PLAINS ALL AMERICAN PIPELINE LP (PAA): what the price assumes

In the published model solve dated 2026-Q2, anchored at $23.17, PLAINS ALL AMERICAN PIPELINE LP (PAA) is priced for -3.8% growth. boothcheck publishes no house fair value, target price, or buy/sell rating; individual model outputs and user-controlled scenarios are analytical inputs, not Boothcheck targets. Narrative composed 2026-06-27.

Generated: 2026-08-10 · Exported: 2026-08-12 · Source: https://boothcheck.com/report/PAA

Headline

FieldValue
TickerPAA
CompanyPLAINS ALL AMERICAN PIPELINE LP
Current price$23.17/sh
CompositionCrude Oil - Sales 96% / Crude Oil - Transportation 3% / Crude Oil - Terminalling, Storage and Other 1% / NGL - Sales 0% / NGL - Terminalling, Storage and Other 0%

What The Price Assumes (Inversion)

The assumption today's price embeds, recovered by inverting the valuation.

FieldValue
Inversion basiswhole-company
Operating margin (value-band context)2.1%
Operating margin today3.3%
Margin compression (value-band)-1.2pp
Implied growth-3.8%
Multiple paid17x operating income

The operating-margin figure is value-band context at year 12: derived from the framework's value band, a separate calculation — not part of the priced-in solve.

Solve inputs: computed at a 7% cost of capital with 4% terminal growth over a 5-year stage; each 1pp of cost of capital moves the implied operating-profit growth ~7.4pp (computed at the 7% minimum rate; the CAPM rate 6.4% sits below it).

Reconcile: at the x-ray's 9.3% required return this reads ~11.7%/yr; the models below use their own rates.

How unusual the bet is: within-range

ReferenceValue
vs own history-0.51σ
cohort percentile (of 46 peers)63
implied end-window share0%

Valuation X-Ray

The price is supported by earnings-power and relative-multiple and growth-DCF value. A value/asset-supported name, not a pure growth bet.

How the valuation models price the stock relative to the market price. Price/FV above 1.0 means the market pays more than that lens defends (expensive); at or below 1.0 the lens can defend the price.

FamilyMedian price/FVModelsReads
Asset—0—
Earnings1.03x4expensive
Relative0.79x2justifies
Growth0.95x3justifies

Families that justify the price: Earnings, Relative, Growth

The models below discount at their own flat-beta convention rates (cost of equity 9.3%, WACC 9.9%); the inversion above states its own rate.

Per-Model Detail (n=9)

ModelFamilyFVPrice/FVApplicableMethodology
DCF Perpetual GrowthGrowth$24.490.95xyesFCF base $2.1B, growth -7% (input: historical growth), terminal g 0.5%, WACC 9.9%, 5yr projection
DCF Exit MultipleGrowth$27.080.86xyesExit EV/EBITDA: 5.0x / 7.0x / 9.0x (bear / base = today's held flat / bull), 5yr
Relative ValuationRelative——noP/E 18x (static sector reference · 2026-04), scenarios: 15.2x / 18.0x / 20.8x (bear / base = reference held flat / bull), EV/EBITDA 12x
Simple DDMGrowth——no—
Two-Stage DDMGrowth——no—
Simple Excess ReturnAsset——no—
Two-Stage Excess ReturnAsset——no—
Discounted Future Market CapGrowth$11.731.98xyesRev $45.3B, growth -7% (input: historical growth; tapered), Terminal P/S: 0.3x / 0.4x / 0.4x (bear / base = today's held flat / bull, cap 8x)
Peter Lynch Fair ValueRelative$19.471.19xyesEPS $1.62, growth 2% (input: historical EPS growth), PEG=7.14 (Overvalued)
Margin TrajectoryGrowth——no—
Earnings Power ValueEarnings$15.311.51xyesNormalized EBIT (5y avg op income, one-time charges added back) $1.12B × (1−0%) / WACC 9.9% → EPV (no growth)
Residual IncomeAsset——no—
Graham NumberAsset——no—
EV/EBITDA RelativeRelative——noEBITDA $2.42B × sector EV/EBITDA 12.0x
FCF YieldEarnings$31.260.74xyesFCF $2082.0M / Kₑ 9.3% — zero-growth perpetuity
SBC-Adj FCF YieldEarnings——no—
Ben Graham FormulaEarnings$52.370.44xyesEPS $1.62 × (8.5 + 2×15.0%) × (4.4 / 5.3%)
ROIC-Justified P/BAsset——no—
P/Sales SectorRelative——noRevenue $45.26B × sector P/S 2.5x
PEG Fair ValueRelative$60.860.38xyesEPS $1.62 × (PEG 1.5 × growth 25.0% (input: historical EPS growth)) → PE 37.5x
Earnings YieldEarnings$17.541.32xyesEPS $1.62 / required return 9.3% (Rf 4.3% + ERP 5.0%)
Funds From Operations MultipleRelative——no—
Clinical Phase NPVGrowth——no—
MertonAsset——no—
V5 Mechanical———no—

