Plains All American (PAA) Q3 2026 earnings review
Plains grows its crude business, while debt refinancing boosts cash
Plains All American, the North American crude oil pipeline operator, grew its core oil business while reshaping its balance sheet after selling its Canadian gas liquids unit. Cash profit from continuing operations jumped 21% to $711 million on higher Permian volume and the Cactus III pipeline purchase, while a one-time accounting charge from buying back preferred units pushed reported net income into a per-unit loss. Chief Executive Willie Chiang kept the full-year cash profit target at $2.88 billion, which by our math leaves $701 million for the fourth quarter.
| Cash profit from continuing crude operations | $711M +20.7% from a year ago |
|---|---|
| Cash available for distribution per unit | $0.67 +10% from a year ago |
| Reported loss per unit (after preferred buyout) | -$0.06 $0.46 profit before the buyout charge, by our math |
| Full-year cash profit outlook | Unchanged middle of the range: $2.88B (+16% in crude) |
⚖️ Verdict: 🟢 Bullish
The story got better because Plains locked in permanent cash savings and new oil supply to replace the Canadian business it sold. Refinancing $2.3 billion of preferred units with cheaper debt adds about $60 million a year in cash for common unitholders, and two gathering deals in the Powder River and Midland basins add future pipeline volume. One caution: lower contract rates on older Permian pipelines, a $68 million write-down on co-owned pipelines, and rising field cleanup costs held back margins.
The question now is whether volume growth from new gathering pipes can outrun lower contract rates and rising field costs once the Cactus III acquisition laps in November. If new barrels and internal cost cuts win out, cash profit keeps climbing in 2027; if rate resets and cleanup bills persist, profit growth stalls until the Midland expansion starts in late 2027. Management's first 2027 outlook next quarter will settle it.
🐂 Bull Case
Continuing Crude Operations Grew 21% After NGL Exit
Plains All American, the North American crude oil pipeline and storage operator, sold its Canadian natural gas liquids (NGL) business in May 2026. Because last year's third quarter still included $80 million from those sold assets, total earnings before interest, taxes, depreciation and amortization (EBITDA), excluding one-offs, grew only 6.3% to $711 million.
On a like-for-like basis, EBITDA excluding one-offs from the continuing crude oil business rose 20.7% from $589 million a year ago. Buying the Cactus III pipeline late last year and capturing $50 million in cost savings from the deal drove the increase. Daily crude volume in the Permian Basin, the company's main oil field in Texas and New Mexico, also rose 7.8% to 8.07 million barrels.
What to watch: fourth-quarter continuing EBITDA excluding one-offs, which marks the first full quarter after the November 2025 Cactus III purchase. A growth rate near the 13.8% pace implied by the full-year outlook would show that pipeline volume gains can carry the business without deal boosts.
Refinancing Preferred Units Adds $60 Million in Yearly Cash
Plains used its balance sheet to cut financing payouts and leave more cash for common unitholders. The partnership issued $1.5 billion of junior subordinated notes and redeemed $2.3 billion of higher-cost Series A and Series B preferred units across September and October.
- Expected annual cash benefit: about $60 million, or $0.09 per common unit
- Accounting charge from the Series A buyout: $358 million, or $0.51 per unit by our math
- Profit per unit excluding one-offs, before the buyout charge: $0.46 by our math, up 18.6% from $0.39 a year ago
Because accounting rules treat the gap between the $1.69 billion cash buyout price and the balance-sheet value of the Series A units as a payout to preferred holders, reported profit per unit fell to a loss of $0.06. That one-time accounting charge masks an 18.6% rise in per-unit profit, by our math, and permanent annual cash savings.
What to watch: preferred unit cash distributions in the first quarter of 2027, the first full period after the October Series B buyout. Dropping to zero from $82 million this quarter will confirm the full $0.09 per unit annual cash boost.
Two Basin Deals Add Dedicated Acreage for 2027
Management is redeploying cash from its Canadian exit into US crude gathering pipes that feed its main long-haul networks. On October 1, the partnership paid $585 million in cash to buy the Silver Creek gathering system in the Powder River Basin, an oil region Chief Executive Willie Chiang described as an area "where we expect significant production growth over the coming years, and enhanced integration with our existing downstream assets".
Plains also signed 10-year agreements with a large integrated oil producer to expand its Permian joint venture gathering network in the Midland Basin. The deal adds about 270,000 dedicated acres and an estimated 225,000 barrels per day of gross volume starting in the fourth quarter of 2027, locking in multi-year supply without relying on higher oil prices.
What to watch: Rocky Mountain pipeline tariff volumes in the fourth quarter, which stood at 470,000 barrels per day before Silver Creek closed. The initial step-up will show how much immediate daily volume the $585 million purchase adds.
