PLAINS ALL AMERICAN PIPELINE LP (PAA) stock intrinsic value fair value estimate & owner earnings analysis

Plains All American Pipeline moves, stores, buys and sells crude oil. Its core is the Permian Basin of West Texas and southeastern New Mexico, where it owns about 5,600 miles of gathering lines that collect oil at producers' wells (through a 65%-owned joint venture), an intra-basin hub network, and interests in long-haul pipelines to Corpus Christi (Cactus, Cactus II and, since late 2025, all of Cactus III), Houston (BridgeTex, Wink to Webster) and Cushing (Basin). Outside the Permian it runs crude systems in South Texas, the Mid-Continent, the Rockies, the Bakken and Canada, plus terminals at Cushing, St. James, Midland and Patoka. In May 2026 it sold its Canadian natural gas liquids business to Keyera for about US$3.76 billion, which leaves an almost pure crude oil company. Most of its margin comes from fees per barrel moved, but little of it is locked in: guaranteed minimum payments under pipeline and terminal contracts are about $640 million for 2026 and fall to about $220 million by 2030. Everything else depends on how much oil producers pump and what shippers will pay in a basin the company itself describes as overbuilt. How we measured earnings. We start from operating cash flow, strip out working-capital swings, and subtract equity-based pay and the company's own maintenance spending (about $150-190 million a year). We also subtract one more item. Plains reports $300-520 million a year of "investment" spending, and about half of it goes into the Permian gathering joint venture, much of it connecting new wells. Shale wells decline steeply, so a gathering system that stops connecting wells loses volume. That half of the investment spending is what keeps the gathering business standing still, so we treat it as a cost of staying in business (about $150 million a year net of the partner's share) rather than as growth. The other half (long-haul expansions, terminals) we treat as optional: we neither charge for it nor credit it with growth. Depreciation and the amortization of acquired contracts, about $950 million a year, are added back; the gradual wearing-out of those contracts is carried instead in how each case fades over time. The joint-venture partners' share is counted as the cash actually distributed to them, about $410-450 million a year. The starting level. We value the business before its lenders and then subtract what it owes. On that basis the continuing crude business produced about $2.20 billion in 2025, a year that included only a couple of months of Cactus III. It ran at about $2.30 billion a year in the first half of 2026, but that half included an oil-price jump in the second quarter that lifted marketing results (crude segment earnings were $582 million in the first quarter and $690 million in the second). We leave out 2024 because it carried about $345 million of costs from the 2015 Line 901 oil spill in California. Our starting point is $2.25 billion, about $3.19 per unit. Last year's gain came from about $2.8 billion of acquisitions, not from the existing pipes: in 2025 Permian volumes rose 9% and acquired assets were added, yet crude segment earnings rose only 3%, because some Permian long-haul contracts reset to lower market rates. No case assumes that pace of growth continues. Base case ($32.10). For five years, contractual tariff escalators roughly offset the roll-off of minimum-volume contracts into a crowded market and cost inflation, so earnings stay flat. From year six to year ten they grow 1% a year as escalators outrun the remaining resets. They then hold flat for another ten years, resting on the acreage dedications behind the gathering system, pipe with decades of physical life, and Plains' record of operating in the Permian since the late 1990s. We cannot point to evidence that sustains earnings beyond the mid-2040s, so after that they decline 5% a year. The business is worth about $33.4 billion, including the pending Silver Creek purchase at its $585 million cost. It owes about $10.8 billion, leaving $22.7 billion, or $32.10 per unit. Bear case ($16.58). More Permian long-haul contracts reset into an overbuilt market, cutting earnings 3% a year for two years. Then comes a downturn of the kind this industry has actually had. In 2020, when the pandemic collapsed demand and oil prices, Plains' cash flow before interest fell 28%, from about $2.59 billion in 2019 to $1.87 billion, and in 2021 it was still 6% below 2019. We apply the same shape in year three: earnings fall 25% to about $1.54 billion, recover to 90% of the pre-downturn level the next year, and settle at 95%, because some lost volume and contracts renegotiated under pressure do not come back. The 2015-2017 oil collapse is the other reminder; Plains cut its