JKM Supply Signals Turn Unanimously Bearish as North American Export Wave Builds
ChAI's 31 supply signals for JKM are uniformly bearish, with a North American LNG export wave of up to 150 MTPA expected from late 2026.
JKM spot LNG closed Monday (2026-09-14) at $24.88/MMBtu, unchanged on the day, but ChAI's supply-side model has turned unanimously against the price. All 31 signals in the forecast index are pointing lower, with inventory and supply data the dominant bearish driver — a divergence that has grown more pronounced as the benchmark climbed nearly $8 since May.3,1
The climb from $17.10/MMBtu on May 19, 2026, per EnergyRiskIQ data, tracked real demand: seasonal Japanese cooling loads and European storage deficits that drew Atlantic LNG cargoes west. Supply signals now point the other way, with inventory data carrying the bulk of the bearish weight in ChAI's model.3,1
A North American export wave expected to add between 93 and 150 MTPA of LNG capacity from H2 2026 onward is the proximate supply threat, according to lngpriceindex.com. Commonwealth LNG in Cameron Parish, Louisiana, closed its offtake book on May 19, 2026 at its full 8.5 mtpa nameplate, with Glencore at 3 mtpa, EQT at 2 mtpa, Mercuria at 1.5 mtpa, PETRONAS at 1 mtpa and Aramco at 1 mtpa all contracted.2
Mercuria anchors the book after amending its 20-year supply and purchase agreement to take an additional 0.5 mtpa, with options to extend for up to 15 further years. The closed book shifts attention to a final investment decision; an FID would set the calendar for first cargoes from what would be another non-Hormuz US Gulf export source.2
US feedgas costs reinforce the competitive pressure. NYMEX Henry Hub front-month gas stood at $2.88/MMBtu on Monday (2026-09-14), well short of the US EIA's $3.80/MMBtu 2026 average forecast issued in May. The Atlantic LNG arbitrage runs from Henry Hub-linked feedgas costs through US Gulf liquefaction and ocean transit to Asian buyers; with the spread between US feedgas and JKM at its current width, existing US export facilities have every incentive to maximize throughput.1
Japan and South Korea account for roughly 35% of global LNG demand, and Japan alone relies on LNG for more than 35% of its electricity generation, per EnergyRiskIQ. The summer pull was genuine. Tullett Prebon forward data showed Tokyo's August baseload contract rising to ¥24.65/kWh on July 23, 2026, up 8.1% from ¥22.80/kWh on July 17, 2026, as cooling demand and fuel-risk concerns lifted near-term pricing across Northeast Asia.3,4
The July 30, 2026 curve showed Tokyo's August contract easing to ¥24.05/kWh and Kansai pulling back from ¥21.30 to ¥20.85, per Tullett Prebon. The heat premium had begun to fade even before the broader seasonal demand cycle ran its course.5
European competition has been a floor under JKM. ICE Endex TTF front-month gas rose 4.33% on Monday (2026-09-14) to €82.95/MWh. Converting at Monday's (2026-09-14) EUR/USD rate of 1.16, TTF trades at roughly $28/MMBtu, above JKM, an arbitrage that directs Atlantic basin LNG toward Europe and away from Northeast Asia, tightening supply available to Pacific buyers. In May 2026, EU gas storage stood at 36.6% against a seasonal norm of 55.0%, per EnergyRiskIQ, a gap that has kept European buyers competitive in spot cargo markets.3
But ChAI's $0.99/MMBtu upward contribution from traders' positions and price signals only partially offsets 31 bearish supply readings. Flat price action on Monday (2026-09-14) reflects a market that has found support from seasonal demand and European buying competition, not one that has absorbed the full weight of incoming supply.1
Commonwealth LNG's FID timeline, European storage recovery into autumn, and first-cargo dates from the broader North American pipeline will shape how much of the bearish supply consensus reaches JKM spot. If European storage fills enough to reduce transatlantic cargo competition, those volumes swing east, adding precisely the supply pressure that 31 signals are already anticipating.2,3