WES Q2 2026 - Post-Call Earnings Update

Event: Quartr Q2 2026 event Retrieved: 2026-08-11T10:52:00Z Comparison mode: maximal Scorecard contract: v1

Consensus scorecard

• Consensus scorecard, bulleted equivalent (carried forward unchanged from the preliminary report for this event):
  • Revenue / total revenues and other: Quartr actual $1,224.719m against API Ninjas consensus $1,127.949m - Beat +$96.770m, +8.6%.
  • EPS / GAAP diluted per common unit: Quartr actual $0.99 against API Ninjas consensus $0.907 - Beat +$0.083, +9.2%.

Management and Q&A

• THE $250m GUIDANCE RAISE WAS BRIDGED COMPONENT BY COMPONENT, WHICH THE RELEASE DID NOT DO. Asked by Francina Kolluri (JPMorgan, appearing for Jeremy Tonet) to test her own decomposition, the CFO confirmed it: Brazos Delaware contributes the $100m referenced, a roughly $20 move in WTI against the original budget is worth approximately $80m of incremental commodity across all of 2026 using the company's published sensitivity, and the remainder comes from increased system throughput plus recovery performance at the plants. The preliminary's first open question was exactly this split.
• THE COMMODITY ASSUMPTION BEHIND THE RAISE WAS DISCLOSED. The CFO said second-half 2026 prices remain above what was modelled coming into the year but have recently MODERATED, and that guidance now uses an average oil price of $71 per barrel for the second half, producing a full-year average of approximately $77 per barrel.
• BRAZOS DELAWARE WAS SIZED IN FULL. The acquisition of Brazos Delaware II closed in mid-June for $1.6bn, funded with approximately $800m of cash and approximately $800m of WES common units struck at the volume-weighted average unit price at the time the agreement was signed. It is expected to generate approximately $100m of adjusted EBITDA in the second half of 2026 and approximately $15m-$20m of cost synergies over the coming quarters, primarily from general and administrative elimination and reduced operation and maintenance expense through supply chain efficiencies. Connection of the legacy Brazos system to the legacy WES system is expected to be complete by year end, which is what lets WES direct volumes to Brazos plants with spare capacity and offload fewer volumes externally.
• BRAZOS ACTIVITY IS RUNNING AHEAD OF UNDERWRITING. The CEO said a number of wells previously planned for 2027 have moved into the second half of 2026 across several customers on the Brazos acreage, and that WES would expect throughput above its initial underwriting assumptions. Asked by Gabe Moreen (Mizuho) about filling the spare processing capacity, he said the customer base there is "much more active than we expected and we underwrote in the transaction" and that the plant is "probably going to see that plant head towards being full pretty quickly," separate from the offloaded volumes being shifted onto it. He also said WES is "probably at capacity in terms of space at North Loving," so the next processing plant would likely go somewhere else, and that the processing stack is under review.
• PATHFINDER ECONOMICS WERE UPGRADED ON THE CALL AND QUANTIFIED FOR THE FIRST TIME. Asked by Gabe Moreen about contracting strategy beyond the Occidental anchor contract, the CEO said the base Oxy contract takes "a little less than a third of the capacity of the pipe," that total capital costs have been brought down from the original budget helped by land work that gained excess capacity and allowed a partial reroute, and that expected returns have risen approximately 500 basis points from high-single-digit to 10% toward closer to 15%, with an expectation of the 20% range as the pipe fills over the next year or so after it comes online. He put pipe capacity at 800,000 barrels per day, "easily expandable to over 1 million barrels a day," and described Pathfinder as becoming a header or loop for the whole integrated water system across New Mexico and Texas. The preliminary flagged that Pathfinder was described as under budget with no project cost or return disclosed.
• THE WATER CUSTOMER DYNAMIC WAS DESCRIBED. The CEO said the company's largest customers are getting very specific about where water is disposed, where it is moved and how it is tracked, that this is a growing challenge for producers and critical to overall oil and gas flow assurance, and that customers want investment-grade counterparties able to move water across the system in multiple directions. He said everything about the water business "is much better than we thought and has improved more quickly than we anticipated when we sanctioned this project," and that WES probably sees another large contract.
• BENEFICIAL REUSE HAS A STATED INTENT BUT STILL NO SANCTION, COST OR TIMELINE. Asked by Burke Sansiviero (Wolfe Research) how soon a standalone project could be sanctioned and how much capital could go to it, the CEO said WES is "working hard to sanction a commercial scale plant," credited the Aris acquisition with bringing a team and a technical advantage while describing WES as technology agnostic, positioned JIP2 as R&D to work out operating costs and find scaling opportunities that bring beneficial-reuse costs down, and said WES hopes "to be announcing something in the not-too-distant future in terms of commercializing that piece of the puzzle." No capital figure, capacity, cost or date was given, so the preliminary's uncertainty on this point stands.
