Energy Transfer Reports First Quarter 2025 Results

Energy Transfer LP (NYSE:ET) ("Energy Transfer" or the "Partnership") today reported financial results for the quarter ended March 31, 2025.

Energy Transfer reported net income attributable to partners for the three months ended March 31, 2025 of $1.32 billion compared to $1.24 billion for the three months ended March 31, 2024. For the three months ended March 31, 2025, net income per common unit (basic) was $0.37.

Adjusted EBITDA for the three months ended March 31, 2025 was $4.10 billion compared to $3.88 billion for the three months ended March 31, 2024.

Distributable Cash Flow attributable to partners, as adjusted, for the three months ended March 31, 2025 was $2.31 billion compared to $2.36 billion for the three months ended March 31, 2024.

Growth capital expenditures in the first quarter of 2025 were $955 million, while maintenance capital expenditures were $165 million.

Operational Highlights

• Energy Transfer's volumes continued to grow during the first quarter of 2025 compared to the first quarter of 2024.
  • Interstate natural gas transportation volumes were up 3%, setting a new Partnership record.
  • Crude oil transportation volumes were up 10%.
  • NGL transportation volumes were up 4%.
  • NGL and refined products terminal volumes were up 4%.
  • NGL exports were up 5%.
  • Midstream gathered volumes were up more than 2%.
• In February 2025, Energy Transfer commissioned the first of eight, 10-megawatt natural gas-fired electric generation facilities to support the Partnership's operations in Texas.
• During the first quarter of 2025, Energy Transfer commenced construction of Phase I of the Hugh Brinson Pipeline and secured all pipeline steel, which is currently being rolled in U.S. pipe mills.

Strategic Highlights

• 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 receive 30% of the LNG production.
• In February 2025, Energy Transfer entered into a long-term agreement with Cloudburst Data Centers, Inc. ("CloudBurst") to provide natural gas to CloudBurst's flagship AI-focused data center development.
• In February 2025, Energy Transfer approved construction of an additional natural gas processing plant in the Midland Basin. The Mustang Draw plant will have a processing capacity of approximately 275 MMcf/d and is expected to be in service in the second quarter of 2026.

Financial Highlights

• In April 2025, Energy Transfer announced a quarterly cash distribution of $0.3275 per common unit ($1.31 annualized) for the quarter ended March 31, 2025, which is an increase of more than 3% compared to the first quarter of 2024.
• As of March 31, 2025, the Partnership's revolving credit facility had an aggregate $4.37 billion of available borrowing capacity.
• The Partnership continues to expect its 2025 Adjusted EBITDA to be between $16.1 billion and $16.5 billion, and 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 segment contributing more than one-third of the Partnership's consolidated Adjusted EBITDA for the three months ended March 31, 2025. 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 Tuesday, May 6, 2025 to discuss its first 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 www.energytransfer.com 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 more than 130,000 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 39% of the outstanding common units of USA Compression Partners, LP (NYSE:USAC). For more information, visit the Energy Transfer LP website at www.energytransfer.com.

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 www.sunocolp.com.

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 www.usacompression.com.

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 www.energytransfer.com.

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.

Transported volumes of gas on our Texas and Oklahoma intrastate pipelines increased primarily due to more third party transportation, partially offset by lower gas production from the Haynesville area. 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 March 31, 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 $122 million in realized natural gas sales and other primarily due to lower pipeline optimization as a result of lower volatility in natural gas prices; and
• an increase of $4 million in operating expenses primarily due to increases in project costs, employee costs and ad valorem taxes; partially offset by
• an increase of $26 million in storage margin primarily due to higher storage optimization; and
• an increase of $8 million in retained fuel margin primarily due to higher gas prices.

Transported volumes increased primarily due to more capacity sold and higher utilization on our Panhandle, Trunkline and Gulf Run systems due to increased demand.

Segment Adjusted EBITDA. For the three months ended March 31, 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 $18 million in segment margin primarily due to a $9 million increase in operational gas sales resulting from higher prices, a $5 million increase in storage and parking revenue and a $4 million increase in transportation revenue from several of our interstate pipeline systems due to higher contracted volumes at higher rates;
• a decrease of $14 million in operating expenses primarily due to lower maintenance costs; and
• an increase of $1 million in Adjusted EBITDA related to unconsolidated affiliates primarily due to an increase from our Southeast Supply Header joint venture; partially offset by
• an increase of $4 million in selling, general and administrative expenses primarily due to an increase in employee costs.