distribution from $2.80 to $1.20 a unit. After the downturn, Permian gathering volumes plateau and earnings slip 1% a year to year ten, then decline 6% a year. We also assume the $2.75 billion of notes maturing between December 2029 and January 2031 must be refinanced after the downturn at about 8%, which adds about $0.34 billion to what is owed. The business is worth about $22.8 billion and owes about $11.1 billion, leaving $11.7 billion, or $16.58 per unit. Even at the trough, cash earnings of about $1.54 billion cover the roughly $575 million annual interest bill about 2.7 times, so the debt stays serviceable; the cost falls on the distribution, not the lenders. Bull case ($40.75). The company's own plans work: its roughly $50 million cost-reduction program and the 75,000-barrel-a-day Cactus III expansion now under way add 3% a year for two years, contracts renew near today's rates so escalators add 1.5% a year to year ten, then earnings hold flat for fifteen years and decline 4% a year after that. The business is worth about $39.5 billion and owes $10.8 billion, leaving $28.8 billion, or $40.75 per unit. What Plains owes. About $10.8 billion in total: $8.43 billion of senior notes with an average coupon of about 5.0%, maturing between December 2029 and 2045, counted at about $7.98 billion because their low fixed rates run for many years; $1.5 billion of junior subordinated notes issued in September 2026 at 6.75% and 7.00%, counted slightly above face, whose rates reset from December 2031 and December 2036 but cannot fall below the starting rates; about $1.0 billion of commercial paper and cash used, together with those notes, to redeem all Series A preferred units in September (about $1.69 billion at 110% of issue price) and all Series B preferred units in October ($800 million); about $0.3 billion of Canadian tax on the sale still unpaid at June 30; the $585 million Silver Creek purchase in the Powder River Basin agreed in September 2026 (its earnings were not disclosed, so we credit it at exactly its price; it comes with 915,000 dedicated acres and contracts averaging more than eight years); and small other debt; less about $0.76 billion of cash beyond operating needs. The nearest maturities are $1.0 billion of 3.55% notes in December 2029, $750 million of 3.80% notes in September 2030 and $1.0 billion of 4.70% notes in January 2031. Margin-of-safety price ($17.50). How sure are we of the earning level? Reasonably sure within a band. The continuing business ran at roughly $2.0 billion before interest in 2023, $2.2 billion in 2025 and $2.3 billion in the first half of 2026. But guaranteed payments cover only about a quarter of that, so the level rests on Permian volumes and on contract rates that are visibly resetting lower. ExxonMobil buys about 31% of the oil Plains sells, though those are low-margin sales at many locations. The worst plausible outcome is a long Permian downturn on top of further resets, which is the bear case, or another major spill like Line 901, whose total cost reached about $870 million. The structure should survive either: nothing matures before December 2029, interest is covered more than twice even at a 2020-style trough, the assets are steel pipe in the ground, and no single contract holds the business up. We could be wrong in two main ways. If keeping volumes flat costs $100 million a year more than we charge (a real worry, with depreciation near $950 million), the units are worth about $2 less. If resets run deeper and longer, the bear case's $16.58 is the answer. Over the holding period, the current distribution of $1.67 a unit is covered about 1.4 times by cash after interest; at $17.50 it alone equals close to 10% a year. For a 20% annual return from $17.50, the units would need to be worth about $24 in three years or about $27 in four, which the base case supports. If the bear case plays out instead, its value of about $16.60, plus any distributions still paid, roughly matches that price. That is why the margin-of-safety price is $17.50. Our earlier estimates were prepared on a different basis and are not comparable. What could make this wrong. On the downside: sustaining spending that proves higher than the half of investment capital we charge, faster Permian decline, or deeper tariff resets. On the upside: continued Permian volume growth, or contracted earnings from recent acquisitions that we have not credited. Not reconcilable from the filings: the exact amount of the Canadian sale tax still unpaid after June 30 (the company booked about $368 million of current tax on the sale in the first half and had paid little tax by June 30); first-half 2026 equity-based pay (estimated); and how much of each year's investment spending went to well connections rather than expansion, because the company does not break this out.