30, (in thousands) 2025 2024 2025 2024 (unaudited) (unaudited) Net cash provided by (used in) operating activities $ 252,341 $ 338,401 $ 603,326 $ 496,991 Plus: Interest expense 49,854 40,690 100,234 84,111 Organizational restructuring expenses 4,627 — 4,627 — Current income tax (benefit) expense 1,070 1,062 1,832 2,237 Net changes in operating assets and liabilities 40,774 (83,712) 6,953 18,614 General and administrative (transaction expenses) — 15 — 347 Other, net (10,597) (6,027) (19,224) (10,539) Consolidated EBITDAX (non-GAAP) $ 338,069 $ 290,429 $ 697,748 $ 591,761 Net Debt Net Debt is a non-GAAP financial measure defined in the Company's Senior Secured Credit Facility as the face value of long-term debt plus any outstanding letters of credit, less cash and cash equivalents, where cash and cash equivalents are capped at $100 million when there are borrowings on the Senior Secured Credit Facility. Management believes Net Debt is useful to management and investors in determining the Company's leverage position since the Company has the ability, and may decide, to use a portion of its cash and cash equivalents to reduce debt. (in thousands) June 30, 2025 December 31, 2024 (unaudited) Total senior unsecured notes $ 1,600,578 $ 1,600,578 Senior Secured Credit Facility 745,000 880,000 Total long-term debt $ 2,345,578 $ 2,480,578 Less: cash and cash equivalents 30,194 40,179 Net Debt (non-GAAP) $ 2,315,384 $ 2,440,399 Net Debt to Consolidated EBITDAX Net Debt to Consolidated EBITDAX is a non-GAAP financial measure defined in the Company's Senior Secured Credit Facility as Net Debt divided by Consolidated EBITDAX for the previous four quarters, which requires various treatment of asset transaction impacts. Net Debt to Consolidated EBITDAX is used by the Company's management for various purposes, including as a measure of operating performance, in presentations to its board of directors and as a basis for strategic planning and forecasting.


Globe and Mail
6 minutes ago
- Globe and Mail
Energy Transfer Reports Second Quarter 2025 Results
Energy Transfer LP (NYSE:ET) ('Energy Transfer' or the 'Partnership') today reported financial results for the quarter ended June 30, 2025. Energy Transfer reported net income attributable to partners for the three months ended June 30, 2025 of $1.16 billion compared to $1.31 billion for the three months ended June 30, 2024. For the three months ended June 30, 2025, net income per common unit (basic) was $0.32. Adjusted EBITDA for the three months ended June 30, 2025 was $3.87 billion compared to $3.76 billion for the three months ended June 30, 2024. Distributable Cash Flow attributable to partners, as adjusted, for the three months ended June 30, 2025 was $1.96 billion compared to $2.04 billion for the three months ended June 30, 2024. Growth capital expenditures in the second quarter of 2025 were $1.04 billion, while maintenance capital expenditures were $253 million. Operational Highlights Energy Transfer's volumes continued to grow during the second quarter of 2025 compared to the second quarter of 2024. Interstate natural gas transportation volumes were up 11%. Midstream gathered volumes were up 10%, setting a new Partnership record. Crude oil transportation volumes were up 9%, setting a new Partnership record. Intrastate natural gas transportation volumes were up 8%. NGL transportation volumes were up 4%, setting a new Partnership record. NGL and refined products terminal volumes were up 3%, setting a new Partnership record. NGL fractionated volumes were up 5%. NGL exports were up 5%, setting a new Partnership record. In the second quarter of 2025, Energy Transfer placed its 200 MMcf/d Lenorah II Processing plant in the Midland Basin into service; the plant is currently running at full capacity. Energy Transfer recently placed its Nederland Flexport NGL Export Expansion Project into ethane and propane service and expects to begin ethylene service in the fourth quarter of this year. The project is expected to add up to 250,000 Bbls/d of total NGL export capacity at the Partnership's Nederland terminal. Energy Transfer also recently placed the 200 MMcf/d Badger Processing Plant into service. This project involved the relocation of a previously idle plant to the Delaware Basin. Energy Transfer also recently commissioned the second of eight, 10-megawatt natural gas-fired electric generation facilities in West Texas. Two more of these facilities are expected to be placed into service in 2025, with the remainder expected in service in 2026. Strategic Highlights Energy Transfer announced today a 1.5 Bcf/d expansion of its Transwestern Pipeline. Transwestern's Desert Southwest Pipeline expansion will include a 516-mile, 42-inch natural gas pipeline that will connect the Permian Basin with markets in Arizona, New Mexico, and Texas, and is expected to be in service by the fourth quarter of 2029. The project is expected to cost approximately $5.3 billion, including $0.6 billion of Allowance for