LNG Costs Push Japan's Power Prices to 3.5-Year Highs as Asian Buyers Pivot to Coal
JKM Asian spot LNG at $21.88/MMBtu is up 62% since the Iran conflict began, pressing Japanese manufacturers and narrowing LNG supply into Europe.
JKM Asian spot LNG held at $21.88 per million British thermal units as of Tuesday (2026-08-18), sustained by supply disruptions that have deepened since the U.S.-Iran conflict began. Prices have risen 62% since the war's outbreak, according to Reuters, an increase filtering through to Japan's wholesale electricity market and testing the cost tolerance of energy-intensive manufacturers across the region.2
Japan's day-ahead spot electricity prices surged 24% during the week of July 20 (2026-07-20) and hit their highest point since January 2023 on Wednesday, July 22 (2026-07-22), according to oilprice.com. The driver was a convergence of high fuel costs, a summer heat wave, and a yen that was trading around 159 to the dollar as of Tuesday (2026-08-18), amplifying the dollar-denominated cost of every LNG cargo.6
The supply shock traces directly to Qatari infrastructure. Iranian retaliation against U.S.-Israeli strikes knocked out an estimated 17% of Qatar's LNG export capacity, according to Reuters, removing a significant volume from one of the world's dominant gas export sources. Asian spot LNG prices had already risen 10% in the week ending July 13 (2026-07-13) to the highest since March, per oilprice.com, before the acceleration in the following week.2,6
Japanese and South Korean utilities responded by burning more coal. Japan's coal-fired power supply rose 11.1% year over year in April 2026 — the fastest pace in at least a year — while gas-fired output fell 12.9% to 16,447 gigawatt-hours, per Japanese Electricity Market data cited by Reuters. South Korea shifted harder: coal-fired generation jumped 39.7% year over year to 10,733 gigawatt-hours in April 2026, the largest annual increase since August 2019, according to Korea Power Exchange data.2
The switching accelerated in early May 2026. During the first ten days of that month, coal-fired supply was up 18.3% in Japan and 14.7% in South Korea, while gas-fired output fell 23.4% and 12.2% respectively, Reuters reported. Newcastle physical coal traded at $122.25 a tonne as of Tuesday (2026-08-18), up 13% since the conflict began — steep, but far below the 62% gain in LNG, leaving coal as the cheaper dispatchable option for utilities with the capacity to burn it.2
Broader Asian buyers are pulling additional supply. DBX Commodities, the London-based firm, estimated that May 2026 coal imports from Asian buyers outside China and India were set to rise 9.4% year over year to 31 million metric tonnes. Bangladesh has separately increased coal-fired generation and cross-border electricity imports, government data show, a sign the fuel switch is spreading beyond the headline importers.2,1
For Japanese manufacturers, the cost exposure compounds over time. Gas-fired generation typically sets Japan's marginal system price, so wholesale electricity tracks LNG closely. Oil-linked supply contracts introduce a further lag: price shocks reprice through formulas tied to crude benchmarks, meaning the full impact of a sustained high-oil environment arrives months after the spot market moves, according to asian-power.com. ICE Brent front-month crude stood at $91.33 a barrel as of Tuesday (2026-08-18).5,4
Japan has absorbed LNG-driven electricity crises before. In 2021, tight LNG supply sent wholesale prices to emergency levels, compelling regulators to cap them at ¥200 per kilowatt-hour. Russia's Ukraine invasion in 2022 triggered a second stress event, exposing limited hedging depth across Japan's power sector, as japan-nrg.com reported. The current shock runs both channels: a physical supply shortfall and a currency that makes every dollar of LNG more expensive in yen terms.3
Germany faces the Atlantic Basin version of the same pressure. ICE Endex TTF front-month traded at €63.62 per megawatt-hour as of Tuesday (2026-08-18), up nearly 3% on the day, while German spot power reached €134.46 per megawatt-hour. Germany expanded LNG import capacity rapidly after 2022 and now competes directly with Asian buyers for Atlantic and Middle Eastern cargoes. When JKM trades at $21.88 per million British thermal units, it narrows the arbitrage that would otherwise attract additional LNG volumes into northwest Europe, tightening TTF supply in turn.2
Wood Mackenzie analyst Lucas Schmitt said the conflict "will significantly reduce Asian LNG demand growth in 2026." His firm cut its forecast for Asian LNG imports to around five million metric tonnes from 12.4 million tonnes, assuming a two-month supply disruption — a reduction of roughly 60% in expected import volume. Global Energy Monitor estimated that about $107 billion in planned regional energy infrastructure investments could be at risk as developers weigh project economics against price and supply uncertainty.1
The duration of the Qatari capacity outage drives everything else. If that 17% reduction persists into the fourth quarter, Asian buyers will enter the heating-season procurement window with inventories already pressured — and the coal-heavy dispatch mix suppressing LNG demand this summer will reverse, pushing prices higher precisely when competition for cargoes is most intense.2,1