Record US LNG Exports Face Demand Headwinds as TTF and JKM Prices Rise
More than 73 million tonnes left US terminals through July 2026, but TTF near €73/MWh and JKM at $24/MMBtu are compressing margins for cost-sensitive buyers.
U.S. LNG producers shipped more than 73 million tonnes in the first seven months of 2026, up 23% from the same period a year earlier, according to a Reuters analysis published on August 23 (2026-08-23). That pace, if sustained, extends a run of records that has already restructured global gas supply. Elevated prices at key destination markets are now testing whether that demand holds.6,7
ICE Endex TTF front-month gas closed at €73.33/MWh on September 7 (2026-09-07), up 1.92% in that session, while JKM front-month settled at $24.02 on September 8 (2026-09-08), well above the levels where cost-sensitive industrial and power-sector buyers typically begin switching fuels or cutting consumption. NYMEX Henry Hub front-month at $2.96 on September 8 (2026-09-08) leaves U.S. liquefaction economics intact. The stress is at the receiving end.6
The growth behind those volumes was compressed into a decade. In 2015, U.S. LNG exports totalled less than 0.03 trillion cubic feet. By 2025 they had reached 5.2 trillion cubic feet, good for a 25.4% share of the global LNG export market, according to the Energy Institute's 2026 Statistical Review of World Energy. U.S. export volumes grew 27% last year, from 4.1 trillion cubic feet in 2024, and the United States supplied roughly 93% of all incremental LNG trade in 2025, contributing approximately 1.10 trillion cubic feet of a 1.2 trillion cubic feet increase in global volumes, oilprice.com reported on July 24 (2026-07-24).5,3
The EIA projected in its July 2026 short-term energy outlook that U.S. LNG gross exports would average 17.4 billion cubic feet per day across 2026 and 2027, up from 15.1 bcf/d in 2025. The quarterly build is steep: 16.7 bcf/d in the third quarter of 2026, rising to 18.0 bcf/d in the fourth quarter and 18.7 bcf/d in the first quarter of 2027.4
S&P Global, in analysis highlighted by Rigzone on July 20 (2026-07-20), argued that flexible U.S. LNG has transformed export capacity into a domestic price shock absorber, a dynamic the Iran conflict earlier this year appeared to validate: Henry Hub prices fell even as global gas benchmarks spiked. That resilience underpins the supply-side optimism. But a low Henry Hub protecting domestic consumers is a different condition from the one faced by buyers paying €73/MWh in Europe or $24 in Asia.4,2
Global natural gas consumption grew just 0.5% in 2025, well below U.S. production growth of about 3%, which was itself driven by high prices and strong export demand. Thin consumption growth signals that buyers have already begun adjusting. The volumes most exposed to further pullback are spot-market cargoes purchased outside long-term U.S. offtake agreements; buyers locked into contracted volumes will load regardless of short-term price movements.1,6
S&P also modelled an "Extended Pause" scenario in which U.S. LNG capacity additions sanctioned after January 2025 were not built out. Under that assumption, global LNG markets would tighten significantly by 2031, pushing European and Asian gas prices roughly 50% higher and redirecting up to $76 billion per year to non-U.S. energy suppliers, S&P estimated. New England and New York peak winter gas prices could fall more than 20% in the 2028 to 2031 period if the capacity additions proceed as planned, according to the same study.4,2
The physical ramp is real and the EIA's quarterly forecasts imply it continues. What is less clear is how much incremental volume clears spot markets with TTF near €73/MWh and JKM at $24. The first indicator worth tracking is spot cargo deferral and destination-switch activity in shipping data. If those patterns emerge at scale before the northern hemisphere winter reload season, the endurance test Reuters columnist John Maguire flagged on August 23 (2026-08-23) is arriving earlier than the supply projections account for.6,7