Energy Transfer LP (ET) | The Buildout — AI Infrastructure
The Verdict
Energy Transfer is a diversified midstream partnership that moves natural gas, NGLs, crude oil, and refined products from supply basins to domestic and export markets. In the AI buildout, it is the physical gas-delivery layer: data centers and gas-fired power plants need firm fuel supply, and Energy Transfer builds laterals, meter stations, and pipelines to connect them.
| Market Cap | — |
| Revenue (TTM) | $89.4B |
| Revenue Growth | +8.9% |
| EBITDA Margin (TTM) | 17.3% |
| Net Debt | $70.1B |
| Earnings Beats | 1 of 7 |
| P/E (TTM) | — |
| EV/EBITDA (TTM) | — |
What We Like
- Q1 2026 adjusted EBITDA was $4,937M, up 20.5% from $4,098M, on record gathering, fractionation, export, and crude volumes.
- Management raised 2026 adjusted EBITDA guidance to $18.2B–$18.6B, a midpoint increase of $750M.
- Contracted over 6 Bcf/d of pipeline capacity with demand-pull customers in the last year; named commitments include Oracle at ~900,000 Mcf/d and Nexus at ~150 MMcf/d.
- 2026 organic growth capital raised to $5.5B–$5.9B; projects carried long-term contracts and management expects mid-teen returns.
- The storage system is part of the pitch for ~99.99% reliability for data centers.
What We’re Watching
- Q1 2026 included roughly $300M of the $500M internal-plan beat called one-time, plus a ~$100M winter storm benefit and a $60M crude inventory gain expected to mostly reverse in Q2.
- Management calls NGL transportation and fractionation its most competitive segment.
- Panhandle FERC rate litigation remains active; Desert Southwest still needs a FERC certificate with the formal application not expected until Q4 2026.
- Lake Charles LNG went unmentioned on the Q1 call, and the Enbridge DAPL light Canadian crude project's prior mid-2026 FID timing was not reaffirmed.
The thesis is strengthening on contract momentum and a raised guidance path, but the quarter's composition tempers the read. Management added named power and data-center deals, raised EBITDA and capex guidance, and pointed to multi-year contracted cash flow; at the same time, the quarter leaned on weather and commodity-linked gains. The open question is whether the 15-state power and data-center discussion set converts into signed contracts at a pace that extends the demand-pull runway.
Earnings
Q1 2026, reported May 5, 2026: revenue $27,771M, gross margin 23.8%, and adjusted EBITDA $4,937M versus $4,098M a year earlier. Results included record midstream gathering, NGL fractionation, NGL export, and crude oil transportation volumes.
| Metric | Q1 FY2026 | Q4 FY2025 | Q1 FY2025 | YoY |
|---|---|---|---|---|
| Revenue | $27.8B | $22.4B | $21.0B | +32.1% |
| Gross margin | 23.8% | 25.8% | 19.7% | +410bps |
| EBITDA | $4.6B | $3.5B | $3.9B | +18.4% |
| EPS | $0.36 | $0.40 | $0.38 | −5.4% |
| Distributable Cash Flow, as adjusted | $2,704M | n/a | $2,307M | +17.2% |
We had an incredible first quarter. We beat our internal plan by approximately $500 million and achieved our full-year optimization earnings target.— Dylan Bramhall, CFO, May 5, 2026
Management tone: Management's tone shifted to confident and forward-leaning versus the prior quarter. The Q1 call described an 'incredible first quarter,' praised the asset base as 'incredibly well-positioned,' added several new projects, and layered in a geopolitical framing of U.S. energy redirection. Q&A was unusually thin with only two analyst questions.
Management Guidance
On May 5, 2026, management raised 2026 adjusted EBITDA guidance to $18.2B–$18.6B from $17.45B–$17.85B, and 2026 organic growth capex to $5.5B–$5.9B from $5.0B–$5.5B. The midpoint assumes a conservative commodity price stack; CFO Dylan Bramhall said prices near current levels would push results to the high end and potentially above. A Q2 2026 press release on August 4, 2026 said ET updated 2026 guidance, but the supplied digest truncates the adjusted EBITDA figure.
Trajectory
Revenue is accelerating: Q1 2026 revenue of $27,771M rose 23.9% sequentially and 32.1% year over year from $21,020M. Gross margin expanded to 23.8% from 19.7% a year earlier, while EBITDA margin compressed to 16.4% from 18.4% as Sunoco's lower-margin refined-product sales mix grew. The quarter's record volumes and adjusted EBITDA gains included weather and commodity-linked benefits that management expects to partly reverse.
The Model
The model projects FY+1 revenue of $106,800M and EBITDA of $18,156M at a 17.0% margin. FY+2 rises to $112,100M revenue and $19,763M EBITDA at a 17.63% margin. Near-term is anchored by management's raised 2026 adjusted EBITDA guidance and the contracted project schedule; FY+2 reflects the multi-year in-service ramp across Hugh Brinson, Bayou Bridge, FGT Phase IX, and Desert Southwest.
| Metric | FY2025 | Next FY (E) | Following FY (E) |
|---|---|---|---|
| Revenue | $82.6B | $106.8B | $112.1B |
| YoY Growth | — | +29.3% | +5.0% |
| EBITDA | $14.8B | $18.2B | $19.8B |
| EBITDA Margin | 17.9% | 17.0% | 17.6% |
Projections are the median of 5 independent model runs. The model’s revenue sits 1.0% below analyst consensus.
