Western Midstream (WES) Q3 2026 earnings review
Western Midstream moves record gas volumes, but project spending climbs
Western Midstream pumped record volumes of gas and water through its pipelines, but lower oil prices and rising construction bills weighed on cash generation. The pipeline operator's Adjusted EBITDA grew 12% from a year ago to $708 million, though it slipped 4% from last quarter as commodity-linked margins cooled. Chief executive Oscar K. Brown backed the full-year profit plan and expects to beat its $2.85 billion middle point, which by our math leaves at least $722 million for the fourth quarter.
| Adjusted EBITDA | $708.3M +12% from a year ago; -4% from last quarter |
|---|---|
| Attributable natural-gas volume | 5.74 Bcf/d +7% from last quarter on Brazos deal |
| Free Cash Flow after distributions | -$148.5M capital spending hit $303.4M |
| 2026 capital spending outlook | Above $1.0B 2027 spending to stay near 2026 level |
⚖️ Verdict: ⚪ Neutral
The story is unchanged because strong volume gains from the June Brazos acquisition are offset by a heavier multi-year construction bill. Instead of letting capital spending fall in 2027 after current water and gas plant builds finish, Brown pushed 2026 spending slightly above $1 billion and said 2027 spending will stay near that level to fund new wells and a 7.5% stake in the Solitude pipeline. One caution: Free Cash Flow fell $149 million short of covering unitholder payouts this quarter, pushing net debt up $1.46 billion since year-end by our math.
The question now is whether 2027 volume growth can generate enough cash to cover the $1.57 billion annual payout while capital spending stays near $1 billion. Bulls see new West Texas plants, mid-December Brazos pipeline tie-ins, and Wyoming contracts lifting profit fast enough to close the funding gap; skeptics see another year of debt-funded payouts and commodity-margin pressure. February's 2027 Free Cash Flow outlook will settle it.
🐂 Bull Case
Brazos Deal Lifted Delaware Gas Volumes 20%
Western Midstream, which operates pipelines and treatment plants for oil and gas producers, bought rival gatherer Brazos Delaware in June to expand in West Texas. This quarter gave the first full three-month reading on those pipes. Attributable natural-gas volume rose 7% from last quarter to 5.74 billion cubic feet per day (Bcf/d), a net addition of 400 million cubic feet per day by our math.
Operated gas volumes in the Delaware Basin jumped 20% from last quarter to a record 2.56 Bcf/d. Chief executive Oscar K. Brown said "The Brazos integration is progressing as expected, and we anticipate tying those assets into our West Texas Complex by mid-December, enabling us to reduce offloads and generate more value for WES unitholders." Keeping that gas inside its own plants will save third-party processing fees starting in early 2027.
What to watch: confirmation on the fourth-quarter call that the mid-December pipeline connection finished on time. A completed tie-in will reduce third-party processing expenses in the cost of product line during the first quarter of 2027.
Core Business Outperformed Initial Plan By $150M
Acquisitions drove much of this year's headline growth, but the existing pipe network is also beating the partnership's initial targets. Brown expects full-year Adjusted EBITDA (operating profit before depreciation and one-offs) to finish above the $2.85 billion middle of the range. Excluding the $100 million contribution from Brazos, that puts full-year operating profit more than $150 million above the original February plan.
Produced water, the salty water pumped up alongside oil and gas that the partnership gathers and injects underground, also grew without a new acquisition this quarter. Attributable water volume rose 2% from last quarter to 2,992 thousand barrels per day. New wells coming online in the fourth quarter and new customer contracts in Wyoming's Powder River Basin back management's expectation for volume growth across all three product streams in 2027.
What to watch: fourth-quarter Adjusted EBITDA against the $722 million implied by the middle of the full-year outlook by our math. Beating that figure will confirm that fourth-quarter well connections offset lower commodity prices.
🐻 Bear Case
Project Spending Keeps Cash Flow Below Payouts
Previously, management framed 2026 as the peak year for construction spending on the Pathfinder water pipeline and the North Loving II gas plant, with capital spending set to fall back in 2027. Instead, Brown lifted 2026 capital spending "slightly above the high end of our $850.0 million to $1.0 billion guidance range, reflecting our investment in Solitude and accelerating producer activity levels." He added that "We expect 2027 capital expenditures to be relatively in line with 2026".