Funds Used During Construction ('AFUDC'), and is supported by significant, long-term commitments with investment grade counterparties. Energy Transfer recently reached FID on Phase II of its Hugh Brinson Pipeline, which will include the addition of compression. Upon completion, this bi-directional pipeline will have the ability to transport approximately 2.2 Bcf/d from west to east and also transport approximately 1 Bcf/d from east to west. Energy Transfer also recently reached FID on the construction of a new storage cavern at its Bethel natural gas storage facility. This project will double Energy Transfer's natural gas working storage capacity at the facility to over 12 Bcf. Southeast Supply Header, LLC recently approved an expansion to its SESH pipeline to serve growing power generation needs. In June 2025, Energy Transfer signed an incremental Sale and Purchase Agreement ('SPA') with Chevron U.S.A. Inc. ('Chevron') for additional LNG supply from its proposed Lake Charles LNG export facility. The 20-year agreement for 1.0 million tonnes per annum ('mtpa') increases Chevron's total contracted volume from Energy Transfer LNG to 3.0 mtpa, following the initial 2.0 mtpa agreement signed in December 2024. In May 2025, Energy Transfer entered into a 20-year LNG SPA with Kyushu Electric Power Company, Inc. related to the Lake Charles LNG project, to supply 1.0 mtpa of LNG. In April 2025, Energy Transfer entered into a Heads of Agreement with MidOcean Energy ('MidOcean') for the joint development of the Lake Charles LNG project, under which MidOcean would commit to fund 30% of the construction costs and be entitled to 30% of the LNG production. Financial Highlights In July 2025, Energy Transfer announced a quarterly cash distribution of $0.33 per common unit ($1.32 annualized) for the quarter ended June 30, 2025, which is an increase of more than 3% compared to the second quarter of 2024. In May 2025, the Partnership redeemed $500 million aggregate principal amount of 6.75% Series F Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units using cash on hand and commercial paper borrowings. As of June 30, 2025, the Partnership's revolving credit facility had an aggregate $2.51 billion of available borrowing capacity. The Partnership now expects to be at or slightly below the lower end of its previously stated Adjusted EBITDA guidance range of $16.1 billion to $16.5 billion. The Partnership continues to expect its 2025 growth capital expenditures to be approximately $5 billion. Energy Transfer benefits from a portfolio of assets with exceptional product and geographic diversity. The Partnership's multiple segments generate high-quality, balanced earnings with no single business segment contributing more than one-third of the Partnership's consolidated Adjusted EBITDA for the three months ended June 30, 2025. In addition, Energy Transfer generates approximately 40% of its Adjusted EBITDA from natural gas-related assets. The vast majority of the Partnership's segment margins are fee-based and therefore have limited commodity price sensitivity. Conference call information: The Partnership has scheduled a conference call for 3:30 p.m. Central Time/4:30 p.m. Eastern Time on Wednesday, August 6, 2025 to discuss its second quarter 2025 results and provide an update on the Partnership. The conference call will be broadcast live via an internet webcast, which can be accessed through and will also be available for replay on the Partnership's website for a limited time. Energy Transfer LP (NYSE: ET) owns and operates one of the largest and most diversified portfolios of energy assets in the United States, with approximately 140,000 miles of pipeline and associated energy infrastructure. Energy Transfer's strategic network spans 44 states with assets in all of the major U.S. production basins. Energy Transfer is a publicly traded limited partnership with core operations that include complementary natural gas midstream, intrastate and interstate transportation and storage assets; crude oil, natural gas liquids ('NGL') and refined product transportation and terminalling assets; and NGL fractionation. Energy Transfer also owns Lake Charles LNG Company, as well as the general partner interests, the incentive distribution rights and approximately 21% of the outstanding common units of Sunoco LP (NYSE: SUN), and the general partner interests and approximately 38% of the outstanding common units of USA Compression Partners, LP (NYSE: USAC). For more information, visit the Energy Transfer LP website at Sunoco LP (NYSE: SUN) is a leading energy infrastructure and fuel distribution master limited partnership operating in over 40 U.S. states, Puerto Rico, Europe, and Mexico. SUN's midstream operations include an extensive network of approximately 14,000 miles of pipeline and over 100 terminals. This critical infrastructure complements SUN's fuel distribution operations, which serve approximately 7,400 Sunoco and partner branded locations and additional