• PER-UNIT MARGIN GUIDANCE WAS GIVEN FOR ALL THREE PRODUCT LINES, NONE OF WHICH IS IN THE RELEASE. Natural gas adjusted gross margin rose $0.03 per Mcf sequentially, is expected slightly lower in the third quarter as commodity prices moderate, and is guided to average approximately $1.30 per Mcf for 2026. Crude oil and NGLs adjusted gross margin rose $0.14 per barrel sequentially on higher Delaware Basin deficiency fees, is expected slightly lower in the third quarter, and is guided to $3.10-$3.15 per barrel for 2026. Produced water adjusted gross margin rose $0.06 per barrel sequentially on higher throughput, is expected slightly lower in the third quarter, and is guided to average approximately $0.91 for 2026, "especially if the crude oil strip for 2026 remains elevated."
• THROUGHPUT GUIDANCE WAS GIVEN BY BASIN AND PRODUCT. Portfolio-wide average year-over-year throughput is now expected up mid-single digits for natural gas and DOWN low double digits for crude oil and NGLs, with produced water up approximately 85% year over year, raised from an original expectation of approximately 80% and driven by the Aris acquisition plus legacy performance. In the Delaware Basin, natural gas is expected up low- to mid-teens percent and crude oil and NGLs up low single digits, with Brazos the primary driver of the improvement. In the DJ Basin, first-half outperformance on strong well performance and higher onloads from other midstream companies improves the outlook to a low-single-digit natural gas decline and a mid-single-digit crude and NGLs decline. Powder River throughput is expected down mid- to high single digits. Other natural gas assets are expected up mid single digits.
• A CURTAILMENT EPISODE AND ITS RESOLUTION WERE DISCLOSED. Certain customers curtailed Delaware Basin throughput during the second quarter because of negative Waha natural gas pricing, but the quarter was exited with NO curtailments as long-haul pipelines returned from maintenance and the GCX expansion and a pipeline the transcript renders as "Hugh Rinson" entered service. Waha pricing is expected to be less volatile through the rest of the year, particularly as a pipeline the transcript renders as "Latcom" comes online later this year.
• OPERATING COST GUIDANCE WAS GIVEN, AND IT IS A LARGE INCREASE. Second-quarter operation and maintenance expense rose approximately 8% sequentially on higher disposal and land fees tied to produced-water throughput and higher chemicals and treating expense. Full-year 2026 operation and maintenance expense is now expected to rise approximately 20%-25% year over year inclusive of both Aris and Brazos, which the CFO characterized as still a meaningful reduction on a combined-company basis. Third-quarter operation and maintenance expense is expected up in the high single digits on the full Brazos run rate, typical third-quarter maintenance and repair work, and higher utility costs. Pro forma for Brazos, WES now estimates it recovers approximately 60% of portfolio-wide utility costs from customers.
• LEVERAGE AND LIQUIDITY WERE DISCLOSED, WHICH THE RELEASE DID NOT DO. The company ended the quarter with more than $1.8bn of total liquidity and a trailing twelve-month net leverage ratio, pro forma for a full year of Brazos contribution, of approximately 3.15 times. The $700m ten-year senior note issuance in June priced at a 123 basis point spread to U.S. Treasuries, which the CFO said was the tightest ten-year spread for any WES senior note issuance in the partnership's history.
• CAPITAL SPENDING WAS EXPLAINED RATHER THAN JUST REAFFIRMED. The $850m-$1.0bn range is maintained with spending expected toward the high end, driven by new Delaware and Powder River expansion opportunities not contemplated in the prior forecast; specifically, the new Powder River gathering and processing agreements require incremental growth capital for expanded gathering facilities and additional compression, part of which falls in 2026. More than half of the 2026 capital program is directed to Pathfinder and North Loving II. Capital is expected to stay elevated through the third quarter before moderating in the fourth, ahead of in-service dates in the first and second quarters of 2027 respectively.
• THE POWDER RIVER AGREEMENTS WERE SIZED FURTHER. The approximately 270,000 dedicated acres contain over 1,000 remaining drilling locations and are backed by substantial multiyear minimum volume commitments. Those customers plan to increase activity in the back half of this year, driving volume growth as WES exits 2026 and again in 2027. No contract value, term or committed volume was disclosed.
• M&A FRAMEWORK RESTATED WITHOUT A NEW COMMITMENT. Asked about the inorganic opportunity set by Francina Kolluri and about basin focus by Burke Sansiviero, the CEO described "programmatic M&A" against four parameters - sustaining or growing the distribution, protecting the balance sheet and investment-grade ratings, diversifying the customer and ownership profile, and accretion on per-unit metrics, which he named as the critical one - and said the strong preference is always to grow organically at higher returns and lower execution risk. He said the Permian remains the key basin, that opportunities exist elsewhere, and that valuations outside the Permian "are just more reasonable, in terms of short-term metrics." No transaction, process or target was named.

