Originally published February 17, 2026 — Updated April 2026
The global coal market entered 2026 navigating a complex terrain of price fluctuations, production uncertainties, and evolving decarbonization pressures. Eleven days after this article was first published, the Strait of Hormuz closed — and the "gradual contraction" thesis that anchored the original analysis was overtaken by events.
This update integrates the post-Hormuz reality into each of the three dimensions covered in the original: price dynamics, production shifts, and the policy landscape.
Price dynamics: the pre- and post-Hormuz picture
Metallurgical coal (pre-Hormuz): At the time of original publication, met coal prices were supported by supply disruptions and tight availability, with values above $250/t. Trading Economics had projected coking coal to trade at $223.98/t by end of Q1 2026, reaching $238.23/t in 12 months.
Metallurgical coal (April 2026): The PLV hard coking coal index dropped approximately $20/t in a single week following the Hormuz closure — not because demand weakened, but because freight costs surged simultaneously, compressing netbacks. Bunker fuel prices in Singapore rose nearly 30% week-on-week. War risk premiums entered voyage economics. The result: FOB prices came under pressure even as underlying demand remained firm. This is a temporary distortion. India's structural met coal import requirements — projected to grow from 58 million tonnes in 2024 toward 95-105 million tonnes by 2030 — are unaffected by a geopolitical event in the Persian Gulf.
Thermal coal (pre-Hormuz): The February baseline had Newcastle FOB 6000NAR around $117/t, with the market expecting continued gradual softening as Chinese renewable capacity displaced coal in the power mix.
Thermal coal (April 2026): Newcastle FOB last traded above $165/t. The move — approximately $48/t or 41% from the February baseline — is driven primarily by LNG displacement. QatarEnergy declared force majeure on LNG deliveries following strikes on Ras Laffan. Asian LNG spot prices surged above $20/mmbtu. Power utilities across South Korea, Japan, Taiwan, Thailand, and Bangladesh switched to coal. The gradual contraction in seaborne thermal coal demand described in the original Bench Energy view is on hold.
Production shifts: Indonesia, Australia, and the supply response problem
Indonesia: The February article noted Indonesia had lowered its thermal coal reference prices, with the average at $32.14/mt FOB in early February, reflecting uncertainty around 2026 production quotas. That uncertainty has been resolved in a direction no one anticipated.
Indonesia's plan to cut production from approximately 480 million tonnes toward 450 million tonnes in 2026 was calibrated for a market in managed decline. With LNG displacement pulling thermal coal demand sharply higher, the price floor Indonesia was trying to establish has arrived faster than planned — and at a much higher level.
The question is whether Indonesian producers can reverse course quickly enough to capture the upside. Given the regulatory nature of Indonesia's export management and the lead time required to ramp production, the supply response is likely to lag the demand signal by at least one quarter. Indonesian supply constraint and Hormuz demand shock are compounding simultaneously — a combination that supports prices through at least Q2 2026.
Australia: Production trajectory is unchanged: output forecast to grow 3.9% to 483.2 million tonnes in 2026, driven by the Maxwell underground project and capacity expansions at Byerwen and Narrabri. The supply is there. But Australian producers are not capturing the full benefit of higher FOB prices because freight costs have also risen sharply. The spread between FOB price and landed cost for Asian buyers has compressed.
Russia: The geographic pivot from Europe to Asia — from 55% European sales pre-2022 to 85% Asian sales in 2024 — continues. Russian coal is offering significant price discounts to Asian buyers. The Hormuz disruption has not materially altered Russian export logistics, which route through Pacific ports rather than the Persian Gulf.
Policy landscape: energy security overrides decarbonization (for now)
The February article cited Ben Jones from Tennessee Valley Authority on the need for policy stability, cost certainty, and capital frameworks for long-term investment decisions. That observation was made in the context of a gradual energy transition. The Hormuz shock has stress-tested it.
The policy response across major coal-importing economies has been immediate and consistent: energy security has temporarily overridden decarbonization commitments.
South Korea has imposed fuel price caps for the first time in 30 years and is evaluating relaxation of seasonal coal curtailments. The curtailments were implemented as part of air quality management policy. They are now being reconsidered under energy emergency conditions.
Taiwan is evaluating whether to restart mothballed coal capacity retired as part of its energy transition plan. The political cost of restarting coal units — significant under normal conditions — has been recalculated against the cost of power shortages.
India is increasing coal-based power generation to compensate for disrupted LNG supplies. The Coal Ministry has confirmed 210 million metric tonnes of coal stock — 88 days of consumption — and is actively dispatching coal-fired capacity at maximum utilization ahead of peak summer demand.
Europe is reassessing coal phase-out timelines. Germany and the Netherlands retain the most meaningful coal capacity to absorb demand switching. The political consensus around accelerated coal retirement that characterized European energy policy in 2024-2025 is under pressure.
The policy stability that utilities require for long-term investment decisions has been disrupted in a different direction than the February analysis anticipated. Rather than uncertainty about decarbonization policy, the uncertainty is now about how long energy emergency conditions will persist — and whether coal capacity that was scheduled for retirement should be preserved as strategic reserve.
Bench Energy view
The February 17 conclusion — that the medium-term outlook suggested gradual contraction in seaborne thermal coal demand driven by decarbonization — was accurate for the market that existed on February 17.
That market no longer exists.
The structural forces behind coal's long-term decline are intact. China's renewable buildout, India's domestic production expansion, the green hydrogen threat to met coal in the 2035-2040 timeframe — none of these have been cancelled by the Hormuz shock. They operate on decade timescales.
But commodity traders operate in real time. The near-term reality is:
- Thermal coal prices are roughly 41% above the February baseline
- Production cuts that made sense in a declining market are now constraining supply in a tightening one
- Policy frameworks built around gradual transition are being stress-tested by energy emergency conditions
- Freight costs have risen independently of commodity prices, adding a second layer of cost pressure
The complex terrain described in February has become significantly more complex. Traders who built 2026 strategies around the pre-Hormuz baseline need to revisit every assumption — price, freight, supply availability, and policy stability — in light of a disruption that has already exceeded the duration threshold at which cascading effects become systemic.
Sources: Westpac IQ, Trading Economics, Wood Mackenzie, Kpler, Supply Chain Intelligence Institute Austria (SCIA), Reuters, S&P Global, Newcastle FOB spot data