independent dealers and commercial customers. SUN's general partner is owned by Energy Transfer LP (NYSE: ET). For more information, visit the Sunoco LP website at USA Compression Partners, LP (NYSE: USAC) is one of the nation's largest independent providers of natural gas compression services in terms of total compression fleet horsepower. USAC partners with a broad customer base composed of producers, processors, gatherers, and transporters of natural gas and crude oil. USAC focuses on providing midstream natural gas compression services to infrastructure applications primarily in high-volume gathering systems, processing facilities, and transportation applications. For more information, visit the USAC website at Forward-Looking Statements This news release may include certain statements concerning expectations for the future that are forward-looking statements as defined by federal law. Such forward-looking statements are subject to a variety of known and unknown risks, uncertainties, and other factors that are difficult to predict and many of which are beyond management's control. An extensive list of factors that can affect future results, including Adjusted EBITDA, and impact current projections, including capital expenditures, are discussed in the Partnership's Annual Report on Form 10-K and other documents filed from time to time with the Securities and Exchange Commission. The Partnership undertakes no obligation to update or revise any forward-looking statement to reflect new information or events. The information contained in this press release is available on our website at June 30, 2025 December 31, 2024 ASSETS Current assets $ 13,671 $ 14,202 Property, plant and equipment, net 95,531 95,212 Investments in unconsolidated affiliates 3,243 3,266 Lease right-of-use assets, net 828 809 Other non-current assets, net 2,072 2,017 Intangible assets, net 5,774 5,971 Goodwill 3,903 3,903 Total assets $ 125,022 $ 125,380 LIABILITIES AND EQUITY Current liabilities $ 11,849 $ 12,656 Long-term debt, less current maturities 60,749 59,752 Non-current operating lease liabilities 754 730 Deferred income taxes 4,204 4,190 Other non-current liabilities 1,609 1,618 Commitments and contingencies Redeemable noncontrolling interests 323 417 Equity: Limited Partners: Preferred Unitholders 3,356 3,852 Common Unitholders 31,360 31,195 General Partner (2 ) (2 ) Accumulated other comprehensive income 65 73 Total partners' capital 34,779 35,118 Noncontrolling interests 10,755 10,899 Total equity 45,534 46,017 Total liabilities and equity $ 125,022 $ 125,380 ENERGY TRANSFER LP AND SUBSIDIARIES (In millions, except per unit data) (unaudited) Three Months Ended June 30, Six Months Ended June 30, 2025 2024 2025 2024 REVENUES $ 19,242 $ 20,729 $ 40,262 $ 42,358 COSTS AND EXPENSES: Cost of products sold 13,946 15,609 29,517 32,206 Operating expenses 1,343 1,227 2,642 2,365 Depreciation, depletion and amortization 1,384 1,213 2,751 2,467 Selling, general and administrative 257 332 545 592 Impairment losses 3 50 7 50 Total costs and expenses 16,933 18,431 35,462 37,680 OPERATING INCOME 2,309 2,298 4,800 4,678 OTHER INCOME (EXPENSE): Interest expense, net of interest capitalized (865 ) (762 ) (1,674 ) (1,490 ) Equity in earnings of unconsolidated affiliates 105 85 197 183 Losses on extinguishments of debt (17 ) (6 ) (19 ) (11 ) Gain on interest rate derivative — 3 — 12 Gain on sale of Sunoco LP West Texas assets — 598 — 598 Other, net 5 3 (6 ) 30 INCOME BEFORE INCOME TAX EXPENSE 1,537 2,219 3,298 4,000 Income tax expense 79 227 120 316 NET INCOME 1,458 1,992 3,178 3,684 Less: Net income attributable to noncontrolling interests 275 663 659 1,099 Less: Net income attributable to redeemable noncontrolling interests 20 15 33 31 NET INCOME ATTRIBUTABLE TO PARTNERS 1,163 1,314 2,486 2,554 General Partner's interest in net income 1 1 2 2 Preferred Unitholders' interest in net income 63 98 130 227 Loss on redemption of preferred units 8 33 8 54 Common Unitholders' interest in net income $ 1,091 $ 1,182 $ 2,346 $ 2,271 NET INCOME PER COMMON UNIT: Basic $ 0.32 $ 0.35 $ 0.68 $ 0.67 Diluted $ 0.32 $ 0.35 $ 0.68 $ 0.67 WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING: Basic 3,432.2 3,370.6 3,431.8 3,369.6 Diluted 3,453.5 3,394.9 3,454.1 3,393.3 ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION (Dollars and units in millions) (unaudited) Three Months Ended June 30, Six Months Ended June 30, 2025 2024 2025 2024 Reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow (a): Net income $ 1,458 $ 1,992 $ 3,178 $ 3,684 Depreciation, depletion and amortization 1,384 1,213 2,751 2,467 Interest expense, net of interest capitalized 865 762 1,674 1,490 Income tax expense 79 227 120 316 Impairment losses 3 50 7 50 Gain on interest rate derivative — (3 ) — (12 ) Non-cash compensation expense 33 30 70 76 Unrealized (gains) losses on commodity risk management activities (100 ) (38 ) (31 ) 103 Inventory valuation adjustments (Sunoco LP) 40 32 (21 ) (98 ) Losses