Guidance and KPI clarification

• Guidance and KPIs, bulleted equivalent: full-year 2026 adjusted EBITDA guidance is $2.75bn to $2.95bn with a $2.85bn midpoint, distributable cash flow $2.05bn to $2.25bn with a $2.15bn midpoint, and free cash flow $1.1bn to $1.3bn with a $1.2bn midpoint. The $250m adjusted EBITDA midpoint increase decomposes into approximately $100m from Brazos Delaware, approximately $80m from a roughly $20 move in WTI against the original budget on the company's published sensitivity, and the remainder from higher system throughput and plant recovery performance. Guidance assumes a $71 per barrel average oil price in the second half and approximately $77 per barrel for the full year. Capital expenditure guidance of $850m to $1.0bn is maintained with spending expected toward the high end because of new Delaware and Powder River expansion work, over half of the program going to Pathfinder and North Loving II, and spending staying elevated through the third quarter before moderating in the fourth. Full-year operation and maintenance expense is expected up approximately 20% to 25% year over year including Aris and Brazos, with the third quarter up high single digits sequentially, and approximately 60% of portfolio-wide utility costs are recovered from customers pro forma for Brazos. Per-unit adjusted gross margins are guided to approximately $1.30 per Mcf for natural gas, $3.10 to $3.15 per barrel for crude oil and NGLs, and approximately $0.91 per barrel for produced water, each with the third quarter slightly below the second. Throughput is guided to mid-single-digit growth for natural gas, a low-double-digit decline for crude oil and NGLs, and approximately 85% growth for produced water, raised from approximately 80%. By basin, Delaware natural gas is up low to mid teens and crude and NGLs up low single digits, DJ natural gas is down low single digits and crude and NGLs down mid single digits, Powder River is down mid to high single digits, and other natural gas assets are up mid single digits. Net leverage was approximately 3.15 times on a trailing twelve-month basis pro forma a full year of Brazos, with more than $1.8bn of total liquidity. The distribution of $0.93 per unit was declared on 20 July for payment on 14 August, with the full-year target of at least $3.70 per unit unchanged against a $3.72 annualized run rate.
• Project detail stated on the call: the Powder River agreements cover approximately 270,000 dedicated acres containing over 1,000 remaining drilling locations, backed by substantial multiyear minimum volume commitments, requiring incremental gathering and compression capital partly falling in 2026. Pathfinder and North Loving II remain on schedule for first-quarter and second-quarter 2027 in-service respectively. JIP2 is delivering approximately 1,000 barrels per day of reclaimed fresh water, roughly ten times JIP1, and is positioned as R&D toward sanctioning a first commercial-scale facility.
• Financing detail stated on the call: the June issuance of $700m of ten-year senior notes priced at a 123 basis point spread to U.S. Treasuries, described as the tightest ten-year spread in the partnership's history.

