TotalEnergies: US Gas Price Spike Risks Cutting LNG Supply to Europe
With European storage nine percentage points below last year's pace, a Henry Hub surge prompting Washington to favour domestic consumers could leave buyers short.
U.S. NYMEX Henry Hub front-month gas prices actually fell during the recent Iran conflict, a study published on Wednesday (2026-07-16) noted — a data point that cuts both ways for European buyers who have grown structurally dependent on American LNG.7
TotalEnergies told Montel on Thursday (2026-06-25) that Europe's reliance on U.S. LNG imports poses little immediate concern at current Henry Hub levels. The company's warning came with a precise caveat: a sustained jump in NYMEX Henry Hub front-month could pressure Washington to restrict exports in order to shield domestic consumers, diverting cargoes away from Europe at the wrong point in the injection season.4
NYMEX Henry Hub front-month closed at $2.91 per MMBtu as of Friday (2026-07-18). ICE Endex TTF front-month settled at €57.51 per megawatt-hour on the same date. That spread makes U.S. LNG economics highly favorable for export, which is why European buyers have built their import strategy around American supply. U.S. LNG exports reached $44 billion in 2025, the July 16 study found — 2.3 times the value of U.S. corn exports.7
The storage deficit makes the dependency harder to absorb. European gas facilities stood at approximately 47% full as of Monday (2026-07-13), against 56% at the same point in 2025, according to data cited alongside reporting on that day's price move. ICE Endex TTF front-month gained 3.5% in that session to €50.37 per megawatt-hour, driven by renewed tensions around the Strait of Hormuz.6
Hormuz has been the dominant short-term price driver for European gas this year. Montel reported ICE Endex TTF front-month jumping 3% early on Tuesday (2026-05-19) after President Trump set a deadline for Iran to reopen the waterway. It fell more than 5% to around €46.3 per megawatt-hour in late May (2026-05-25) when U.S.-Iran talks showed signs of progress.1,3
A more durable supply disruption emerged from Qatar. Attacks on the Ras Laffan industrial complex — responsible for around 20% of global LNG supply — left 17% of Qatari LNG capacity offline, with damage expected to keep that production curtailed for three to five years, according to Q1 2026 market analysis.2
Together, these events have shifted the structural importance of U.S. supply to European storage rebuilding. The top three European LNG terminals accounted for 30.1% of total LNG flows entering the continent — a concentration that leaves the European market sensitive to any policy or price shock affecting American exports.5,7
The July 16 study adds a medium-term dimension. Under a scenario where planned U.S. export capacity additions since 2025 are not realized, global LNG markets could tighten significantly by 2031, pushing prices as much as 50% higher for both Europe and Asia. The constraint is not political but logistical: domestic U.S. pipeline capacity to connect new production basins to liquefaction terminals remains the main bottleneck the industry faces.7
The near-term export-curb risk TotalEnergies identified remains low. NYMEX Henry Hub at $2.91 per MMBtu provides no political incentive for Washington to prioritize domestic consumers over export revenues. But the arithmetic shifts if a demand shock — or a further tightening of global LNG supply following Qatar's capacity loss — drives Henry Hub materially higher. European buyers who have used the current arb to substitute U.S. LNG for Norwegian or Qatari supply would find themselves exposed precisely when storage headroom is thinnest. The level at which Henry Hub prices begin generating domestic political pressure in Washington is the number European energy traders should be tracking through the rest of the injection season.4,7,6