on extinguishments of debt 17 6 19 11 Adjusted EBITDA related to unconsolidated affiliates 182 170 349 341 Equity in earnings of unconsolidated affiliates (105 ) (85 ) (197 ) (183 ) Gain on sale of Sunoco LP West Texas assets — (598 ) — (598 ) Other, net 10 2 45 (7 ) Adjusted EBITDA (consolidated) 3,866 3,760 7,964 7,640 Adjusted EBITDA related to unconsolidated affiliates (b) (182 ) (170 ) (349 ) (341 ) Distributable cash flow from unconsolidated affiliates (b) 129 121 240 246 Interest expense, net of interest capitalized (865 ) (762 ) (1,674 ) (1,490 ) Preferred unitholders' distributions (65 ) (100 ) (137 ) (218 ) Current income tax expense (55 ) (239 ) (112 ) (261 ) Transaction-related income taxes (c) — 199 — 199 Maintenance capital expenditures (305 ) (258 ) (507 ) (393 ) Other, net 13 19 35 56 Distributable Cash Flow (consolidated) 2,536 2,570 5,460 5,438 Distributable Cash Flow attributable to Sunoco LP (290 ) (186 ) (600 ) (357 ) Distributions from Sunoco LP 67 61 131 122 Distributable Cash Flow attributable to USAC (100%) (90 ) (85 ) (179 ) (172 ) Distributions from USAC 24 24 48 48 Distributable Cash Flow attributable to noncontrolling interests in other non-wholly owned consolidated subsidiaries (289 ) (346 ) (597 ) (688 ) Distributable Cash Flow attributable to the partners of Energy Transfer 1,958 2,038 4,263 4,391 Transaction-related adjustments 1 1 3 4 Distributable Cash Flow attributable to the partners of Energy Transfer, as adjusted $ 1,959 $ 2,039 $ 4,266 $ 4,395 Distributions to partners: Limited Partners $ 1,133 $ 1,095 $ 2,257 $ 2,165 General Partner 1 1 2 2 Total distributions to be paid to partners $ 1,134 $ 1,096 $ 2,259 $ 2,167 Common Units outstanding – end of period 3,432.6 3,371.4 3,432.6 3,371.4 (a) Adjusted EBITDA and Distributable Cash Flow are non-GAAP financial measures used by industry analysts, investors, lenders and rating agencies to assess the financial performance and the operating results of Energy Transfer's fundamental business activities and should not be considered in isolation or as a substitute for net income, income from operations, cash flows from operating activities or other GAAP measures. There are material limitations to using measures such as Adjusted EBITDA and Distributable Cash Flow, including the difficulty associated with using either as the sole measure to compare the results of one company to another, and the inability to analyze certain significant items that directly affect a company's net income or loss or cash flows. In addition, our calculations of Adjusted EBITDA and Distributable Cash Flow may not be consistent with similarly titled measures of other companies and should be viewed in conjunction with measures that are computed in accordance with GAAP, such as operating income, net income and cash flows from operating activities. Definition of Adjusted EBITDA We define Adjusted EBITDA as total partnership earnings before interest, taxes, depreciation, depletion, amortization and other non-cash items, such as non-cash compensation expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and other non-operating income or expense items. Inventory valuation adjustments that are excluded from the calculation of Adjusted EBITDA represent only the changes in lower of cost or market reserves on inventory that is carried at last-in, first-out ('LIFO'). These amounts are unrealized valuation adjustments applied to Sunoco LP's fuel volumes remaining in inventory at the end of the period. Adjusted EBITDA reflects amounts for unconsolidated affiliates based on the same recognition and measurement methods used to record equity in earnings of unconsolidated affiliates. Adjusted EBITDA related to unconsolidated affiliates excludes the same items with respect to the unconsolidated affiliate as those excluded from the calculation of Adjusted EBITDA, such as interest, taxes, depreciation, depletion, amortization and other non-cash items. Although these amounts are excluded from Adjusted EBITDA related to unconsolidated affiliates, such exclusion should not be understood to imply that we have control over the operations and resulting revenues and expenses of such affiliates. We do not control our unconsolidated affiliates; therefore, we do not control the earnings or cash flows of such affiliates. The use of Adjusted EBITDA or Adjusted EBITDA related to unconsolidated affiliates as an analytical tool should be limited accordingly. Adjusted EBITDA is used by management to determine our operating performance and, along with other financial and volumetric data, as internal measures for setting annual operating budgets, assessing financial performance of our numerous business locations, as a measure for evaluating targeted businesses for acquisition and as a measurement component of incentive compensation. Definition of Distributable Cash Flow We define Distributable Cash Flow as net income, adjusted for certain non-cash items, less distributions to preferred unitholders and