Business context and reporting period
Plains All American Pipeline, L.P. (Nasdaq: PAA) filed this Form 10-K for the fiscal year ended December 31, 2023. It operates crude oil and NGL pipelines, storage, terminals, gathering, processing and marketing businesses across the United States and Canada, with substantial Permian Basin exposure. The filing provides annual comparisons; standalone fourth-quarter financial results are not clearly provided in the supplied text.
Financial results and key metrics
| Metric | 2023 | 2022 |
|---|---|---|
| Total revenue | $48.712 billion | $57.342 billion |
| Operating income | $1.510 billion | $1.292 billion |
| Net income attributable to PAA | $1.230 billion | $1.037 billion |
| Basic and diluted net income per common unit | $1.40 | $1.19 |
| Adjusted EBITDA attributable to PAA (non-GAAP) | $2.711 billion | $2.510 billion |
| Net cash provided by operating activities | $2.727 billion | $2.408 billion |
| Adjusted Free Cash Flow after distributions (non-GAAP) | $809 million | $828 million |
| Total debt at year-end | $7.751 billion | $8.446 billion |
- Revenue fell 15.1%, primarily as lower commodity prices reduced merchant sales and associated purchases. Product sales revenue declined 16%, while services revenue rose 25% to $1.738 billion.
- Operating income increased 17% and PAA-attributable net income rose 19%. Adjusted EBITDA attributable to PAA increased 8%. Implied distributable cash flow available to common unitholders was $1.726 billion; reported common-unit cash distributions were $748 million, leaving $978 million of implied excess DCF.
- Operating cash flow improved by $319 million. Net investing cash use was $702 million and net financing cash use was $1.976 billion. The filing does not provide a clear consolidated margin measure; commodity sales and purchases are large, substantially pass-through merchant activities.
- Year-end cash and cash equivalents were $450 million. Available liquidity was $2.640 billion, including cash and borrowing capacity, subject to covenant compliance. Working capital was in deficit by $90 million.
- Crude Oil Segment Adjusted EBITDA increased 9% to $2.163 billion, supported by higher pipeline tariff volumes, tariff escalations and acquisitions. Crude oil tariff volumes rose 12% to 8.460 million barrels per day. NGL Segment Adjusted EBITDA was nearly unchanged at $522 million; fractionation volumes fell 16% to 115,000 barrels per day.
- Common distributions paid during 2023 totaled $1.07 per unit, versus $0.8325 in 2022. The fourth-quarter 2023 distribution was $0.3175 per unit, paid in February 2024.
Material changes versus the prior comparable period
- Crude Oil performance strengthened on higher volumes, tariff escalations and acquisitions; fewer market-based merchant opportunities partly offset those gains.
- NGL Segment Adjusted EBITDA was broadly stable despite lower volumes, higher operating costs and the sale of the Keyera Fort Saskatchewan interest; favorable basis differentials and market opportunities helped offset these effects.
- 2023 included a $140 million gain on the Keyera facility sale and a $29 million gain from remeasuring the previously held OMOG interest. 2022 included a $330 million non-cash impairment of California crude oil assets and a $370 million gain from remeasuring the previously held Cactus II interest. These items affect year-over-year comparability.
- Interest expense declined to $386 million from $405 million, reflecting a lower average debt balance after senior-note repayments. PAA repaid $1.1 billion of senior notes in 2023 and ended the year with lower total debt.
- Operating cash flow benefited from working-capital changes, including lower NGL inventory and changes in hedging margin balances. Adjusted Free Cash Flow after distributions declined slightly despite higher operating cash flow.
Outlook, commentary, risks and unusual items
- Management expects meaningful multi-year free cash flow and prioritizes distributions, disciplined investment and maintaining investment-grade credit metrics. It did not provide a specific earnings or cash-flow forecast in the supplied text.
- 2024 investment capital is projected at approximately $465 million gross ($375 million net to PAA); maintenance capital is projected at approximately $250 million gross ($230 million net). Management expects to fund these expenditures primarily with retained cash flow.
- Key risks include crude oil and NGL volume and price-market changes, pipeline capacity overbuild and tariff pressure, customer and counterparty credit risk, commodity and interest-rate exposure, operational incidents, cyberattacks, extreme weather, permitting and environmental regulation, and access to capital. ExxonMobil represented 26% of 2023 revenue, up from 20% in 2022.
- Line 901 incident costs are estimated at approximately $750 million in total. At year-end PAA reported a $94 million gross remaining liability and a $225 million long-term insurance receivable; insurers have denied coverage for a substantial portion of the disputed claims, and arbitration is underway. Additional lawsuits remain pending. Recovery timing and amount are uncertain.
- Canadian tax authorities reassessed transfer-pricing matters for 2012–2018, with assessments, penalties and interest of approximately $165 million. PAA remitted approximately $87 million and disputes the reassessments; it has not recorded a related uncertain-tax-position liability.
- The Series A preferred distribution reset took effect in January 2023, setting the rate at 9.375% of issue price annually. Series B distributions float with SOFR plus contractual spreads; the February 2024 annualized rate was 9.75093%. Preferred distributions rank ahead of common distributions.
- The partnership reported compliance with debt covenants, effective disclosure controls and effective internal control over financial reporting. The independent auditor issued unqualified opinions on the financial statements and internal controls.
Important facts for investors to verify
- Review the sustainability of crude oil tariff-volume growth, contract commitments and renewal economics amid competition and capacity overbuild.
- Assess the quality and repeatability of earnings and cash generation, distinguishing merchant activity and working-capital effects from fee-based performance and non-GAAP adjustments.
- Track debt maturities, refinancing needs, liquidity and covenant headroom, particularly the $750 million of senior notes due in 2024.
- Monitor Line 901 insurance recovery proceedings, remaining claims and changes to the estimated liability or receivable.
- Follow the Canadian transfer-pricing dispute and potential cash, tax and interest consequences.
- Confirm 2024 capital spending, project execution, distribution coverage and the effect of floating-rate Series B preferred distributions.