- Q3 Free Cash Flow: $244.2 million, down 39% from $397.4 million a year ago by our math
- Q3 Free Cash Flow after unitholder distributions: negative $148.5 million
- Nine-month cash balance: down from $819.5 million at year-end to $44.5 million
- Nine-month net debt: up $1.46 billion to $8.84 billion by our math
Because construction budgets will stay near $1 billion next year rather than dropping, Free Cash Flow will take longer to cover the $3.72 per unit annual payout (~$1.57 billion a year). The pipeline owner is covering the gap with borrowings and cash on hand.
What to watch: formal 2027 Free Cash Flow and capital spending targets on the fourth-quarter call in February. A 2027 Free Cash Flow midpoint below $1.55 billion would mean payouts exceed cash generation for a second straight year.
Lower Oil Prices Cut Per-Unit Margins
While the partnership gets most of its revenue from fixed fees, a minority of contracts pay based on oil, natural-gas liquids, and recovered skim-oil prices. An April oil price rally lifted those contracts in the second quarter, and the reversal pulled them down this quarter. Adjusted Gross Margin (revenue minus commodity purchase costs, plus equity distributions) fell across all three streams on a per-unit basis from last quarter.
- Natural-gas Adjusted Gross Margin: $1.25 per thousand cubic feet (Mcf), down 7% from $1.35 last quarter
- Produced-water Adjusted Gross Margin: $0.89 per barrel, down 7% from $0.96 last quarter
- Crude-oil and natural-gas liquids Adjusted Gross Margin: $2.93 per barrel, down 9% from $3.21 last quarter
- GAAP operating margin: 38.6% of revenue, down 7.7 percentage points from a year ago by our math
Compared with a year ago, GAAP operating margin shrank because purchased commodity costs (cost of product) rose 4.8 percentage points of revenue, plant operating and maintenance costs rose 2.1 points, and depreciation rose 0.9 points following the Aris and Brazos deals.
What to watch: fourth-quarter per-unit Adjusted Gross Margin across gas and water. Further drops below $1.25 per Mcf in gas or $0.85 per barrel in water would show commodity weakness eating into the volume gains from new wells.
Legacy DJ Basin Volumes Slipped 4%
Outside of West Texas, the partnership operates a mature pipeline network in Colorado's DJ Basin, where drilling activity is sensitive to lower crude-oil prices. Brown noted that third-quarter Adjusted EBITDA dipped 4% from the second quarter "primarily due to lower crude-oil and NGLs pricing, decreased throughput in the DJ Basin, and slightly higher operation and maintenance expense, which is typical in the third quarter".
Operated natural-gas volume in the DJ Basin fell 4% from last quarter to 1,482 million cubic feet per day, and crude-oil and natural-gas liquids volume there fell 4% to 90 thousand barrels per day. Because the DJ Basin carries high fixed-fee margins, volume declines there require steady drilling in the Delaware Basin just to keep company-wide profits moving up.
What to watch: fourth-quarter DJ Basin gas and oil volumes in the operating statistics table. A second consecutive quarterly drop would confirm that lower oil prices are slowing producer drilling in Colorado heading into 2027.
Risks this quarter didn't answer
Two standing accounting and customer risks and one unit-supply overhang received no new detail in the earnings release or remained open.
- Non-cash revenue boost: recognized fee revenue exceeded actual customer cash billings by $38.1 million in Q3 (after $52.8 million in Q2) from amortizing the Occidental contract liability, which lifts Adjusted EBITDA but is subtracted from Distributable Cash Flow.
- Occidental rate dispute: the earnings release did not mention the DJ Basin cost-of-service rate calculation dispute with top customer and 37.7% owner Occidental; the quarterly 10-Q filing's commitments footnote will show if the exposure changed.
- Brazos unit lock-up: the 19.4 million common units issued to the sellers of Brazos in June become eligible for transfer in December 2026.