maintenance capital expenditures. Non-cash items include depreciation, depletion and amortization, non-cash compensation expense, amortization included in interest expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and deferred income taxes. For unconsolidated affiliates, Distributable Cash Flow reflects the Partnership's proportionate share of the investees' distributable cash flow. Distributable Cash Flow is used by management to evaluate our overall performance. Our partnership agreement requires us to distribute all available cash, and Distributable Cash Flow is calculated to evaluate our ability to fund distributions through cash generated by our operations. On a consolidated basis, Distributable Cash Flow includes 100% of the Distributable Cash Flow of Energy Transfer's consolidated subsidiaries. However, to the extent that noncontrolling interests exist among our subsidiaries, the Distributable Cash Flow generated by our subsidiaries may not be available to be distributed to our partners. In order to reflect the cash flows available for distributions to our partners, we have reported Distributable Cash Flow attributable to partners, which is calculated by adjusting Distributable Cash Flow (consolidated), as follows: For subsidiaries with publicly traded equity interests, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiary, and Distributable Cash Flow attributable to our partners includes distributions to be received by the parent company with respect to the periods presented. For consolidated joint ventures or similar entities, where the noncontrolling interest is not publicly traded, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiaries, but Distributable Cash Flow attributable to partners reflects only the amount of Distributable Cash Flow of such subsidiaries that is attributable to our ownership interest. For Distributable Cash Flow attributable to partners, as adjusted, certain transaction-related adjustments and non-recurring expenses that are included in net income are excluded. (b) These amounts exclude Sunoco LP's Adjusted EBITDA and distributable cash flow related to its investment in the ET-S Permian and J.C. Nolan joint ventures, which amounts are eliminated in the Energy Transfer consolidation. (c) For the three and six months ended June 30, 2024, the amount reflected for transaction-related income taxes reflects current income tax expense recognized by Sunoco LP in connection with its April 2024 sale of convenience stores in West Texas, New Mexico and Oklahoma. ENERGY TRANSFER LP AND SUBSIDIARIES (Tabular dollar amounts in millions) (unaudited) Three Months Ended June 30, 2025 2024 Segment Adjusted EBITDA: Intrastate transportation and storage $ 284 $ 328 Interstate transportation and storage 470 392 Midstream 768 693 NGL and refined products transportation and services 1,033 1,070 Crude oil transportation and services 732 801 Investment in Sunoco LP 454 320 Investment in USAC 149 144 All other (24 ) 12 Adjusted EBITDA (consolidated) $ 3,866 $ 3,760 The following analysis of segment operating results includes a measure of segment margin. Segment margin is a non-GAAP financial measure and is presented herein to assist in the analysis of segment operating results and particularly to facilitate an understanding of the impacts that changes in sales revenues have on the segment performance measure of Segment Adjusted EBITDA. Segment margin is similar to the GAAP measure of gross margin, except that segment margin excludes charges for depreciation, depletion and amortization. Among the GAAP measures reported by the Partnership, the most directly comparable measure to segment margin is Segment Adjusted EBITDA; a reconciliation of segment margin to Segment Adjusted EBITDA is included in the following tables for each segment where segment margin is presented. Three Months Ended June 30, 2025 2024 Natural gas transported (BBtu/d) 14,229 13,143 Revenues $ 931 $ 637 Cost of products sold 561 205 Segment margin 370 432 Unrealized gains on commodity risk management activities (21 ) (29 ) Operating expenses, excluding non-cash compensation expense (61 ) (66 ) Selling, general and administrative expenses, excluding non-cash compensation expense (10 ) (14 ) Adjusted EBITDA related to unconsolidated affiliates 5 5 Other 1 — Segment Adjusted EBITDA $ 284 $ 328 Transported volumes of gas on our Texas intrastate pipelines increased primarily due to more third-party transportation. Transported volumes reported above exclude volumes attributable to purchases and sales of gas for our pipelines' own accounts and the optimization of any unused capacity. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our intrastate transportation and storage segment decreased due to the net impact of the following: a decrease of $45 million in realized natural gas sales and other primarily due to lower optimization volumes with shifts to long-term third-party contracts from the Permian and narrower price spreads; a decrease of $11 million in transportation fees primarily due to the recovery in the prior period of certain disputed fees on our Texas system; and a decrease of $2 million in storage margin primarily due to lower storage optimization; partially offset by a decrease of $5 million in operating expenses primarily due to a decrease in maintenance projects costs; and an increase of $4 million in retained fuel margin primarily due to higher gas prices. Interstate Transportation and Storage Three Months Ended June 30, 2025 2024 Natural gas transported (BBtu/d) 18,153 16,337 Natural gas sold (BBtu/d) 30 20 Revenues $ 590 $ 519 Cost of products sold 3 2 Segment margin 587 517 Operating expenses, excluding non-cash compensation, amortization, accretion and other non-cash expenses (221 ) (210 ) Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses (26 ) (32 ) Adjusted EBITDA related to unconsolidated affiliates 130 118 Other — (1 ) Segment Adjusted EBITDA $ 470 $ 392 Transported volumes increased primarily due to more capacity sold and higher utilization on several of our major pipeline systems due to increased demand. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our interstate transportation and storage segment increased due to the net impact of the following: an increase of $70 million in segment margin primarily due to a $35 million negative impact in the prior period related to the conclusion of a rate case on our Panhandle system, a $33 million increase in transportation revenue from several of our interstate pipeline systems due to higher contracted volumes and a $4 million increase due to higher storage and liquids revenue; and an increase of $12 million in Adjusted EBITDA related to unconsolidated affiliates due to a $6 million increase from our Citrus joint venture, a $4 million increase from our Midcontinent Express Pipeline joint venture and a $2 million increase from our Southeast Supply Header pipeline joint venture; partially offset by an increase of $11 million in operating expenses primarily due to an increase in volume-driven expenses. Midstream Three Months Ended June 30, 2025 2024 Gathered volumes (BBtu/d) 21,329 19,437 NGLs produced (MBbls/d) 1,181 955 Equity NGLs (MBbls/d) 64 56 Revenues $ 3,135 $ 2,507 Cost of products sold 1,911 1,457 Segment margin 1,224 1,050 Operating expenses, excluding non-cash compensation expense (416 ) (321 ) Selling, general and administrative expenses, excluding non-cash compensation expense (47 ) (43 ) Adjusted EBITDA related to unconsolidated affiliates 6 6 Other 1 1 Segment Adjusted EBITDA $ 768 $ 693 Gathered volumes increased primarily due to newly acquired assets, as well as additional and upgraded plants in the Permian region, partially offset by lower dry gas gathering in the Northeast and Ark-La-Tex regions. NGL production increased primarily due to recently acquired assets and increased Permian plant utilization. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our midstream segment increased due to the net impact of the following: an increase of $176 million in segment margin primarily due to recently acquired assets and higher volumes in the Permian region; and an increase of $11 million in segment margin due to higher natural gas prices of $38 million, partially offset by lower NGL prices of $27 million; partially offset by a decrease of $13 million in segment margin due to lower dry gas volumes in the Northeast and Ark-La-Tex regions; an increase of $95 million in operating expenses primarily due to recently acquired assets and assets placed in service as well as higher employee costs; and an increase of $4 million in selling, general and administrative expenses due to an adjustment to the workers' compensation reserve in the prior period and higher corporate allocations. NGL and Refined Products Transportation and Services Three Months Ended June 30, 2025 2024 NGL transportation volumes (MBbls/d) 2,331 2,235 Refined products transportation volumes (MBbls/d) 599 602 NGL and refined products terminal volumes (MBbls/d) 1,553 1,506 NGL fractionation volumes (MBbls/d) 1,150 1,093 Revenues $ 5,941 $ 5,795 Cost of products sold 4,635 4,512 Segment margin 1,306 1,283 Unrealized (gains) losses on commodity risk management activities (34 ) 20 Operating expenses, excluding non-cash compensation expense (230 ) (232 ) Selling, general and administrative expenses, excluding non-cash compensation expense (41 ) (34 ) Adjusted EBITDA related to unconsolidated affiliates 32 33 Segment Adjusted EBITDA $ 1,033 $ 1,070 NGL transportation volumes increased primarily due to higher volumes from the Permian region. The increase in transportation volumes also led to higher fractionated volumes at our Mont Belvieu NGL Complex. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our NGL and refined products transportation and services segment decreased due to the net impact of the following: a decrease of $78 million in marketing margin (excluding unrealized gains and losses on commodity risk management activities) primarily due to lower gains from the optimization of hedged NGL and refined product inventories; and an increase of $7 million in selling, general and administrative expenses primarily due to increased costs from recently acquired assets; partially offset by an increase of $33 million in transportation margin primarily due to higher throughput and contractual rate escalations on our Mariner East and our Gulf Coast pipeline systems; and an increase of $12 million in fractionators and refinery services margin primarily due to higher throughput. Crude Oil Transportation and Services Three Months Ended June 30, 2025 2024 Crude oil transportation volumes (MBbls/d) 7,049 6,490 Crude oil terminal volumes (MBbls/d) 3,216 3,291 Revenues $ 5,748 $ 7,372 Cost of products sold 4,725 6,309 Segment margin 1,023 1,063 Unrealized gains on commodity risk management activities (25 ) (19 ) Operating expenses, excluding non-cash compensation expense (237 ) (216 ) Selling, general and administrative expenses, excluding non-cash compensation expense (38 ) (36 ) Adjusted EBITDA related to unconsolidated affiliates 8 7 Other 1 2 Segment Adjusted EBITDA $ 732 $ 801 Crude oil transportation volumes were higher due to continued growth on our gathering systems and from assets contributed upon the recent formation of the ET-S Permian joint venture with Sunoco LP, partially offset by lower volumes on our Bakken Pipeline. Crude terminal volumes were lower primarily due to lower volumes received from our Bakken Pipeline system. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our crude oil transportation and services segment decreased due to the net impact of the following: a decrease of $46 million in segment margin (excluding unrealized gains and losses on commodity risk management activities) due to decreased transportation revenue, primarily from our Bakken Pipeline system, partially offset by increases from assets contributed upon the formation of the ET-S Permian joint venture; an increase of $21 million in operating expenses primarily due to a $10 million increase from assets contributed upon the formation of the ET-S Permian joint venture, a $6 million increase in employee costs and a $5 million increase in expense projects; and an increase of $2 million in selling, general and administrative expenses primarily due to costs associated with the ET-S Permian joint venture. Investment in Sunoco LP Three Months Ended June 30, 2025 2024 Revenues $ 5,390 $ 6,173 Cost of products sold 4,821 5,609 Segment margin 569 564 Unrealized gains on commodity risk management activities (7 ) (6 ) Operating expenses, excluding non-cash compensation expense (162 ) (149 ) Selling, general and administrative expenses, excluding non-cash compensation expense (47 ) (132 ) Adjusted EBITDA related to unconsolidated affiliates 51 3 Inventory fair value adjustments 40 32 Other, net 10 8 Segment Adjusted EBITDA $ 454 $ 320 The investment in Sunoco LP segment reflects the consolidated results of Sunoco LP. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our investment in Sunoco LP segment increased due to the net impact of the following: an increase of $12 million in segment margin (excluding unrealized gains and losses on commodity risk management activities and inventory valuation adjustments) primarily due to the acquisition of NuStar, which was acquired in May 2024 and therefore is only reflected for two months in the prior period. This increase was partially offset by a decrease of $50 million from Sunoco LP's deconsolidation of certain of NuStar's assets in connection with the formation of ET-S Permian effective July 1, 2024, as well as a $29 million decrease in fuel profit due to lower profit per gallon; an increase of $48 million in Adjusted EBITDA related to unconsolidated affiliates due to the formation of ET-S Permian; and a decrease of $85 million in selling, general and administrative expenses, excluding non-cash compensation expense, primarily related to one-time NuStar acquisition costs in 2024; partially offset by an increase of $13 million in operating expenses due to increased costs from the acquisition of NuStar, which was acquired in May 2024 and therefore is only reflected for two months in the prior period. This increase was partially offset by a decrease of $6 million from Sunoco LP's deconsolidation of certain of NuStar's assets in connection with the formation of ET-S Permian effective July 1, 2024. Investment in USAC Three Months Ended June 30, 2025 2024 Revenues $ 250 $ 236 Cost of products sold 40 36 Segment margin 210 200 Operating expenses, excluding non-cash compensation expense (47 ) (43 ) Selling, general and administrative expenses, excluding non-cash compensation expense (14 ) (14 ) Other — 1 Segment Adjusted EBITDA $ 149 $ 144 The investment in USAC segment reflects the consolidated results of USAC. Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our investment in USAC segment increased due to the net impact of the following: an increase of $10 million in segment margin primarily due to higher revenue-generating horsepower as a result of increased demand for compression services and higher market-based rates on newly deployed and redeployed compression units; partially offset by an increase of $4 million in operating expenses primarily due to an increase in employee costs associated with increased revenue-generating horsepower. All Other Three Months Ended June 30, 2025 2024 Revenues $ 936 $ 296 Cost of products sold 909 287 Segment margin 27 9 Unrealized gains on commodity risk management activities (14 ) (4 ) Operating expenses, excluding non-cash compensation expense — (3 ) Selling, general and administrative expenses, excluding non-cash compensation expense (13 ) (8 ) Adjusted EBITDA related to unconsolidated affiliates 2 1 Other and eliminations (26 ) 17 Segment Adjusted EBITDA $ (24 ) $ 12 Segment Adjusted EBITDA. For the three months ended June 30, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our all other segment decreased due to the net impact of the following: a decrease of $48 million due to the intersegment elimination of Sunoco LP's 32.5% share of ET-S Permian, which is consolidated in our crude oil transportation and services segment and also reflected as an unconsolidated affiliate in our investment in Sunoco LP segment; partially offset by an increase of $9 million in our natural gas marketing business; and an increase of $4 million from our compressor packaging business. ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION ON LIQUIDITY (In millions) (unaudited) The table below provides information on our revolving credit facility. We also have consolidated subsidiaries with revolving credit facilities which are not included in this table. Facility Size Funds Available at June 30, 2025 Maturity Date Five-Year Revolving Credit Facility $ 5,000 $ 2,506 April 11, 2029 ENERGY TRANSFER LP AND SUBSIDIARIES (In millions) (unaudited) The table below provides information on an aggregated basis for our unconsolidated affiliates, which are accounted for as equity method investments in the Partnership's financial statements for the periods presented. Three Months Ended June 30, 2025 2024 Equity in earnings of unconsolidated affiliates: Citrus $ 40 $ 27 MEP 18 14 White Cliffs 5 4 Explorer 7 9 SESH 14 10 Other 21 21 Total equity in earnings of unconsolidated affiliates $ 105 $ 85 Adjusted EBITDA related to unconsolidated affiliates: Citrus $ 88 $ 82 MEP 26 22 White Cliffs 10 8 Explorer 12 14 SESH 15 13 Other 31 31 Total Adjusted EBITDA related to unconsolidated affiliates $ 182 $ 170 Distributions received from unconsolidated affiliates: Citrus $ 36 $ 61 MEP 29 24 White Cliffs 9 10 Explorer 10 10 SESH 15 14 Other 25 26 Total distributions received from unconsolidated affiliates $ 124 $ 145 ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION ON NON-WHOLLY OWNED JOINT VENTURE SUBSIDIARIES (In millions) (unaudited) The table below provides information on an aggregated basis for our non-wholly owned joint venture subsidiaries, which are reflected on a consolidated basis in our financial statements. The table below excludes Sunoco LP and USAC, which are non-wholly owned subsidiaries that are publicly traded, as well as Sunoco LP's 32.5% interest in the ET-S Permian joint venture. Three Months Ended June 30, 2025 2024 Adjusted EBITDA of non-wholly owned subsidiaries (100%) (a) $ 566 $ 677 Our proportionate share of Adjusted EBITDA of non-wholly owned subsidiaries (b) 275 329 Distributable Cash Flow of non-wholly owned subsidiaries (100%) (c) $ 544 $ 655 Our proportionate share of Distributable Cash Flow of non-wholly owned subsidiaries (d) 255 309 Below is our ownership percentage of certain non-wholly owned subsidiaries: Non-wholly owned subsidiary: Energy Transfer Percentage Ownership (e) Bakken Pipeline 36.4 % Bayou Bridge 60.0 % Maurepas 51.0 % Ohio River System 75.0 % Permian Express Partners 87.7 % Red Bluff Express 70.0 % Rover 32.6 % Others various (a) Adjusted EBITDA of non-wholly owned subsidiaries reflects the total Adjusted EBITDA of our non-wholly owned subsidiaries on an aggregated basis. This is the amount included in our consolidated non-GAAP measure of Adjusted EBITDA. (b) Our proportionate share of Adjusted EBITDA of non-wholly owned subsidiaries reflects the amount of Adjusted EBITDA of such subsidiaries (on an aggregated basis) that is attributable to our ownership interest. (c) Distributable Cash Flow of non-wholly owned subsidiaries reflects the total Distributable Cash Flow of our non-wholly owned subsidiaries on an aggregated basis. (d) Our proportionate share of Distributable Cash Flow of non-wholly owned subsidiaries reflects the amount of Distributable Cash Flow of such subsidiaries (on an aggregated basis) that is attributable to our ownership interest. This is the amount included in our consolidated non-GAAP measure of Distributable Cash Flow attributable to the partners of Energy Transfer.