Energy Transfer’s Buy case is driven by rising EBITDA, higher 2026 guidance, and fully contracted pipeline growth. The offset is a leveraged balance sheet that keeps the story in moderate-risk territory.
Energy Transfer LP (ET) merits a Buy rating for moderate-risk investors seeking income and medium-term growth. The case rests on three facts: second-quarter 2026 adjusted EBITDA rose 31% year over year to $5.07B, full-year 2026 adjusted EBITDA guidance increased to $18.8B-$19.1B, and the company is adding long-term contracted capacity for natural gas, NGLs, crude oil, power generation, and data centers.
The main attraction is an integrated network that links U.S. production basins with storage, processing, fractionation, pipelines, terminals, power plants, and export markets. ET operates about 140,000 miles of pipeline and associated infrastructure across 44 states. That footprint gives the partnership several ways to monetize the same molecule, although it also comes with heavy debt, large growth capital requirements, and exposure to commodity-driven optimization gains.
The balance sheet keeps ET from earning a more aggressive rating. Debt reached $68.6B at June 30, 2026, compared with $1.0B of cash, while annual debt-to-equity stood at 2.0x at December 31, 2025. The operating trajectory is stronger than the capital structure, which is a familiar midstream trade-off: a broad toll-road network, financed with a large mortgage.
Energy Transfer LP is a Dallas-based energy infrastructure partnership founded in 1996 and listed on the NYSE under ET. The company had 22,311 employees and operated across natural gas transportation and storage, midstream gathering and processing, NGL logistics, refined products, crude oil transportation, and investments in Sunoco LP and USA Compression Partners.
Its physical network includes approximately 12,200 miles of intrastate natural gas pipelines, 20,090 miles of interstate natural gas pipelines, 5,700 miles of NGL pipelines, and 18,000 miles of crude oil trunk and gathering pipelines. The system also includes storage facilities, processing plants, fractionators, terminals, compression assets, and refined-product distribution under the Sunoco and EcoMaxx brands.
ET's revenue mix shows why the company is more diversified than a single-commodity pipeline operator. In 2024, Oil and Gas revenue was $25.4B, Oil and Gas, Refining and Marketing revenue was $22.1B, NGL sales revenue was $19.1B, and Natural Gas, Midstream revenue was $12.0B. That mix creates resilience across commodity corridors, but sales-linked businesses also make reported revenue more volatile than fee-based earnings alone.
NGL and refined products is one of ET's strongest current growth areas. First-quarter 2026 adjusted EBITDA reached approximately $1.2B, up from $978M in the prior-year quarter. Higher Gulf Coast pipeline throughput, record Mont Belvieu fractionation volumes, new chilling capacity, and record Nederland export volumes supported the result.
Crude oil transportation generated first-quarter 2026 adjusted EBITDA of $869M, compared with $742M a year earlier. Growth across crude pipelines and gathering systems, a $43M recovery of revenue tied to a legacy shipper contract, and favorable inventory valuation effects supported the increase. Management also identified a $60M inventory gain that it expected to offset with hedge losses in the second quarter, so part of the quarter's result was timing-sensitive.
Natural gas remains the central expansion platform. First-quarter 2026 Interstate Natural Gas adjusted EBITDA was $519M, compared with $512M a year earlier, while Intrastate Natural Gas adjusted EBITDA was $437M versus $344M. The interstate result benefited from higher contracted volumes and rates on Panhandle Eastern, Trunkline, Florida Gas, and Transwestern. The intrastate result included approximately $100M from Winter Storm Burn.
Midstream adjusted EBITDA was $887M in the first quarter, compared with $925M a year earlier. Permian volumes increased 8% through new and upgraded processing plants, but lower NGL and natural gas prices and a prior-year $160M Winter Storm Uri revenue item weighed on the comparison. The segment still has operating leverage because management identified idle or available capacity in the Mid-Continent, Eagle Ford, Haynesville, Northeast, and Permian systems.
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The Hugh Brinson Pipeline is ET's clearest near-term flagship growth asset. The 400-mile system is designed to move 1.5 Bcf per day from west to east, is fully contracted from West to East, and reached commercial service in 2026. Management expected Phase I to reach full capacity by September 1, 2026, with Phase II adding compression in the first quarter of 2027.