Economic-Unit Decomposition (Sum Of The Parts)

One or more material disclosed units has unresolved economics. Unknown/general is not evidence of homogeneity: segment SOTP is primary but incomplete, consolidated cash flow may remain only a secondary cross-check when every unit shares an enterprise basis, and one sector multiple or target margin is withheld.

UnitRoleValuation basisRevenueReported profitValue evidenceStatus
Crude Oiloperatingenterprise$44.1b—withheldunresolved no unit value
NGLoperatingenterprise$151.0m—withheldunresolved no unit value

No total common-equity value is stated. One or more material units lack a supported unit value. The displayed values are an indicative subtotal; consolidated debt and cash cannot be applied to a fraction of the company.

Solvency

FieldValue
Net debt$11.7b
Net debt / NOPAT (after-tax)7.91x
Net debt / operating income (pre-tax)7.89x
Interest coverage2.5x
Burning cashno

Bullet Takeaways

Bull Case

Lead with the balance sheet, because for a pipeline partnership the capital structure tells you more than the income statement. Plains carries roughly $11.7 billion of net debt against about $1.5 billion of trailing operating income, leverage near 4x. That looks heavy until you understand what the debt is financing: a network of fee-based crude-oil transportation, terminalling, and storage assets that generate steady, contracted cash flow regardless of the oil price. Management's confidence shows in the actions, not just the words. The board raised full-year 2026 adjusted EBITDA guidance by $130 million to $2.88 billion and lifted adjusted free cash flow guidance to about $1.85 billion (Plains Q1 2026, stocktitan). A management team that raises guidance and is actively deleveraging is signaling it believes in the durability of its own cash flows.

The crude oil segment, the core of the business, is performing. Q1 2026 crude oil adjusted EBITDA was $582 million, up 4% year over year on higher volumes and recent acquisitions, partly offset by contract resets (Plains Q1 2026, stocktitan). The filings describe a business that earns through transportation tariffs plus significant revenue from commercial and merchant activities that increase utilization of its transportation system (FY2025 10-K, accession 0001070423-26-000014). This is toll-road economics: the more crude that moves through the Permian and onto Plains pipelines, the more it earns, and US crude production growth underpins the volumes.

The deleveraging catalyst is concrete and imminent. Plains is divesting its NGL business for roughly $3.3 billion of net proceeds, which would lower pro forma leverage from about 4.1x to 3.5x (Plains Q1 2026, stocktitan). That move simplifies the business to a focused crude-oil pipeline pure-play and de-risks the balance sheet at the same time. At about 16x operating income, a multiple the model reads as below what even a modest decline would justify, with a high cash distribution and a clear path to lower leverage, the bull case is a stable, fee-based cash machine that is getting safer just as it returns more cash to unitholders.

Bear Case

The structural truth a unitholder has to face is the leverage: roughly $11.7 billion of net debt against about $1.5 billion of operating income, with interest coverage around 2.5x, is a thin margin in a capital-intensive business. The 2.5x coverage is the number that should give pause; it means a meaningful share of operating income goes to servicing debt, and there is limited room to absorb a downturn in volumes or a refinancing at higher rates. Pipeline partnerships are built to carry leverage because their cash flows are stable, but stable is not the same as guaranteed, and at 4x EBITDA Plains has less cushion than a unitholder buying a 'safe' income stream might assume.

