ET Q2 2026 - Post-Call Earnings Update

Event: Quartr Q2 2026 event Retrieved: 2026-08-04T21:00:00Z Comparison mode: maximal Scorecard contract: v1

Consensus scorecard

Carried forward unchanged from the event's preliminary report. Nothing on the call revised a reported actual.

Management and Q&A

• The call filled the single biggest gap in the preliminary: segment-level adjusted EBITDA. Tom Long, introduced by the operator as CEO, walked all five large segments with prior-year comparisons and named the specific drivers behind each (table below). The preliminary flagged that the release pages reviewed carried no segment table; that uncertainty is now resolved for the five segments Long quantified.
• Dylan Bramhall gave an explicit bridge for the guidance raise: the Q1 raise of $750m was "approximately $600 million in Q1 results and $150 million from just stronger performance that we saw continuing through the balance of the year," and this quarter's raise is "another $550 million," of which the majority is "strong beats across almost all segments this quarter. Midstream, Intrastate, Crude were all about $100 million, roughly beats, and NGL, over $200 million."
• Bramhall was direct that the back-half plan does not assume the first-half commodity backdrop repeats: "the volatility we've seen, the wider spreads, the higher commodity prices that we all saw happen through Q1 and Q2. We don't really have much of that in our plan for the back half of the year." Asked to confirm, they agreed the revised range is achievable without a volatility uptick and that persisting volatility would be additive.
• Mackie McCrea attributed the first-half outperformance to asset flexibility rather than to a single price move: "the war had a lot to do with it," alongside weather, with the point being the ability "to chill less ethane, more ethane, more propane, more butane" and to move gas "west to east to west, from all major hubs." Several analysts congratulated McCrea on their retirement; no succession detail was given on the call.
• Two specific hedge/inventory timing items were disclosed that do not appear in the preliminary. NGL and refined products results "included gains related to our NGL refined products inventory hedges, $27 million of which we anticipate will be offset in the fourth quarter of this year." Separately, a Q1 benefit "of approximately $60 million related to our crude inventory value" was "offset by hedge losses in the second quarter" inside the crude segment.
• On the Permian gas backdrop, McCrea said Waha basis narrowed "quicker than we thought" and framed Hugh Brinson as the cause: "There's a lot of pent-up volume, a lot of shut-in gas, a lot of ducts to bring online, and producers have been holding back. This is really going to unleash production in a big way." They referenced Permian takeaway going from "a Bcf growing to maybe 4.5 Bcf by the first quarter of next year," including a competitor line.
• On Y-grade recontracting, Adam Arthur said contracts are being signed at market rates after industry capacity additions, but "We do believe that we've seen the bottom of those rates and that we expect going forward that all additional contracting will be at higher rates." That is a forward view, not a reported rate.
• On the bear case that turbine lead times and permitting are slowing data-center gas demand, Arthur was flat: "We're just not seeing the slowdown," adding that customers are "pivoting and looking more to where they're already building, and they're already welcome versus new greenfield sites."
• On ERCOT interconnection-queue risk, McCrea said "if not all, the vast majority of the power plant data centers we do are behind the meter," which they characterized as making the roughly 2,000 ERCOT interconnection requests "kind of irrelevant to our customers." Long confirmed the same framing.
• On DAPL and Mainline 2, Arthur conceded a miss on timing: "what maybe we underappreciated was the regulatory complexity that's going on within Canada right now," pointing to back-half clarity and USMCA. They reiterated the previously announced Southern Illinois Connector moving 100,000 barrels a day of Canadian heavy for 15 years on the ECHO line, and said conversations with Bakken producers are encouraging.
• On the Green Chile line serving Oracle's Project Jupiter, Arthur declined specifics and pointed to ongoing work with FERC and BLM. McCrea characterized the opposition as data-center-directed rather than pipeline-directed and said the project may be "delayed a little bit from where we first anticipated." They said they do not expect similar challenges on Desert Southwest.
• No analyst asked about, and management did not address, the $396m of unrealized commodity risk-management gains removed in the adjusted EBITDA reconciliation, the July junior subordinated note issuance, or the two differing maintenance capex figures in the release. All three were flagged in the preliminary and remain open.

Guidance and KPI clarification

• Guidance shape: management framed the raised range as achievable on base business alone, with the high end contingent on commodity volatility persisting. Bramhall: "with some of this volatility, we can very easily achieve that high end of the guidance range."
• Project timing is back-half and 2027 weighted. Mustang Draw II and Frac IX both arrive late enough that management explicitly limited their 2026 contribution and pointed to 2027.
• Returns discipline was addressed directly against the higher capex run rate. Bramhall: "we're not by any means lowering our return threshold. In fact, I think when we look at these projects, our return threshold's probably going up because the opportunity set is just so great."
• Segment contributions from Sunoco and USA Compression were not quantified on the call; the five segments above are the only ones broken out.