Hugh Brinson matters because it turns ET's existing pipeline network into a larger header system rather than a standalone project. The system can connect multiple supply basins with downstream markets, while committed backhaul volumes add another source of throughput. Contracted capacity reduces the volume risk that typically accompanies a large pipeline build.
The project also illustrates ET's preferred commercial model. Long-term commitments provide a base of contracted revenue, while the broader network creates optionality around power generation, industrial demand, and future interconnections. The result is less glamorous than a technology launch, but pipelines tend to have longer useful lives than market narratives.
ET's innovation is primarily infrastructure-based. The company placed the Gateway NGL pipeline debottlenecking project into service during the first quarter of 2026, increased deliveries of Delaware Basin liquids to Mont Belvieu, and commissioned the Mustang Draw I processing plant with 275 MMcf per day of capacity. Mustang Draw II is also scheduled for service in the fourth quarter of 2026 with another 275 MMcf per day.
At Mont Belvieu, ET is building a 3 million-barrel ethane storage cavern to support its ninth fractionator and future export expansions. The cavern is scheduled for service in the second half of 2027, while the ninth fractionator is expected in the fourth quarter of 2026. At Nederland, the company extended most ethane export agreements into 2041, adding 10 years to existing contracts.
The integrated network is ET's durable advantage. A smaller operator can own a pipeline or a fractionator. ET can connect gathering, processing, transportation, storage, fractionation, and export infrastructure across multiple basins. Its first-quarter record for midstream gathering, NGL fractionation, NGL exports, and crude transportation shows the commercial value of that connectivity.
ET's supply chain runs from wellhead production to domestic demand and international exports. The company gathers and processes natural gas, moves NGLs to Mont Belvieu, fractionates the liquids, stores them, and delivers products to domestic customers or export terminals. Its crude network gathers and transports oil to refineries, storage sites, and export facilities.
Operational scale is visible in the project pipeline. Springerville Lateral is a 120-mile, 30-inch pipeline with expected capacity of 625 MMcf per day, backed by 20-year agreements and scheduled for the fourth quarter of 2029. Florida Gas Transmission's Phase 9 project is designed to add 525 MMcf per day through 90 miles of looping and new compression, with service expected in the fourth quarter of 2028.
The company is also adding connections for Oklahoma power plants totaling approximately 300 MMcf per day, with investment-grade counterparties supporting the contracts. A Texas intrastate agreement for the Nexus Hubbard Campus starts at approximately 150 MMcf per day, with service expected by the end of 2026. ET also signed an agreement supporting an Arkansas data center with approximately 150 MMcf per day of firm transportation service.
Execution is the central operating risk. ET raised 2026 organic growth capital guidance to $5.6B-$5.9B, and projects such as Desert Southwest, Florida Gas Transmission expansions, NGL storage, and Permian processing require construction, permitting, and customer commitments to progress together. The scale creates earnings power, but it also creates more places for a budget or schedule to slip.
The U.S. natural gas market is adding infrastructure where demand is concentrated. EIA reported that projects completed in 2025 added approximately 6.3 Bcf per day of U.S. pipeline capacity. About 85% of that capacity, or 5.3 Bcf per day, was dedicated to the South Central region, and approximately 65% of total new capacity was intrastate.
That geography fits ET's asset base. The South Central region links Permian and Haynesville supply with Gulf Coast LNG, petrochemical, power, and export demand. ET's Transwestern, intrastate Texas, NGL, and Gulf Coast systems give it exposure to each part of that chain.
NGL demand adds a second growth lane. ET's second-quarter 2026 NGL transportation volumes increased 13% year over year, while total NGL exports increased 25%. The fully subscribed Nederland expansion adds 240,000 barrels per day of ethane export capacity and 55,000 barrels per day of LPG capacity, providing a direct link between U.S. production and international buyers.
The market is also shifting toward power demand. ET has signed or developed projects for Oklahoma power plants, the Nexus Hubbard Campus, an Arkansas data center, and Entergy Louisiana facilities. Those projects turn electricity demand growth into contracted gas transportation demand, a useful bridge between the energy infrastructure and data-center investment cycles.
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ET serves producers, utilities, independent power plants, local distribution companies, industrial users, refiners, marketers, exporters, and large energy traders. Its customer base also includes power and data-center developers that need firm natural gas transportation to support electricity generation.
