Whitehaven Coal Limited

Income statement: notes and sources

Notes: FY21 reference — revenue A$1,557.0m, EBITDA A$204.5m, NPAT before significant items A$(87.3)m, statutory NPAT A$(543.9)m (FY21 Results announcement). FY22/FY23 from FY23 Results announcement (FY23 revenue A$6,064.7m; EBITDA A$3,985.6m; FY22 revenue A$4,920.1m; EBITDA A$3,060.1m); FY23 NPAT headline "A$2.7bn" (A$2,668m per FY23 Annual Report; one secondary source rounds to A$2.6bn). FY24 D&A derived from FY24 comparatives in FY25 announcement. Whitehaven does not report gross profit as a line item. FY23 DPS 74c (32c interim + 42c final). FY25 DPS 15c (9c + 6c). FY26 DPS 10c (4c + 6c). FY26 "total adjustments to net profit" were +A$158m (FY25 +A$330m), principally remeasurement of the BMA contingent payment, FX gains and, in FY25, the Blackwater sell-down gain.

Margins (%)

All derived from 6.1.

Revenue CAGR: FY21–FY26 (5-year): 28.2% (derived: A$1,557m → A$5,401m). FY22–FY26 (4-year): 2.4%. The 5-year figure is flattered by the FY21 trough and the acquisition; organic like-for-like growth is far lower.

Operating drivers

FY23 metallurgical share approximated from management's statement that 94% of FY23 sales went to the thermal market.

Balance sheet

Notes: FY22 cash ~A$1.2bn (Morningstar summary of FY22 directors' report). FY23 net cash A$2.65bn (FY23 results). FY21 net debt A$808.5m. Gross debt structure post-April 2026 refinancing: US$900m senior secured notes (two US$450m tranches) plus US$475m term loan, with a US$125m revolver (drawn amount not disclosed). Deferred and contingent consideration payable to BMA (final US$100m deferred plus final contingent payment) is a material debt-like obligation outside reported net debt.

Quarterly net debt trajectory (FY26): ~A$0.8bn (30 Sep 2025) → A$0.7bn (31 Dec 2025) → A$0.6bn (31 Mar 2026) → A$1.33bn (30 Jun 2026, after the US$500m BMA payment on 2 April 2026).

Cash flow: notes and sources

Notes: FY25 total capital returned during FY25 (dividends + buy-backs) A$199m; 4.2m shares bought back in FY25. FY26 buy-back: 10.1m shares for ~A$77–79m (sources differ slightly: June quarter report A$77m; annual report summary A$79m). Development project expenditure FY26 A$47m (FY25 restated A$78m in the FY26 report vs A$119m reported in FY25 AR — the discrepancy likely reflects reclassification of Narrabri mains development; both figures noted). FY27 capex guidance A$390–490m, excluding deferred acquisition payments.

Ratios

All derived.

Commentary on trends, inflections and drivers

FY21 trough to FY23 super-cycle. FY21 was a low point: an A$80/t average price in H1, Narrabri geological problems and A$650m of pre-tax impairments produced a statutory loss of A$543.9m. The Russia–Ukraine energy shock then drove thermal coal prices to records; with ~94% thermal exposure, Whitehaven captured an average A$445/t in FY23, generating A$4.2bn of operating cash, a 66% EBITDA margin and A$2.65bn net cash while buying back ~9% of its capital.

FY24 inflection — redeploying the windfall. Rather than continue maximal returns, the board suspended buy-backs in August 2023 to fund the BMA acquisition. Thermal prices normalised, revenue fell 37% to A$3.8bn and EBITDA to A$1.4bn, though only three months of Queensland earnings were included.

FY25 — first full year of the enlarged group. Revenue rose 53% to A$5.8bn, but EBITDA was flat at A$1.36bn because the PLV HCC index averaged US$196/t (down 32%) and gC NEWC US$121/t (down 11%). Finance costs jumped to A$289m (vs A$22m) on acquisition debt and unwinding of deferred consideration. Underlying NPAT fell 57% to A$319m; statutory NPAT of A$649m was boosted by the Blackwater sell-down gain. Importantly, EBITDA per share grew >3x versus pre-deal, management's preferred lens.

