Energy Transfer's Quarter of Quiet Substitutions

Guidance up $850 million for a third straight quarter, a $2.6 billion Permian bolt-on — and the LNG megaproject that vanished from the script entirely

ET · Earnings Call · 2026-11-03

The number that keeps repeating

Energy Transfer's third quarter was a $5 billion EBITDA quarter against roughly $3.8 billion a year earlier, with distributable cash flow of about $2.5 billion versus $1.9 billion. Full-year guidance went to $19.7–19.9 billion, up $850 million at the midpoint from guidance issued just three months ago. Strip out the approximately $285 million of previously disputed natural gas purchases recognized against a downstream customer in the fourth quarter, and the raise is still large. But the mechanism is what matters. Tom Long opened the same way he has for three quarters running: “For the third consecutive quarter, we captured meaningful upside from market volatility reflecting the quality of our diversified asset footprint.” — Thomas E. Long, Senior Management · 2026-11-03 That phrase, market volatility, has hardened from an excuse into a line item. Dylan Bramhall put a number on it. The plan historically assumes a couple hundred to four hundred million dollars of optimization; the realized run rate has been “probably more than $600 million to $700 million range a year. But we do not always know exactly where it is coming from... We are looking at something probably closer to $1.5 billion across this year.” — Dylan A. Bramhall, Senior Management · 2026-11-03 Back in May the same CFO was describing a $500 million beat of internal plan in the first quarter, “about $300 million would probably be considered one-time” — Dylan Bramhall, CFO · 2026-05-05 — and conceding it happens almost every year. Three consecutive beats is no longer a one-time anything. It is a business with an embedded, under-modelled trading and optimization book sitting on top of a toll road.

What stopped being said

The loudest thing on this call was an absence. For five straight quarters, Lake Charles — the LNG project — dominated the Q&A. Every analyst asked about it. Mackie McCrea set an explicit bar in November: “Yes, we will not proceed with LNG until we have secured 80% of equity partners similar to ourselves.” — Marshall McCrea, Senior Management / Executive · 2025-11-06 This quarter: not one mention in prepared remarks, not one question in Q&A. The capital that would have gone into a Louisiana liquefaction train is instead being committed at a pace nobody expected a year ago — roughly $3.9 billion of organic growth capital through nine months, $5.4–5.6 billion for the full year, and about $7 billion for 2027, which Bramhall called “probably the high watermark as we see it right now” — Dylan A. Bramhall, Senior Management · 2026-11-03 before stepping back to $5 billion-plus for several years. Where it went is legible. The South Mississippi pipeline reached FID: 215 miles, 1.2 Bcf/d, roughly $1.6 billion, 51% owned and operated, 2030 in service, backed by 20-year demand-based firm transportation. The Vaquero acquisition — $2.625 billion in cash and units, ~300 miles of Delaware Basin gathering and three cryogenic plants at 675 MMcf/d — was struck at roughly 8.5x 2027 estimated EBITDA, falling below 7x by 2029. Frac X, a tenth Mont Belvieu fractionator at 200,000 barrels a day, was sanctioned. So was Bear II. This is not a company that abandoned growth; it is a company that swapped a capital-heavy, equity-partner-dependent export project for a conveyor belt of small, bankable, integrated ones.

Demand pull, with a credit department attached

The other building block is demand-side contracting. Since the start of 2025, ET has signed over 9.5 million MMBtu per day of agreements with hyperscalers, data centers and power plants. This quarter added a 250,000 MMBtu/d, ten-year firm transportation agreement with an A-rated hyperscaler tied to the Crusoe AI campus in Abilene, and two Missouri power plant deals at roughly 150,000 Mcf/d. The phrasing is deliberate: demand pull customers, not supply push. And unlike the crude-segment contracts Jean Ann Salisbury flagged as still travelling at spot rates, these are long-dated. Adam Arthur was unusually specific about counterparty risk, which matters when the customer is a shell entity behind a $50 billion campus:

We are generally making sure that we are contracting through to an investment grade counterparty. And so that can take many different forms... generally, we are getting some form of parental guarantee for the contract value or a large portion of the contract value, so that we are protected upstairs. In the few cases where we have done something with non-investment grade counterparties, generally several years' support... through an LC or a surety bond.
Adam Arthur, Senior Management · 2026-11-03

This is the same wave every utility on the tape is now describing — large load interconnections at Xcel, Talen, Pinnacle West, PPL, Portland General. ET's specific edge is that most of these interconnects are two, three, eighteen miles from existing pipe, so the marginal capital is trivial and the fee is not. The data center demand is consensus; the low-capital lateral is the company-unique part.

The valuation argument nobody wants to have on the record

Mackie McCrea is stepping aside as co-CEO in January, leaving Tom Long in sole command, and his farewell included the least corporate sentence of the quarter:

I am always puzzled by why we trade as poorly as we trade compared to our competitors. It makes no sense. We look at our interest rate and intrastate pipeline network unmatched by far by anybody in the industry.
Marshall S. McCrea, Senior Management · 2026-11-03

The numbers give him some cover and some rope. Trailing price to net income of 9.4x and 13.0x free cash flow are cheap against a market at cyclical highs. Operating income reached $3.6 billion in the last reported quarter, up 55% year over year, on revenue of $34.3 billion. The counterweight is the balance sheet: effective net cash of −$67.4 billion against $3.6 billion of quarterly operating income — roughly 19 turns. Against that, interest coverage of 3.8x, up 43% year over year is the whole bull case in one line: leverage is high but the denominator is growing faster.

What to watch next

Three things. First, the give-back: about $100 million of NGL marketing margin and $100 million of crude margin are expected to reverse over the next two quarters as derivative losses realize — watch whether the fourth quarter still clears the raised bar. Second, Vaquero's close in mid-fourth quarter and whether the multiple actually compresses toward 7x as the Delaware processing capacity fills; that is the test of whether this is a bolt-on or an overpay. Third, the South Mississippi binding open season — Mackie's pipeline network story depends on backhauling up to 2 Bcf/d from Florida Gas into Louisiana LNG and industrial demand, and final line sizing will tell you how much of that is real. The units, for what it is worth, have done nothing: up about 2% over 90 days, sitting 5.8% below a September high, flat since May. A company that raised guidance three quarters in a row, sanctioned four projects, bought a Delaware gatherer and quietly retired its most-talked-about megaproject got a two percent tape for its trouble. That gap — between what management is now building and what the market is paying for — is the actual story here.