HALLADOR ENERGY CO (HNRG) stock intrinsic value fair value estimate & owner earnings analysis

Hallador Energy owns the 1,080-megawatt Merom coal-fired power plant in Sullivan County, Indiana, which it bought from Hoosier Energy in 2022, and the Oaktown, Freelandville and Prosperity coal mines, which supply it. It sells electricity and accredited capacity (which buyers of power in the MISO grid must hold against their load) to utilities and other market participants, and sells coal to outside power plants. Starting point. We measure owner earnings as operating cash flow after removing working-capital swings, stock compensation and the part of capital spending that only maintains the plant and mines, then add back cash interest to see what the business produces before its lenders. On that basis the business produced about $56 million in 2023, $8 million in 2024 and $33 million in 2025 ($1.52, $0.21 and $0.76 per share). We start from the middle year, about $33 million. Earlier years describe a coal-based company before Merom, and 2022 was the transition year. Two accounting points matter. First, customers prepay for capacity and energy: prepayments stood at $149 million at the end of 2025 ($146 million in June 2026), and in 2025 the company received $137 million of prepayments while recognizing $143 million of revenue from them. We treat the build and release of that balance as working capital. Second, the $215 million 2024 write-down of the coal mines is a non-cash charge on money already spent, so it is not deducted. Of 2025 capital spending of $69 million, $13.6 million was for the expansion project at Merom; our method counted about $9 million of the year as growth rather than maintenance. The first half of 2026 was poor: a net loss of $24.6 million against a $18.2 million profit a year earlier, operating cash flow of negative $3.4 million against positive $49.8 million, and capital spending of $33.9 million. The company points to the annual planned outage on Merom Unit 1 and limited unplanned downtime on Unit 2 during high power prices, which forced it to buy replacement power: $23.5 million in the half, against $20.9 million for all of 2025 and $10.9 million in 2024. We read that rising trend as a real reliability cost for a plant that began operating in 1982 and 1983, and the cases carry it. Business cash flow rose from about $8 million in 2024 to about $33 million in 2025. For 2026 we assume a decline (the first half alone was roughly $35 million negative), then about $40 million in 2027, a recovery that rests on capacity prices already contracted for 2026 and 2027 (about $249 per megawatt-day in 2026), partly offset by lower contracted power prices ($43.32 per megawatt-hour in 2026 and $46.50 in 2027, against $48.82 realized in 2025). The company's expectation of better third-quarter volumes is not credited. Contracts. At the end of 2025 contracted revenue for power and outside coal was $867 million: $390 million in 2026, $336 million in 2027, $125 million in 2028 and $17 million in 2029. Outside coal sales are contracted at 2.73 million tons in 2026, 2.50 million in 2027 and 0.50 million in 2028, and none after. The coal segment earned $20.1 million of EBITDA in 2025 against $1.3 million in 2024, so losing those sales matters. In August 2026 the company reported capacity contracts averaging 765 megawatts in 2026, 789 in 2027, 768 in 2028, 608 in 2029 and 500 a year from 2030 to 2040, at prices rising to about $480 per megawatt-day from 2030, including a 12-year agreement signed on May 1, 2026. Some of these sales need approval from the Indiana Utility Regulatory Commission, which the company expects by November 15, 2026, and the filings do not say which ones. We therefore count none of the higher capacity prices that start in 2028 in any case; capacity revenue is held at its 2025 level of $58.1 million, which was the same in 2024. If the approvals come as signed, we estimate each case would be higher by roughly $4 to $5 per share (about $2.60, $8.20 and $16.90). Bear case: negative $2.07 per share. It combines another loss of about $10 million in the second half of 2026; replacement-power and reliability costs of $15 million a year through 2030; outside coal ending after 2028, with the mines running below capacity (a further $8 million a year, since the coal segment earned only $1.3 million on 3.9 million tons in 2024); and one downturn of the kind the company lived through in 2020, when revenue fell 24%, from $317.4 million to $244.2 million, and stayed low through 2021. We apply a 24% fall in energy revenue (about $60 million a year) in 2031 and 2032 and half that in 