🐻 Bear Case
Rate Resets and Joint Venture Write-Downs Drag on Profit
"Our company delivered solid operational performance year-to-date with continued execution across the organization on our key initiatives for the year," Chiang said. Yet older, high-priced shipping contracts in the Permian Basin keep expiring, and the company noted that "the impact from certain Permian long-haul contract rates resetting to market in 2025" reduced third-quarter results.
At the same time, profit from unconsolidated joint ventures — pipelines Plains co-owns with other energy firms — fell 11.5% from a year ago to $85 million, and the partnership took a $68 million write-down on those investments. Operating margin also shrank by 0.8 percentage points to 3.4% as the cost of buying crude oil rose 1.0 percentage point to 92.5% of revenue.
What to watch: equity earnings in unconsolidated entities in the fourth quarter. Another drop below the $89 million earned in last year's fourth quarter would show that lower tariff rates are still hurting joint-venture pipelines.
Environmental Cleanup and Taxes Lift Field Operating Costs
Plains plans to deliver $50 million of organizational cost savings across 2026. While general and administrative overhead fell 6.0% from a year ago to $78 million, field operating costs — the day-to-day expense of running and maintaining pipelines — rose 6.3% to $306 million.
The partnership said "higher operating costs driven by environmental remediation expenses and property tax expense" offset part of its volume gains. Meanwhile, pipeline volume outside the Permian Basin was uneven, with Gulf Coast volume dropping 17.6% to 187,000 barrels per day and South Texas falling 6.1% to 505,000 barrels per day.
What to watch: fourth-quarter field operating costs against last year's $281 million. A second straight quarter above $300 million would show that cleanup bills and property taxes are eating up the company's internal cost cuts.
👓 Other Themes
Management Merged Its Reporting Segments Into One
Following the May 2026 sale of its Canadian NGL business, Plains combined its historical Crude Oil and NGL divisions into a single reporting segment. Management said it now runs commercial operations across North America "without regard to market or geographic location", which removes separate profit breakdowns for any remaining non-crude assets.
Management Sees Tailwinds Despite Oil Market Swings
Crude oil prices and producer drilling budgets have swung throughout 2026, keeping North American drillers cautious on near-term output. Even so, Chiang said the oil backdrop remains "volatile, yet constructive, and we see multiple tailwinds for our business as we build momentum into 2027" as new gathering pipes come online.
💲 Other KPIs
Implied distributable cash flow (DCF) per common unit — cash generated from operations after interest, taxes and maintenance, available to pay unitholders — rose 9.8% from $0.61 a year ago. After declining in the first quarter and rising 6.1% in the second, growth picked up and covered the $0.4175 quarterly distribution by 1.61 times.
Total debt fell 11.9% from $11.26 billion at the end of 2025 as the pipeline operator used $3.53 billion in net proceeds from the Canadian asset sale to pay down borrowings. Including the October preferred buyout and Silver Creek purchase, the debt-to-EBITDA ratio stands at about 3.6 times, inside the 3.25 to 3.75 target range.
Total investment and maintenance capital spending attributable to Plains fell 27.5% from $171 million a year ago, with growth project spending down $23 million to $96 million and maintenance down $24 million to $28 million. Lower capital spending after the Canadian sale helped lift free cash flow excluding working capital swings to $569 million.
🔮 Guidance
Unchanged at the middle of the range. Management narrowed the band by $25 million on each side, keeping the $2.88 billion target that calls for 1.7% total growth over 2025 after raising it by $130 million in the first quarter. By our math, that leaves $701 million for the fourth quarter, down 5.0% in total but up 13.8% against last year's continuing crude business.
Raised from the 13% growth rate management set at the start of the year. The outlook calls for the continuing crude oil business to add about $370 million in cash profit over 2025, driven by a full year of the Cactus III pipeline and $100 million of combined deal synergies and internal cost cuts.
❓ Key Questions
What caused the $68 million joint venture write-down?
Plains recorded a $68 million impairment on its investments in unconsolidated entities and saw quarterly equity earnings fall 11.5% to $85 million. Management did not name which co-owned pipeline lost value or whether lower tariff rates triggered the charge.
How much will Silver Creek add to fourth-quarter profit?
The partnership closed its $585 million cash purchase of the Silver Creek gathering system on October 1 but kept its full-year cash profit target unchanged at $2.88 billion. Investors need to know how much fourth-quarter EBITDA Silver Creek contributes.
How big are the environmental cleanup costs in field expenses?
Field operating costs rose 6.3% from a year ago to $306 million, which the release blamed on environmental remediation and property taxes. Without the exact dollar size of the cleanup charges, readers cannot tell if the $50 million efficiency plan is working.
What is the capital cost of the Midland Basin expansion?
Plains announced a 10-year deal adding 270,000 dedicated acres and 225,000 barrels per day of gross volume in late 2027. The release did not state how much capital Plains and its joint-venture partner must spend to build the gathering pipes.