Updated neutral analysis

Factual bullish evidence from the call:

• The guidance raise was decomposed rather than asserted. Bramhall attributed the $550m increase to roughly $100m beats each in Midstream, Intrastate and Crude and over $200m in NGL, which is consistent with the segment table management walked in prepared remarks.
• The back-half plan carries little assumed commodity volatility, per Bramhall. If accurate, that means the raised range does not require a repeat of the first-half spread environment, and the preliminary's uncertainty about how much of the raise rests on spreads versus base business is answered in favor of base business.
• Hugh Brinson reached commercial service ahead of the prior schedule and management says Phase II will come in under budget. The Intrastate segment already booked ~$17m from commissioning volumes, and the bulk of Phase I contract economics does not start until 1 January 2027, so that contribution is still ahead.
• Contracted, long-dated volume was added on both sides of the business: ~300,000 bpd of Y-grade transport/fractionation into the 2030s, 100% of the Nederland ethane export expansion committed into the 2040s, and two Texas customers upsizing existing gas contracts by a combined 100 MMcf/d.
• Management pushed back on the data-center slowdown thesis with a structural argument, not just optimism: the vast majority of their power-plant data-center projects are behind the meter, insulating them from ERCOT interconnection queues.
• Permian NGL takeaway is roughly 95% utilized and Mont Belvieu fracs were fully utilized in the quarter, which supports the case that Frac IX and the Mont Belvieu expansions fill rather than sit idle.

Factual bearish evidence from the call:

• Management identified two quantified timing benefits that reverse or have already reversed: $27m of NGL inventory hedge gains expected to be offset in Q4 2026, and a Q1 crude inventory benefit of ~$60m offset by hedge losses inside the Q2 crude segment. Neither is a going concern, but both confirm mark-to-market and inventory timing are moving segment results in both directions.
• The largest single stated driver of the Intrastate beat, ~$113m from wider basis differentials, is a spread outcome, not a volume or fee outcome. Wide Waha basis is exactly what McCrea then said Hugh Brinson is eliminating: "Hugh Brinson has unleashed it." The same asset that adds contracted capacity narrows the spread that produced part of the quarter's beat.
• Crude's $106m of "favorable market conditions" includes Strategic Petroleum Reserve activity, which is policy-driven and not a recurring commercial contract.
• The capital program grows rather than tapers. Long said visibility supports "$5 billion, $5 billion plus all the way out through 2029." No funding mix, equity issuance, retained cash or incremental leverage plan was discussed, and the preliminary's funding-mix question is unanswered. The July $1.75bn junior subordinated note issuance at 6.550% and 6.700% was not mentioned on the call.
• The $396m of unrealized commodity risk-management gains stripped out in the adjusted EBITDA reconciliation, the single largest quality-of-earnings item flagged in the preliminary, went entirely unaddressed by both management and analysts.
• Mainline 2 slipped on management's own account, with Arthur conceding an underappreciation of Canadian regulatory complexity, and the Green Chile line serving Oracle may be delayed. Both are demand-side projects management had previously presented as advancing.

Investor-relevant uncertainty:

• The durability of the base-business step-up is untestable this quarter. Management says the back-half plan excludes first-half volatility benefits, but the segment drivers they disclosed for Q2 are substantially spread-, price- and arbitrage-linked. Whether the raised guide is genuinely fee-based will only be visible when Q3 prints against a narrower Waha.
• Hugh Brinson's contracted economics are staged and largely begin 1 January 2027. The 1.5 Bcf/d by 1 September date is a capability date, not a flowing-volume commitment, and management conditioned it on commissioning continuing "as scheduled."
• Growth capex at $5bn+ per year through 2029 against a stated 4.0x–4.5x leverage target and 3%–5% distribution growth implies a funding path the call did not describe.
• Y-grade rate direction is a management forecast. "We've seen the bottom of those rates" is a view, and management simultaneously acknowledged that industry capacity was added.
• SUN and USAC contributions to consolidated adjusted EBITDA were not disclosed on the call, so the full composition of the $5,066m still cannot be reconstructed from the transcript alone.

Market context and limitations

• API Ninjas snapshot from the preliminary: ET $20.53 on NYSE, volume 3,412,650, retrieved 2026-08-04T14:12:43Z (10:12 a.m. ET). The call was held the same morning after a pre-market release. That single intraday quote is not a measurement of the reaction to the call, and no post-call quote is included in this update.
• The full Quartr transcript for this event was read in its entirety: 96 paragraphs covering the operator introduction, complete prepared remarks and the complete Q&A through the closing statement. No section is missing or truncated.
• Automatic speech transcription introduces several garbles. Two analyst turns carry no speaker attribution in the Quartr feed (identified in context only as an analyst appearing for Julien Dumoulin-Smith of Jefferies). One prepared-remarks sentence reads "Burke recently completed six in-person and two virtual scoping meetings," where the subject appears mis-transcribed. Arthur's recontracting answer contains a dropped word ("We're extremely that we made year-to-date on recontracting"). McCrea self-corrects Hugh Brinson Phase II timing from "mid-second quarter" to "mid-first quarter" within the same sentence; the corrected figure is used above.
• One LNG demand figure is garbled beyond safe use. McCrea said projections show LNG demand "growing to early 2030s, 2031 to 2036 Bcf. That's about a 16 Bcf growth." The numbers and units in that sentence are internally inconsistent as transcribed, so no LNG demand figure is carried into this report.
• Arthur's Q&A reference to signing 300,000 barrels a day of Y-grade deals says "in the last quarter," while the prepared remarks place the same signings in the second quarter. The prepared-remarks framing is used above.
• All segment adjusted EBITDA figures are stated by management as approximate, and all project dates, capital figures and guidance are forward-looking management statements rather than reported results. Segment figures should be checked against the release MD&A and the supplemental presentation before being relied on precisely.

Sources

• Quartr transcript and prepared remarks
• Quartr Q2 2026 earnings release
• Quartr supplemental presentation
• Preliminary report