Updated neutral analysis

• What the call resolved from the preliminary: the split of the $250m adjusted EBITDA guidance raise between acquisition, commodity price and throughput; the Brazos Delaware purchase price, funding mix, second-half earnings contribution and synergy target; the commodity price assumption underpinning the raise; the per-unit margin guidance across all three product lines; throughput guidance by basin and product; the operating cost trajectory; net leverage and liquidity; and Pathfinder's capacity, contracted share and expected returns.
• What the call did NOT resolve: the distribution coverage ratio, which is still not stated anywhere; the $266.9m adverse swing in the six-month "change in other items" cash flow line to a $(188.3)m use; the composition of the 34.2% six-month increase in other liabilities and the 24.4% increase in other assets; the fixed-recovery natural gas processing contracts' share of natural gas adjusted gross margin; the movement in the Occidental subsidiary's limited partner interest in WES Operating; and any sizing at all for the commercial-scale beneficial reuse facility. None of these were asked about.
• The guidance bridge is the most useful disclosure on the call and it changes the read on quality. Of the $250m midpoint increase, approximately $100m is acquired, approximately $80m is commodity price, and the residual of roughly $70m is operational - throughput and plant recoveries. Roughly a third of the raise is therefore price, which management itself flagged as having moderated recently, and the second-half assumption of $71 per barrel is below the first half implied by the approximately $77 full-year average.
• The cost line is where the acquisitions show up most visibly. Full-year operation and maintenance expense is guided up 20% to 25% year over year, the second quarter was already up 8% sequentially and 27% year over year on a reported basis, and the third quarter is guided up high single digits again. Management frames this as a reduction on a combined-company basis, which is a different comparison than the reported one and is not quantified.
• The water business is the growth engine on management's own account, and the numbers support it. Produced water throughput guidance was raised to approximately 85% year-over-year growth, produced water adjusted gross margin rose fastest of the three product lines sequentially, and Pathfinder's expected return was raised from high-single-digit-to-10% toward 15% with a path to the 20% range. Against that, the produced water per-barrel margin guide of approximately $0.91 is explicitly conditioned on the crude oil strip staying elevated.
• The 2027 setup is stronger than the 2026 one by design. Pathfinder and North Loving II both come online in the first half of 2027, the Powder River agreements begin driving volume as WES exits 2026, Brazos systems connect at year end, and Brazos customer activity is running ahead of underwriting. The corollary is that 2026 carries elevated capital at the high end of the range, a declining DJ Basin in the second half, and Powder River throughput still down mid- to high single digits for the year.
• The distribution coverage question the preliminary raised is still open and the call did not close it. Free cash flow after distributions was negative $111m in the quarter. Full-year free cash flow guidance of $1.1bn-$1.3bn against a distribution run rate of $3.72 per unit on roughly 413 million units outstanding implies roughly $1.5bn of annual distributions, so the relationship between the guided free cash flow and the distribution was not addressed on the call and is not resolved here.
• Management's 12%-14% total annual equity return framing, and its statement that 2026 should produce "well above 14%," are the company's own forward characterizations of its equity, restated from prior communications. They are recorded here as management statements and are neither adopted nor evaluated.
• The scorecard is unchanged. Both rows carry forward from the preliminary. Nothing on the call restated, corrected or contradicted total revenues and other of $1,224.7m or diluted net income per common unit of $0.99.

Market context and limitations

• SCOPE OF TRANSCRIPT READ: the Quartr transcript for event 662219 is complete and not live. All 62 paragraphs were read - the full prepared remarks and the entire Q&A. The Q&A ran to three analyst lines: Gabe Moreen (Mizuho), Francina Kolluri appearing for Jeremy Tonet (JPMorgan) and Burke Sansiviero (Wolfe Research). Speaker names and roles were carried on the transcript records, so attributions in this report are the transcript's own.
• Management referenced an accompanying slide deck and a published commodity price sensitivity within it (Quartr document 3969601). The slide deck itself was NOT read, and the sensitivity table behind the approximately $80m commodity contribution was therefore not verified. Any figure that appears only on a slide and was not spoken is absent from this update.
• TWO PIPELINE NAMES ARE REPRODUCED AS THE TRANSCRIPT RENDERS THEM AND MAY BE TRANSCRIPTION ARTEFACTS: "Hugh Rinson" and "Latcom." Both appear in a passage about Permian long-haul natural gas takeaway relieving negative Waha pricing. No attempt was made to correct them to any actual project name, because doing so would substitute an assumption for the source.
• The transcript renders one CFO passage as "our 2026 adjusted EBIT range." The figures given in that sentence are the adjusted EBITDA figures stated everywhere else on the call and in the release, so it is treated here as adjusted EBITDA.
• Management's spoken figures are rounded relative to the release - adjusted EBITDA "$737 million" against $736.5m, distributable cash flow "$537 million" against $537.2m, free cash flow "$264 million" against $263.6m, operating cash flow "$535 million" against $534.7m, net income attributable to limited partners "$395 million" against $394.9m. Where a release figure exists it is used; spoken-only figures are reported as spoken.
• API Ninjas price snapshot for WES returned $47.40 on NYSE with volume of 711,987, retrieved 2026-08-11T10:50:19Z. That is a pre-market quote three trading days after the call, taken before the US equity session opened, against the $46.15 post-close quote recorded in the preliminary on 2026-08-05. It is not a measured reaction to the call and no reaction is characterized here.
• Every figure in the consensus scorecard is carried forward from the preliminary report for this event and was not recalculated. The preliminary's disclosed limitations stand in full, including that the release's extracted statements lost column alignment and every figure was assigned to its period by arithmetic reconciliation, and that Western Midstream publishes no adjusted per-unit earnings measure, so GAAP diluted net income per common unit is the only per-unit basis available for the scorecard.
• The implied annual distribution of roughly $1.5bn cited in the analysis is calculated locally from the $3.72 annualized run rate and the 413,172,388 common units outstanding at 30 June disclosed in the release. The company does not state it, it excludes general partner and noncontrolling interests, and it takes no account of unit count changes over the year.
• Adjusted EBITDA, distributable cash flow, free cash flow, adjusted gross margin and net leverage are non-GAAP or company-defined measures. The company did not define net leverage on the call and the release does not present it.
• This report is factual only. It contains no ranking, no recommendation, and no view on the security.