Peabody Energy Corporation — 2017 Form 10-K
Business context and reporting period. The filing covers the fiscal year ended December 31, 2017. Peabody mines thermal and metallurgical coal in the U.S. and Australia and also trades and brokers coal and freight. It emerged from Chapter 11 on April 3, 2017 and adopted fresh-start accounting, creating separate Successor (April 2–December 31) and Predecessor (January 1–April 1) reporting periods. Full-year figures below combine those periods where the filing does so; comparisons with 2016 are affected by the new accounting basis.
Financial and operating highlights
| Metric | 2017 | Prior comparable period / context |
|---|---|---|
| Revenue | $5.579 billion | $4.715 billion in 2016; up 18.3% |
| Operating profit | $885.2 million combined | 2016 operating loss of $276.9 million |
| Income from continuing operations, net of tax | $517.6 million combined | 2016 loss of $663.8 million |
| Net income | $481.6 million combined | Includes $19.8 million of discontinued-operations losses |
| Adjusted EBITDA | $1.487 billion combined | $532.0 million in 2016; non-GAAP measure |
| Operating cash flow | $1.011 billion combined | 2016 use of $52.8 million |
| Capital expenditures | $199.4 million | $126.6 million in 2016 |
| Cash and available liquidity | $1.012 billion cash; $1.244 billion available liquidity at year-end | Liquidity includes facility and receivables-program availability; excludes restricted cash and collateral |
| Debt | $1.461 billion, including capital leases and other obligations | 2016 debt was $7.791 billion, largely subject to compromise before reorganization; not directly comparable |
| Coal volumes | 191.5 million tons sold; 188.3 million produced | Sales up 2.5% from 186.8 million tons in 2016 |
Combined 2017 free cash flow, defined by the company as operating cash flow less investing cash flow, was approximately $932.9 million. The filing reports no full-year consolidated EPS that is directly comparable across the Successor and Predecessor periods.
Material changes and performance drivers
- Australian coal pricing drove much of the improvement: Australian Metallurgical revenue rose 42.1% and Adjusted EBITDA was $524.5 million, versus a $16.3 million loss in 2016. Australian Thermal Adjusted EBITDA rose to $382.2 million from $217.6 million.
- U.S. performance was mixed. Powder River Basin sales volumes rose 10.5%, but lower realized prices contributed to lower Adjusted EBITDA. Midwestern U.S. Adjusted EBITDA fell 19.7%; Western U.S. Adjusted EBITDA increased 78.9%, partly reflecting higher-margin volumes and $21.5 million of liquidated-damage settlements.
- Coal demand and seaborne prices strengthened in 2017, amid higher global steel production and supply disruptions. U.S. coal-fired generation declined 3%; higher average natural-gas prices supported Powder River Basin demand.
- Fresh-start accounting reset asset and liability values. Year-end assets were $8.181 billion and stockholders’ equity $3.656 billion; comparisons with predecessor balances require caution.
Outlook, risks and unusual items
- Outlook: For 2018, management estimated U.S. thermal sales of approximately 150 million tons at planned production levels, with about 90% of projected U.S. production priced. Australian targets were 19–21 million tons of thermal sales and 11–12 million tons of metallurgical sales. Planned 2018 capital expenditures were $275–$325 million, including approximately $85 million for mine extension and expansion projects. These are estimates, not assured results.
- Management expected U.S. power-plant retirements to reduce base coal demand by approximately 25–35 million tons in 2018 and projected an average 15–20 million-ton annual demand decline over the next five years from retirements. It cited natural-gas prices, renewables, weather and Chinese policy as significant market variables.
- Customer concentration: Five largest customers generated 27% of 2017 revenue. The Navajo Generating Station is the sole customer for a Western U.S. mine; its supply contract runs through December 2019. Closure could materially reduce revenue, EBITDA and cash flow and reduce reserves by about 180 million tons.
- Contractual and reclamation commitments: Take-or-pay obligations totaled approximately $1.337 billion, mainly for Australian rail and port capacity, with terms up to 25 years. Year-end asset retirement obligations were $691.1 million; reclamation bonding and other financial assurance requirements can consume liquidity.
- Unusual items: Results included $627.2 million of reorganization items in the January–April Predecessor period; full-year income-tax benefits totaling $424.8 million; and Successor-period gains including $52.2 million on the Burton Mine sale, $31.2 million from extinguishing a reclamation guarantee, and $28.0 million of break fees. These items affect interpretation of reported earnings.
- Contingencies and other risks: A creditor committee appealed the confirmation of the reorganization plan, seeking unspecified damages or discounted stock rights; Peabody says it will defend the appeal. A Queensland joint-venture dispute seeks damages ranging from A$15.6 million to A$1.8 billion; the company says the potential loss cannot currently be reasonably estimated. Other significant risks include coal-price volatility, competing fuels and environmental regulation, permits, mine safety, labor relations, foreign exchange, counterparty performance and debt covenants.
- The filing reports a material weakness in deferred-tax controls identified in 2017 and says remediation was completed and tested in the fourth quarter. Management and the auditor concluded internal control over financial reporting was effective at year-end; the financial-statement audit opinion was unqualified.
Important facts for investors to verify
- Review the Successor/Predecessor presentation and fresh-start adjustments before interpreting year-over-year earnings, assets, equity or EPS.
- Assess how sustainable 2017’s Australian coal-price uplift and $1.487 billion of Adjusted EBITDA may be under management’s stated market assumptions.
- Track the Navajo Generating Station’s ownership and operating plans beyond 2019, and the associated mine’s alternatives and closure exposure.
- Reconcile available liquidity with restricted cash, collateral, reclamation assurances, take-or-pay commitments and capital spending plans.
- Evaluate debt repayment, mandatory excess-cash-flow provisions, covenant limits on dividends and repurchases, and the effect of share repurchases and preferred-stock conversion on dilution.
- Monitor resolution and potential financial exposure from the creditor appeal, Queensland joint-venture litigation, and other legal, environmental and permitting matters.