US LNG Export Surge Meets Elevated Buyer Costs in Europe and Asia
Record US shipments of 73 million tonnes in seven months mask a growing risk that high TTF and JKM prices curb demand from price-sensitive buyers.
ICE Endex TTF front-month gas climbed 3.14% to €71.96 per megawatt-hour on September 2, 2026, as traders weighed whether persistently high European import costs were beginning to test the appetite for record American LNG inflows. JKM, the Asian LNG benchmark, held at $23.61 per MMBtu the same day. NYMEX Henry Hub front-month gas, by contrast, changed hands at $2.94 per MMBtu — reflecting the feedstock price before liquefaction, shipping and regasification costs add their weight on the far end of the supply chain.
US producers shipped more than 73 million tonnes of LNG in the first seven months of 2026, up 23% from the same period a year earlier, according to Zawya's reporting on a Reuters column by Maguire. That pace makes the US the world's dominant LNG supplier. But buyers with limited ability to pass through fuel costs face increasingly uncomfortable arithmetic when both TTF and JKM stay elevated for sustained periods.4,5
The scale of US export dominance is worth stating plainly. The United States supplied approximately 1.10 trillion cubic feet of the 1.2 trillion cubic feet added to global LNG trade in 2025, roughly 93% of total incremental supply, according to data from the Energy Institute's 2026 Statistical Review of World Energy. US export volumes reached 5.2 trillion cubic feet by 2025, against less than 0.03 trillion cubic feet in 2015. The US share of global LNG exports stood at 25.4% as of last year.3
The US Energy Information Administration, in its short-term energy outlook released in July 2026, projected LNG gross exports averaging 17.4 billion cubic feet per day across 2026 and 2027, up from 15.1 billion cubic feet per day in 2025. The quarterly trajectory is steeper still: 16.7 billion cubic feet per day in the third quarter of 2026, rising to 18.0 billion cubic feet per day in the fourth quarter and 18.7 billion cubic feet per day in the first quarter of 2027.2
Whether buyers in Europe and Asia absorb those rising volumes without flinching depends partly on alternatives and partly on how long import prices stay above substitution thresholds. S&P, in a study highlighted by Rigzone in July 2026 (2026-07-20), argued that flexible US LNG has served as a domestic price shock absorber — Henry Hub prices fell even during the Iran conflict, which disrupted Hormuz transit routes, demonstrating the market's resilience to external shocks. But that flexibility works in both directions.2,1
The Hormuz disruption showed how quickly import markets can reprice. The World Bank's natural gas price index surged 24% month-on-month in March 2026, following the closure of the Strait of Hormuz, through which roughly one-fifth of global LNG normally transits. European and Asian buyers absorbed that shock. How many similar rounds of elevated pricing they absorb before trimming spot procurement is a harder calculation.6
S&P modelled the consequences of an Extended Pause scenario — one where new US LNG investment sanctioned since the lifting of the export pause in January 2025 was never realised. Their conclusion: prices roughly 50% higher for Europe and Asia by 2031, with up to $76 billion per year redirected to non-US suppliers, most of it flowing into coal and other fossil fuels. That scenario was constructed to justify continued US investment, but it also implies that American LNG's marginal buyer is sensitive to sustained import premiums.2,1
Henry Hub's relative calm at $2.94 per MMBtu on September 2, 2026 has kept US liquefaction economics solid for producers. The 23% export surge through July confirms that. But TTF at €71.96 per megawatt-hour and JKM holding at $23.61 per MMBtu suggest that buyers, particularly utilities and industrial end-users without long-term supply contracts, are already close to tolerance limits for spot cargoes.4,5
The fourth quarter will sharpen that pressure. EIA projects US LNG exports stepping up to 18.0 billion cubic feet per day in Q4, just as European winter demand typically lifts TTF and NBP prices. Whether cost-sensitive buyers in South and Southeast Asia, the market's growth frontier for spot volumes, pare back purchases before a seasonal correction arrives is the concrete signal to track over the next eight weeks.2,4