👓 Other Themes
Solitude Pipeline Stake Adds 2029 Takeaway Capacity
Western Midstream bought a 7.5% stake in the Solitude Pipeline System joint venture operated by WhiteWater. The project consists of two 48-inch natural-gas pipelines running from the Permian Basin to Katy, Texas, and will add 2.25 Bcf/d of transport capacity in late 2029 and another 2.25 Bcf/d in 2030. It contributed $25.1 million of equity investment cash outflow this quarter and brings no revenue until late 2029.
💲 Other KPIs
Distributable Cash Flow — operating profit after cash interest, maintenance capital spending, taxes, and non-cash revenue adjustments — dipped 4.6% from last quarter's $537.2 million and 6.4% from $547.3 million a year ago. Higher cash interest ($115.8 million vs $106.6 million in Q2) and higher maintenance capital ($38.0 million vs $26.7 million) drove the sequential drop.
Cash generated by operations rose 6.1% from $534.7 million last quarter and sat 0.5% below $570.2 million a year ago. For the first nine months of 2026, operating cash flow fell 5.6% from a year ago to $1.57 billion because working capital outflows and the Occidental contract change reduced cash collections relative to reported revenue.
The diluted unit count increased 8.4% from 382.8 million a year ago and 3.9% from 399.4 million last quarter. The midstream partnership issued 26.6 million units for the Aris acquisition in October 2025 and 19.4 million units for Brazos in June 2026, partially offset by 15.3 million units retired in the February Occidental contract exchange.
🔮 Guidance
Unchanged, with management now guiding above the $2.85 billion middle of the range (up 15% from 2025). By our math, hitting the midpoint leaves $722 million for Q4, up 2% from Q3 and up 14% from Q4 last year. This follows a $250 million raise in Q2; in both 2024 and 2025 the partnership beat its initial midpoint by an average of 1.6%.
Unchanged. The plan calls for $2.15 billion at the middle of the range, up 1.2% from 2025. By our math, that leaves $604 million for Q4, a 18% jump from Q3's $512.3 million and up 15% from a year ago, which requires a sharp fourth-quarter step-up in customer billings or lower maintenance spending.
Unchanged. The middle of the range sits at $1.20 billion, down 21% from 2025 because of heavy construction spending. By our math, reaching the $1.20 billion midpoint requires $450 million of Free Cash Flow in Q4, nearly double Q3's $244.2 million and up 32% from Q4 last year.
Raised. Management now expects capital spending to finish slightly above the $1.0 billion top of the range, up at least 37% from $728 million in 2025. With $808.4 million of cash capital spending and $27.7 million of equity contributions through nine months, fourth-quarter spending should slow from Q3's $303.4 million accrual pace.
Unchanged. The partnership declared $0.930 per unit for the third straight quarter, keeping the annualized payout at $3.72 per unit, which is 2% above the $3.64 annualized rate in the third quarter of last year.
❓ Key Questions
How much will the Solitude pipeline cost in 2027?
Management said 2027 capital spending will stay near 2026's ~$1 billion level rather than dropping after North Loving II and Pathfinder finish. Investors need to know how much of the 2027 budget goes to the 7.5% Solitude stake versus new Delaware and Powder River wells.
What drives the implied Q4 jump in Free Cash Flow?
By our math, reaching the $1.20 billion full-year Free Cash Flow midpoint requires $450 million in the fourth quarter, up from $244 million in the third quarter. Management did not explain how much of that step-up comes from lower fourth-quarter capital spending versus working-capital inflows.
Where do per-unit margin targets stand after Q3's drop?
Per-unit Adjusted Gross Margin dropped 7% to 9% across all three streams in the third quarter as oil and natural-gas liquids prices cooled. Management did not say whether fourth-quarter per-unit margins have stabilized or will fall further.
Has the DJ Basin rate dispute with Occidental progressed?
The second-quarter filing disclosed a disagreement with Occidental over cost-of-service rate calculations in the DJ Basin that could reduce rates and trigger a charge. The third-quarter release gave no update on the talks or potential financial impact.