The business also faces slow structural and cyclical erosion that the cheap multiple may be correctly pricing. NGL adjusted EBITDA fell 23% in Q1 2026 on lower frac spreads, a reminder that not all of Plains' segments are pure fee-based tolls; some carry commodity-margin exposure that swings with spreads (Plains Q1 2026, stocktitan). The crude segment itself absorbed contract resets that partly offset volume growth, which is the quiet risk in pipeline economics: as legacy contracts roll, they often reset to lower tariffs in a competitive midstream market. And the entire volume base depends on continued US crude production growth; if the shale treadmill slows or peaks, throughput growth stalls and a tariff-based business has little organic growth left.

The partnership structure and the negative book value add complication. The asset-based methods cannot even run here because book value per share is negative, leaving no equity floor to value against, and several methods are unusable on non-positive earnings inputs. As a limited partnership, Plains issues a K-1 rather than a 1099, which carries tax complexity, and the distribution, while attractive, depends on the leverage staying serviceable. The NGL sale will help, but it also removes a cash-generating segment, so the deleveraging comes at the cost of a smaller earnings base. The bear case is straightforward: a highly leveraged, partly commodity-exposed midstream partnership where the cheap multiple reflects real risks, the equity sits behind $11.7 billion of debt, and the growth depends on a US production cycle that will not run uphill forever.

Valuation

Plains is a leveraged midstream partnership, and its valuation has to be read through that lens. The asset-based methods do not apply (book value per share is negative, so the excess-return, residual-income, and Graham methods all drop out), which leaves the cash-flow and relative methods to carry the analysis. The P/S-based figures near $160 are nonsensical artifacts of applying a sector revenue multiple to a low-margin pass-through business and should be ignored entirely.

The inversion gives the cleanest read. At $21.34 the market pays about 16x company-wide operating income, computed at a 7% cost of capital (the model floor) with 4% terminal growth, a multiple so low it sits below what even a 5%-a-year operating-profit decline would warrant. That is a bound, not a solved growth rate: the price embeds an assumption that operating profit slowly erodes, which is the market's way of discounting the leverage and the contract-reset risk. The reverse-DCF floored at the current price, meaning the inversion could not find a positive growth scenario the price implies. The honest summary is that Plains is priced as a stable-to-slowly-declining, high-yield income vehicle rather than a grower. The deleveraging from the $3.3 billion NGL sale (pro forma leverage falling toward 3.5x) is the real source of potential re-rating: a safer balance sheet at the same cash flow should command a higher multiple. The valuation is reasonable for an income holder who accepts the leverage and the partnership tax treatment, and undemanding if the deleveraging lifts the multiple.

Catalysts

Plains All American reported Q1 2026 results on May 8, 2026, with adjusted EBITDA attributable to PAA of $730 million, net income of $152 million, and operating cash flow of $418 million; crude oil adjusted EBITDA rose 4% to $582 million while NGL fell 23% to $145 million on lower frac spreads (Plains Q1 2026, stocktitan). Management raised the midpoint of full-year 2026 adjusted EBITDA guidance by $130 million to $2.88 billion and lifted adjusted free cash flow guidance to about $1.85 billion.

The dominant forward catalyst is the NGL divestiture, expected to bring roughly $3.3 billion of net proceeds and lower pro forma leverage from about 4.1x to 3.5x, simplifying Plains into a focused crude-oil pipeline pure-play. The items to track are the closing and use of those proceeds, the trajectory of crude volumes through the Permian system (the core growth driver), the pace of contract resets on legacy tariffs, the distribution level and coverage, and overall US crude production trends. Because Plains is structured as a limited partnership, unitholders receive a K-1 and should weigh the tax treatment. The next quarterly print and the completion of the NGL sale are the key checkpoints for whether the deleveraging re-rates the units.

Peer Cohorts (Per Segment, With Filing Citations)

Crude Oil (reported)

NGL (reported)

Methodology Note

Fundamentals sourced from SEC EDGAR filings. Current price from Databento. The priced-in inversion and valuation x-ray are computed by the boothcheck engine; narrative composed by AI from the structured data.

View the full interactive PAA report on boothcheck