On May 5, 2026, management raised 2026 adjusted EBITDA guidance to $18.2B–$18.6B from $17.45B–$17.85B, and 2026 organic growth capex to $5.5B–$5.9B from $5.0B–$5.5B. The midpoint assumes a conservative commodity price stack; CFO Dylan Bramhall said prices near current levels would push results to the high end and potentially above. A Q2 2026 press release on August 4, 2026 said ET updated 2026 guidance, but the supplied digest truncates the adjusted EBITDA figure.
What Could Go Right — and Wrong
- The 15-state power-plant discussion set converts into signed contracts, adding to the 6 Bcf/d already contracted and the named Oracle, Nexus, Entergy, and Oklahoma deals.
- Project completions stay on schedule: Hugh Brinson Phase 1 in Q4 2026, Mustang Draw I/II, Frac IX, and Nexus by end of 2026, Bayou Bridge in Q1 2027, FGT Phase IX in Q4 2028, and Desert Southwest by 2029.
- Export strength persists, with ethane contracts extended into 2041 and the June 2026 Nederland expansion fully subscribed.
- Commodity volatility and optimization stay recurring, as management says happened in five of the last eight years.
- Prices near current levels push 2026 adjusted EBITDA to the high end or above the full-year guidance range.
- Q1 one-time benefits reverse: the one-time portion of the $500M beat, the ~$100M winter storm benefit, and the $60M crude inventory gain expected mostly reversed in Q2.
- Competition in NGL transportation and fractionation persists, since management calls it the most competitive segment.
- FERC or litigation outcomes delay Desert Southwest, the Panhandle rate case, or MLM income-tax policy.
- Steel tariffs and a trade war raise growth project costs and maintenance capex.
- Project execution slips on the larger capital program as equipment lead times stay constrained.
Looking Ahead
The next 12 months are about converting contracted projects into in-service assets. Near-term milestones include Mustang Draw I full service in June 2026, two remaining Oracle laterals in mid-2026, Hugh Brinson early gas in Q3 2026, and Hugh Brinson Phase 1, Mustang Draw II, Frac IX, and Nexus all slated for 2026. Bayou Bridge adds early 2027 capacity. Desert Southwest's formal FERC certificate application in Q4 2026 is the key regulatory gate.
- Mid-2026Two remaining Oracle laterals — Lateral completions test data-center gas contract execution.
- Q3 2026Hugh Brinson early gas — Early gas flows before Phase 1; tests Permian egress timing.
- Q4 2026Desert Southwest FERC application — Formal certificate application expected; largest project permitting gate.
- Q4 2026Hugh Brinson Phase 1 — Full phase in service; contracted west-to-east volumes ramp.
- End of 2026Nexus Hubbard AI campus — Initial ~150 MMcf/d ramps; tests AI campus gas supply.
- Q1 2027Bayou Bridge crude expansion — Expansion complete; capacity up to ~600,000 bpd.
Financials
Annual Summary
| Metric | FY2024 | FY2025 | TTM | YoY |
|---|---|---|---|---|
| Revenue | $82.7B | $82.6B | $89.4B | -0.1% |
| Gross Margin | 19.0% | 21.6% | 22.9% | +260bps |
| EBITDA | $14.3B | $14.8B | $103.9B | +3.2% |
| EBITDA Margin | 17.3% | 17.9% | 17.3% | +56bps |
| Net Income | $4.8B | $4.9B | $4.8B | +1.8% |
| Free Cash Flow | $7.3B | $3.8B | $29.9B | — |
| Net Cash | — | — | — | — |
Key Ratios (Trailing)
- P/E TTM—
- EV/EBITDA TTM—
- EV/Revenue TTM—
- Price/FCF TTM—
- Gross Margin (TTM)22.9%
- EBITDA Margin (TTM)17.3%
- Net Margin (TTM)5.4%
- ROIC7.5%
- FCF Conversion23.6%
- SBC / Revenue0.1%
The Company
The 10-K describes Energy Transfer as one of the largest diversified midstream energy companies in the U.S. It moves natural gas, NGLs, crude oil, and refined products from supply basins to domestic and export markets. In the AI buildout, it supplies the firm gas transportation and storage that power plants and data centers need for reliable electricity.
The network spans roughly 12,200 miles of intrastate gas pipelines and ~24 Bcf/d capacity; about 20,090 miles of directly owned interstate pipelines with ~20.1 Bcf/d capacity; over 18,000 miles of crude pipelines; and Mont Belvieu fractionation capacity of 1.15 MMBbls/d. It uses joint ventures for major pipelines, including FGT with Kinder Morgan, SESH with Enbridge, Bayou Bridge with Phillips 66, and Enable South Central with CVR Energy.
Business Segments
Competitive Landscape
Energy Transfer is described in its filings as one of the largest diversified midstream energy companies, with management claiming an 'unparalleled ability' to move energy from major supply basins to markets. The source material names Kinder Morgan, Enbridge, Phillips 66, and CVR Energy as both competitors and joint-venture partners, and management acknowledges NGL transportation and fractionation is its most competitive segment.
- Kinder MorganJV partner in Citrus, which owns FGT 50/50; competitor.
- EnbridgeJV partner in SESH and on the DAPL light Canadian crude project; competitor.
- Phillips 66JV partner/competitor; joint owner of Bayou Bridge Pipeline.
- CVR EnergyJV partner/competitor; joint owner of Enable South Central Pipeline.
Supply Chain
Energy Transfer sits between producers and end demand, moving gas and liquids through pipelines, storage, processing, and export terminals.