Contract duration is a key customer-quality measure. Springerville Lateral is backed by 20-year agreements. Florida Gas Transmission projects have 15- to 25-year agreements with anchor shippers. Entergy Louisiana has a 20-year binding transportation agreement for at least 250,000 MMBtu per day, with an option to increase its commitment to as much as 1 Bcf per day.
The customer profile is becoming more power-oriented. ET added four Oklahoma power plant connections totaling approximately 300 MMcf per day, entered a 150 MMcf per day agreement for the Nexus Hubbard Campus, and signed a 150 MMcf per day letter of intent for an Arkansas data center. The Oklahoma connections are supported by investment-grade counterparties, which strengthens the contracted-revenue profile.
ET competes with Williams Companies (WMB), Kinder Morgan (KMI), TC Energy, Enterprise Products Partners (EPD), Plains All American Pipeline (PAA), Enbridge, and regional operators. Competition in transportation and storage is based on location, available capacity, price, reliability, service, flexibility, and access to market hubs.
Williams and Kinder Morgan are major natural gas pipeline competitors. Enterprise Products Partners is especially relevant in NGL transportation, fractionation, storage, and Gulf Coast terminals. Plains, Enbridge, and Kinder Morgan overlap with ET in crude transportation, storage, and terminal markets. DT Midstream and smaller basin gatherers compete in selected regional systems.
ET's advantage is breadth rather than dominance in one narrow category. Its approximately 140,000-mile network, presence in 44 states, NGL export infrastructure, crude systems, and interests in Sunoco and USA Compression create a connected platform that is difficult to replicate. The trade-off is complexity, because the partnership must manage more commodities, projects, and regulatory jurisdictions than a focused pipeline owner.
Geopolitical disruption has increased the strategic value of U.S. energy infrastructure. During the first-quarter 2026 earnings call, management described a redirection toward U.S. LNG, NGL, and oil supplies following the Middle East conflict. The same discussion linked stronger demand with higher volumes and rates across ET's network.
Management also said the guidance midpoint was based on a conservative commodity price deck and that prices near first-quarter levels would support the high end of the 2026 guidance range. That statement supports the operating outlook, but the company itself identified approximately $300M of first-quarter outperformance as one-time in character. Investors should therefore separate recurring contracted growth from volatility-driven optimization gains.
Regulation remains a structural constraint. Interstate projects such as Desert Southwest and Florida Gas Transmission require FERC processes, while pipeline and terminal construction faces environmental review, route development, and community engagement. ET began the FERC prefiling process for Desert Southwest in March 2026 and expected to submit its formal certificate application in the fourth quarter of 2026.
Energy security also supports storage demand. IEA member countries maintain oil stocks equal to at least 90 days of net imports, while EU rules require at least 90 days of average daily net imports or 61 days of average daily inland consumption, whichever is greater. Those requirements reinforce the role of storage and terminal infrastructure during supply disruptions.
Debt stood at $68.6B versus just $1.0B of cash at June 30, 2026, leaving Energy Transfer with a C+ balance sheet despite strong operating momentum.
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Get Full Access →Second-quarter 2026 adjusted EBITDA jumped 31% year over year to $5.07B, showing broad strength across ET’s midstream and NGL businesses.
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Get Full Access →Management lifted full-year 2026 adjusted EBITDA guidance to $18.8B-$19.1B, signaling that recent operating gains are carrying into the outlook.
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Get Full Access →ET’s valuation earns a B, with the stock positioned around a $24 fair value against a business benefiting from contracted growth and income appeal.
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Get Full Access →The report’s Buy call is anchored by a $24 fair value, with upside tied to fully contracted projects like Hugh Brinson and continued EBITDA growth.
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Get Full Access →Energy Transfer has moved from a high-leverage infrastructure story toward a broader growth platform. The second-quarter 2026 results, the higher full-year EBITDA guidance, record NGL and crude volumes, Hugh Brinson's ramp, and new power-related contracts provide concrete evidence of operating momentum.
The investment is not a balance-sheet bargain. Debt is high, growth capital is substantial, and recent earnings include weather, hedging, inventory, and optimization effects. Even so, ET's network scale, contracted projects, export capacity, and exposure to U.S. power demand create a credible medium-term compounding path. A Buy rating is appropriate while the unit price remains below the report's $24.00 fair-value estimate and management continues converting its project backlog into cash flow.
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