FY26 — volume and cost offset price and FX. Revenue fell 7% to A$5.4bn as the average price declined to A$202/t (1H A$189/t, down ~19% YoY) and the AUD strengthened to 0.68. Managed production rose 3% and sales 8%; unit cost fell 5% to A$132/t after delivering the A$60–80m annualised savings target. EBITDA margin held at 23%. D&A rose 12% to A$682m. Underlying NPAT fell 29% to A$227m. Pricing improved sharply in Q4 (A$222/t vs A$189/t a year earlier) on LNG disruption and stronger Asian thermal demand.

FY27 set-up. Three tailwinds converge: (1) stronger benchmarks at the start of FY27 (PLV HCC US$215–235/t vs US$180–190/t a year earlier; gC NEWC ~US$130/t in July 2026 vs US$110/t), (2) A$50–55m annualised interest savings from refinancing, and (3) new rail contracts from 1 July 2026. Headwinds are diesel cost inflation, a guided unit cost range of A$132–147/t (midpoint above FY26 actual), and the final US$100m deferred and contingent BMA payments.

Management guidance (FY27)

Managed ROM 38.0–41.0Mt; managed sales 30.4–33.0Mt; equity sales 23.9–26.0Mt; unit cost A$132–147/t; capex A$390–490m. Management states the company is well positioned for improving markets, while flagging Middle East-related energy-market volatility.

Consensus expectations

Not publicly verified. Directionally, broker targets of A$9.80–10.50 imply ~28–37% upside from ~A$7.64, consistent with expectations of materially higher FY27 earnings on stronger benchmarks and lower interest costs.

Bull case

1. Price leverage on a fixed cost base: benchmarks have rebounded (PLV HCC US$215–235/t; gC NEWC ~US$147/t in Sept 2026) while unit costs were cut to A$132/t; at ~32Mt managed sales, every A$10/t increase in realised price adds roughly A$300m+ of revenue.

2. Free cash flow step-up from FY28: BMA payments end in July 2027 and interest costs fall A$50–55m p.a., freeing cash for returns and deleveraging toward the 0.5x end of the target band.

3. Valuation: ~6x EV/trailing trough EBITDA for Tier-1, long-life assets with Japanese steelmaker partners.

Bear case

1. Structural margin dilution: QLD progressive royalties and higher D&A mean earnings recover less than prices; FY26 underlying NPAT was only A$227m on A$5.4bn revenue.

2. Cost creep: FY27 unit cost midpoint (A$139.5/t) is above FY26's A$132/t, with diesel and labour inflation.

3. Terminal-value and ESG risk: thermal coal demand decline, approval litigation and capital access could compress multiples regardless of near-term cash generation.

Catalysts and monitorables (next 12 months)

Analyst verdict

Whitehaven has completed the most consequential transformation in its 27-year history. The FY23 windfall was redeployed into Blackwater and Daunia at a price whose deferred and contingent structure shifted much of the risk back to BMA, and the subsequent 30% Blackwater sell-down to Nippon Steel and JFE both funded the deal and embedded strategic offtake. FY25 and FY26 were, unfortunately for shareholders, the first two years of ownership and also the softest pricing years since FY21, which explains why EBITDA has stagnated around A$1.25–1.4bn despite a production base roughly double its pre-deal size.

The operational evidence is nonetheless encouraging. FY26 production and sales landed at the top of guidance, unit costs fell 5%, safety reached a record, and the April 2026 refinancing replaced short bank debt with notes running to 2031 and 2034 at lower cost. With the last BMA obligations falling away by July 2027, the business transitions from acquisition-servicing to unencumbered cash generation precisely as met and thermal benchmarks recover.

The central debate is the conversion rate of price into profit. Queensland's royalty regime, D&A of nearly A$700m and a cost guidance midpoint above FY26 actuals mean that headline price strength will not translate one-for-one into earnings. Investors also need to underwrite a terminal value in an industry facing long-run decarbonisation and persistent legal friction on approvals.

On balance, at ~6x trailing trough EV/EBITDA, with net debt near 1x and a clearly articulated 40–60% payout framework, Whitehaven offers asymmetric exposure to a coal-price recovery, particularly metallurgical coal into India and Southeast Asia.

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All figures in A$ unless noted. "n/a" denotes data not publicly disclosed in the documents retrieved during this research cycle and deliberately not estimated. Derived figures are analyst calculations from disclosed data.