2033. It also loses the roughly $18 million of turbine and project deposits (construction in progress rose from $39.7 million to $58.0 million in the first half of 2026). The business is worth about negative $58 million, net debt is about $21.5 million and the deposits add $18 million, so the shares are worth about negative $98 million, or negative $2.07 per share: in this case the company owes more than the business is worth. Cash flow falls below the interest bill for several years, which lenders would not fund, so shareholders would likely lose everything. Base case: $3.46 per share. Starting from the $33 million level and adjusting only for contracts: second half 2026 about $9 million, 2027 about $40 million, 2028 about $23 million, then about $15 million a year to 2040. Energy sells at contracted prices (2028 $52.94, 2029 $51.33) and otherwise at the roughly $48.70 realized in 2024 and 2025; outside coal margin of about $17 million a year ends after 2028; maintenance capital spending stays near $60 million. 2040 is when the company now estimates Merom's life ends (it was 2032 until June 2026) and when the contracts end; nothing is credited after. The business is worth about $184 million, net debt is about $21.5 million, leaving $163 million, or $3.46 per share. No growth is credited. Bull case: $12.18 per share. Three levers execute: replacement-power cost returns to the 2024 level ($10.9 million), adding $10 million a year; outside coal is renewed at today's $56 to $59 per ton, adding about $14 million in 2028 and $17 million a year after; and a further 250 megawatts of capacity is sold at the $249 price of the 2026 contracts from 2029, adding $23 million a year. The evidence is that contracted capacity for 2028 rose from 454 to 768 megawatts in six months. The business is worth about $596 million, less $21.5 million of net debt, or $12.18. Left out in every case: the proposed 460-megawatt gas plant at Merom (cost below $800 million, operation targeted for the second half of 2028) has no final investment decision, no financing and no customers, so it is worth $0. The $350 million turbine purchase signed on May 30, 2026 is assumed to be neutral: the equipment either goes into a project that earns only its cost or is resold at its price. Its payment schedule is not in the materials we reviewed. Debt. Bank debt is $45.0 million at 7.11%, due $2.25 million in the rest of 2026, $4.5 million in each of 2027 and 2028 and $33.75 million on March 5, 2029, plus about $4 million of finance leases, against $29.0 million of cash. We add about $1 million because the loan costs more than a long bond. Covenants cap total leverage at 4.25 times and require fixed-charge coverage of at least 1.25 times (amended June 25, 2026); the company was in compliance at June 30 but says there is no assurance the covenants will allow it to finance the turbines. Share count rose from 30.6 million (2021) to 47.1 million (June 2026), including a January 2026 offering of 3.2 million shares. Margin-of-safety price: $3.00, once the regulator approves the pending capacity sales. We are not sure of the earnings level: business cash flow ranged from $8 million to $56 million in three years and the first half of 2026 was deeply negative, so the price reflects contracts and a demonstrated record, not recovery. The worst plausible event that no case models is that customers stop prepaying. They have paid $146 million for deliveries not yet made; if that is not renewed, revenue of that size arrives without cash, about $3 per share. Combined with the $350 million turbine commitment and covenants the company itself says may be tight, the likely consequence is share sales at poor prices or a forced equipment sale. Debt is small today, but commitments are large, the business rests on one 1980s-era plant and one mine, and the contracts are fixed-price. If we are wrong on reliability or the approvals, the shares are worth near the base or bear figures above. The company pays no dividend, so the price assumes a three-to-five-year holding period for the 2028-to-2040 contracts to appear in cash. At $3.00 the price is about what the shares are worth in our severe case if the approved contracts hold (about $2.60); the cushion for the unmodeled prepayment risk is thin, so the price is not set higher. Could not be reconciled or verified from the filings: which contracts need approval, the payment terms of the turbine purchase, and the cause of the first-half 2026 shortfall beyond the company's explanation. Full-year 2026 results are not yet available. Our September 2026 estimates were prepared on a different basis and are not comparable.