South Korea and Japan Pivot to Coal After LNG Disruptions Hit Asian Supply
Iranian retaliation that removed 17% of Qatari LNG export capacity triggered the sharpest coal fuel-switch in both markets in years, with South Korea's April generation data showing a 39.7% year-on-year surge.
South Korea's coal-fired power generation surged 39.7% year-on-year in April (2026-04) to 10,733 gigawatt-hours, the steepest increase since August 2019, according to Korea Power Exchange data. Gas-fired output fell 6.4% over the same period. The reversal followed Iranian retaliation against US-Israeli strikes, which disrupted roughly 17% of Qatar's LNG export capacity — removing a critical swing supply source for Northeast Asian utilities that had been banking on spot cargoes to manage summer demand.3
Japan tracked a similar path. Coal-fired generation rose 11.1% in April (2026-04) — its fastest growth rate in at least a year — while gas-fired output dropped 12.9% to 16,447 gigawatt-hours, per the Japanese Electricity Market Data Hub. Nuclear output declined 2.7% in Japan and 14.6% in South Korea during April (2026-04), with further falls recorded in the first ten days of May (2026-05). The simultaneous retreat from both gas and nuclear left both systems leaning harder on coal heading into peak summer demand.3
Fei Xu, senior gas analyst at ICIS, estimated that Japan's shift alone displaced roughly four LNG cargoes in April (2026-04) — approximately half the annual import reduction the government had projected from efficiency improvements. That figure captures the scale of the displacement: a single month of supply disruption unwound half a year of anticipated demand-side progress.3
Vietnam compounded the regional picture. Coal-fired generation there rose 12.3% in April (2026-04) to a record 17,864 gigawatt-hours, according to government figures, driven by reduced LNG availability and a heatwave that pushed consumption toward grid limits across Southeast Asia. Across South Asia, power shortages in several Indian states in May (2026-05) approached levels last recorded in 2014, when outages were estimated to have cut roughly 5% from India's GDP. At current economic scale, analysts cited by Insurance Journal put the potential cost of more widespread and persistent shortages close to $100 billion. Hours-long daily blackouts affected Pakistan, Myanmar, Sri Lanka and India during the same period.3,2
The disruptions arrived as global electricity demand was already accelerating. The IEA said this year that demand is growing at its fastest pace in fifteen years, projecting a 3.6% average annual increase between 2026 and 2030, led by air conditioning, data centers, electric vehicles and industrial electrification. Meeting that trajectory would require annual grid investment to rise roughly 50% above the current $400 billion level, the agency calculated.4
Coal, still supplying approximately 35% of global electricity generation from around 2,100 gigawatts of installed capacity, remains the system's short-run shock absorber.1 Newcastle physical coal settled at $119.15 per tonne as of Tuesday (2026-07-07). JKM spot LNG was at $16.06 on the same date (2026-07-07), a level that continues to reflect the supply-side risk embedded in Asian markets since the Qatari disruption began.3
For traders, the pivot point is how quickly Qatari export capacity normalises. As long as LNG flows stay constrained, gas-fired generation in South Korea and Japan faces competition from coal at current price levels. If cargoes resume in volume before demand peaks in August, the coal premium should compress and utilities could rebuild gas burn. If they do not, both countries enter the highest-demand weeks of the year with a fuel mix weighted toward coal in a way their power system planners had not anticipated at the start of the season.3