Damage to Qatar's Ras Laffan LNG facility during the Middle East conflict has triggered a surge in Asian coal consumption, with an additional 70 million tonnes expected to be burned in 2026 alone, according to research from Rystad Energy published Monday. The shift is not a policy reversal but a brute-force response to a 35-million-tonne liquefied natural gas shortfall that gas-dependent utilities cannot close. Japan's coal-fired generation has already jumped 11% while its gas output fell 13%, Rystad reported.
The numbers are stark. Rystad Energy projects cumulative additional thermal coal consumption across Asia-Pacific will reach 150 million tonnes through 2030, with roughly half landing this year. The trigger is a supply gap, not ideology.
Qatar's Ras Laffan complex, damaged in the widening Middle East conflict, has declared force majeure and removed close to 10.2 million tonnes per annum of LNG supply destined for Asia. The partial shutdown is expected to stretch through late summer. That timeline terrifies utility operators.
The Japan Korea Marker, the regional LNG benchmark, has surged near three-year highs. Some demand is being destroyed by price. But most of the gap—an estimated 35 million tonnes per annum this year—is being absorbed by coal.
Rystad calculates roughly 90 terawatt-hours of electricity generation have shifted directly to coal-fired power. "What we are seeing is not a coal comeback but a reality check for APAC's energy transition," said Tonmit Talukdar, an analyst in Rystad Energy's coal research team. "Coal is stepping in when gas prices spike, supply tightens or mothballed plants are briefly restarted."
The policy says one thing. The reality says another. Across Northeast Asia, governments that had pledged to phase down coal are now removing regulatory caps to keep the lights on.
Japan's coal-fired generation grew 11% even as gas output fell 13%. South Korean and Japanese coal imports for May tracked more than 50% and 20% above year-ago levels, respectively. In Southeast Asia, Vietnam, Thailand and the Philippines are all running their coal fleets harder to offset tighter gas balances.
What this actually means for your family. Higher LNG prices eventually feed into electricity bills across the region. For manufacturing-heavy economies like South Korea and Japan, expensive power erodes industrial competitiveness.
For developing economies in Southeast Asia, it forces painful trade-offs between energy access and climate commitments. The contrast with the 2022 energy crisis is instructive. When Russia invaded Ukraine and disrupted gas supplies, global coal demand surged dramatically.
Renewable capacity was limited then. Coal inventories across major Asian markets were significantly lower. This time, strong stockpiles and record alternate energy availability in India, China and other major economies have prevented the market from becoming as structurally strained.
The response remains more contained, Rystad noted. China sits largely insulated. Its power sector has low gas penetration, meaning the LNG price spike contributes only marginal seaborne coal demand.
The pain is concentrated in gas-exposed systems: Japan, South Korea, Taiwan, and the fast-growing Southeast Asian economies that had bet heavily on LNG as a bridge fuel. Behind the pricing lies a simple mechanism. Newcastle 6000 kcal coal, the global benchmark for seaborne thermal coal, reflects marginal pricing conditions where shifts in gas availability, nuclear output and import dependence are most visible.
Under Rystad's base case, Newcastle coal averages around $125 per tonne in 2026 before easing to $115 in 2027. The decline assumes nuclear restarts in Northeast Asia and gradually improving LNG supply conditions ease regional fuel tightness. A darker scenario exists.
If hostilities resume and further disrupt energy infrastructure, Rystad estimates coal demand could rise by around 90 million tonnes in 2026 alone. Cumulative near-term demand would reach approximately 190 million tonnes, materially above the base case. The supply chain for coal remains untouched by the conflict.
That makes it the default fallback. No major producer has moved to sanction large-scale new mining projects or materially extend mine lives. This marks a sharp contrast to the period following Russia's 2022 invasion.
Governments have largely characterized recent demand increases as emergency-driven, reflecting system constraints rather than a structural policy shift. Producers like Glencore, BHP, Adaro and Bumi are watching and waiting. Any meaningful move toward new mine commissioning or significant life extensions would signal a durable shift in industry expectations.
For now, such investment responses remain limited. Producers still view current conditions as cyclical, not structural. That is the key signal.
Capital is not flowing toward new coal supply. The market is treating this as a temporary, conflict-driven spike rather than a permanent reordering of energy priorities. Why It Matters: The forced return to coal exposes the fragility of Asia's LNG-dependent energy transition.
Until storage, grid flexibility, and firm low-carbon capacity scale sufficiently to cover peak demand and periods of low wind or hydro output, coal will continue to serve as the system's fallback. Every disruption to gas supply—whether from conflict, infrastructure failure, or price spikes—will push emissions higher and delay climate targets across the world's fastest-growing energy market. - Asia-Pacific will burn an additional 150 million tonnes of thermal coal cumulatively through 2030 due to LNG supply damage from the Middle East conflict, with 70 million tonnes concentrated in 2026. - Japan, South Korea and Taiwan are leading the coal surge as regulatory caps are removed and nuclear restarts proceed slower than needed. - No major mining investments have been triggered, signaling producers view the demand spike as temporary and conflict-driven rather than structural. - A resumption of hostilities could push incremental coal demand to 90 million tonnes in 2026 and 190 million tonnes cumulatively, well above the base case. Watch the capital.
The single most important indicator of whether this coal surge becomes permanent is investment decisions from major producers. If Glencore, BHP, Adaro or Bumi announce new mine commissioning or significant life extensions, the market is signaling a structural shift. For now, they are holding back.
Every month the facility remains partially offline tightens the LNG market further and pushes more generation toward coal. Nuclear restarts in Japan will provide some relief, but the schedule remains uncertain. The next six months will determine whether 2026 becomes a temporary emissions spike or the start of a longer detour from Asia's clean energy path.
Key Takeaways
— Asia-Pacific will burn an additional 150 million tonnes of thermal coal cumulatively through 2030 due to LNG supply damage from the Middle East conflict, with 70 million tonnes concentrated in 2026.
— Japan, South Korea and Taiwan are leading the coal surge as regulatory caps are removed and nuclear restarts proceed slower than needed.
— No major mining investments have been triggered, signaling producers view the demand spike as temporary and conflict-driven rather than structural.
— A resumption of hostilities could push incremental coal demand to 90 million tonnes in 2026 and 190 million tonnes cumulatively, well above the base case.
Source: OilPrice.com
