Japan and Germany Absorb Higher LNG Costs as Middle East Supply Disruption Squeezes Asian Markets
Japan's power market hit a 3.5-year high in late July as Middle East LNG disruption pushed JKM spot prices to $22.94/MMBtu, raising manufacturing costs across Asia and Europe.
JKM Asian LNG spot prices stood at $22.94 per million British thermal units in the August 23 (2026-08-23) session, holding near a floor set by a Middle East supply shock that sent Japan's day-ahead electricity market to its highest point in three and a half years. Day-ahead spot electricity surged 24% in the week of July 20 (2026-07-20), reaching its highest since January 2023 on Wednesday, July 22 (2026-07-22), according to oilprice.com.6
Japan's industrial base pays the price directly. Marginal LNG-fired generation typically sets the clearing price in Japan's power market, according to Japan-NRG, meaning fuel cost spikes pass through to factory electricity bills almost immediately.4 The yen was trading at 158.94 per dollar as of August 23 (2026-08-23), and the currency's weakness amplifies the yen-denominated cost of every dollar-priced LNG cargo, adding further pressure on manufacturers that cannot quickly pass higher energy costs to customers.6
The disruption traces to conflict involving Iran, which has effectively closed the Strait of Hormuz to regular LNG traffic. Asian spot LNG prices surged 10% in a single week to their highest since March, by the week ending July 13 (2026-07-13), as Middle East re-escalation triggered a near-halt to shipping through the strait, oilprice.com reported.6,1 Japanese utilities had spent several years cutting their reliance on Middle Eastern supply. It was not enough.
Japan's utilities have shifted toward coal. By mid-May (2026-05-12), coal-fired generation was rising while gas-fired output was falling, as war in the Middle East made LNG expensive, oilprice.com reported.2 Newcastle thermal coal stood at $124.55 per tonne as of August 23 (2026-08-23), and a coal ETF tracking the sector rose 2.9% in the same session. But the shift is constrained.
Take-or-pay LNG contract structures limit operators' ability to reduce gas offtake even as spot economics deteriorate, leaving many utilities carrying above-market gas costs while also buying additional coal, according to Asian Power.5 Japan has been through versions of this before — in 2021, scarce LNG sent wholesale electricity prices to emergency levels and forced regulators to impose a cap of ¥200 per kilowatt-hour, according to Japan-NRG. In 2022, Russia's invasion of Ukraine delivered another shock through the same structural exposure.3
Wood Mackenzie has cut its forecast for Asian LNG imports this year to roughly five million metric tons, down from 12.4 million tons, assuming a two-month disruption to Middle East supply. "The conflict will significantly reduce Asian LNG demand growth in 2026," said Lucas Schmitt, an analyst at the consultancy.1 The revision strips out more than 7 million tons of expected Asian demand. That represents contracted supply, regasification bookings, and project economics premised on Middle Eastern LNG flowing freely.
Global Energy Monitor estimates around $107 billion in planned regional energy infrastructure investment is at risk from the sustained disruption.1 Projects sized against pre-crisis supply assumptions now face a market in which Middle Eastern LNG deliverability cannot be taken for granted.
Germany's exposure runs through a different channel. ICE Endex TTF front-month gas closed at €65.83 per megawatt-hour on August 22 (2026-08-22), and German front-month power settled at €135.17 per megawatt-hour the same day. European gas markets are not directly severed by Strait of Hormuz disruption. But the Atlantic LNG arbitrage links Asian and European spot benchmarks: when Asian spot premiums widen sharply, cargoes divert east, reducing volumes available to European terminals and placing upward pressure on TTF.
Across South Asia, Bangladesh increased coal-fired generation and imports of coal-based electricity in May (2026-05), according to government data, widening the regional pattern of fuel-switching away from constrained LNG.1 Analysts say high prices and supply uncertainty are likely to curb LNG demand growth across the region through the rest of the year.1
Wood Mackenzie's revised import forecast assumes a two-month disruption. If the Strait of Hormuz closure extends beyond that window, Japan's utilities face another round of spot LNG exposure heading into the winter gas injection season, and the $107 billion infrastructure pipeline already flagged at risk would require deeper revision.1