Gathered volumes increased primarily due to newly acquired assets and higher volumes in the Permian region, partially offset by declines in other regions. NGL production increased primarily due to recently acquired assets and increased Permian plant utilization.

Segment Adjusted EBITDA. For the three months ended March 31, 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 $153 million in segment margin primarily due to recently acquired assets and higher volumes in the Permian region;
• an increase of $160 million in segment margin due to the non-recurring recognition of certain amounts associated with Winter Storm Uri in 2021, which represents the remainder of midstream segment margin from Winter Storm Uri that had not already been recognized. In our intrastate transportation and storage segment, a total of approximately $285 million of previously invoiced amounts, excluding interest, related to Winter Storm Uri are currently disputed by customers and remain unrecognized, of which approximately $263 million is due from CPS Energy; and
• an increase of $28 million in segment margin due to higher natural gas prices of $35 million offset by lower NGL prices of $7 million; partially offset by
• an increase of $98 million in operating expenses primarily due to recent acquisitions and assets placed in service; and
• an increase of $12 million in selling, general and administrative expenses due to higher corporate allocations, as well as the impact of a $5 million decrease in workers' compensation reserve in the prior period.

NGL transportation volumes increased primarily due to higher volumes from the Permian region and on our Mariner East pipeline system. 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 March 31, 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:

• an increase of $19 million in operating expenses primarily due to a $10 million increase in gas and power utility costs and a $6 million increase in employee costs;
• a decrease of $15 million in fractionators and refinery services margin primarily due to lower gains from blending activities; and
• an increase of $6 million in selling, general and administrative expenses primarily due to increased costs from recently acquired assets; partially offset by
• an increase of $24 million in terminal services margin primarily due to a $22 million increase in fees from loading NGL volumes for export at our Nederland and Marcus Hook terminals and a $2 million increase from higher throughput and storage at our refined product terminals; and
• an increase of $2 million in storage margin primarily due to the timing of deficiency payments.

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.

Segment Adjusted EBITDA. For the three months ended March 31, 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 $69 million in segment margin (excluding unrealized losses on commodity risk management activities) due to decreased transportation and the timing of optimization losses realized during the quarter which we expect to partially reverse in future periods, partially offset by increases from assets contributed upon the formation of ET-S Permian;
• an increase of $25 million in operating expenses primarily due to a $9 million increase from assets contributed upon the formation of ET-S Permian, a $7 million increase in volume-driven expenses, and a $5 million increase in employee expenses;
• an increase of $8 million in selling, general and administrative expenses primarily due to costs associated with ET-S Permian; and
• a decrease of $3 million in Adjusted EBITDA related to unconsolidated affiliates due to lower volumes and lower re-contracted rates.

The investment in Sunoco LP segment reflects the consolidated results of Sunoco LP.

Segment Adjusted EBITDA. For the three months ended March 31, 2025 compared to the same period last year, Segment Adjusted EBITDA related to our investment in Sunoco LP increased due to the net impact of the following:

• an increase of $224 million in segment margin (excluding unrealized gains and losses on commodity risk management activities and inventory valuation adjustments) primarily due to the acquisitions of NuStar and Zenith European terminals; and
• an increase of $47 million in Adjusted EBITDA related to unconsolidated affiliates due to the formation of ET-S Permian; partially offset by
• an increase of $53 million in operating expenses and $4 million in selling, general and administrative expenses primarily due to the acquisitions of NuStar and Zenith European terminals.

The investment in USAC segment reflects the consolidated results of USAC.

Segment Adjusted EBITDA. For the three months ended March 31, 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 $14 million in segment margin primarily due to higher market-based rates on newly deployed and redeployed compression units and higher average rates on existing customer contracts, and higher revenue-generating horsepower as a result of increased demand for compression services; 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.

Segment Adjusted EBITDA. For the three months ended March 31, 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 $47 million due to intersegment eliminations 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; and
• a decrease of $13 million in our natural gas marketing business due to the timing of gains on stored natural gas in the prior period; partially offset by
• an increase of $3 million in rental income on recently acquired real estate.

   

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