Henry Hub natural gas stayed above $2.90 per MMBtu in early September, even as Europe’s Dutch TTF benchmark climbed above €73 per megawatt-hour, its highest level in more than three and a half years. Converted into the same units, European gas is trading near $24.80 per MMBtu, leaving a spread of roughly $21.90 versus the U.S. benchmark.
That gap is the defining feature of the current gas market. U.S. gas is cheap by global standards, but domestic prices are being restrained by record production, strong storage levels and a hard ceiling on how much gas can be exported as liquefied natural gas.
For investors, the disconnect explains why international gas stress is lifting LNG-linked equities and winter futures more than the prompt Henry Hub contract. The market is not short of molecules in the United States; it is short of export capacity.
Key Facts
- Henry Hub futures held above $2.90 per MMBtu, after touching about $2.95 earlier in September, the highest level in nearly two months.
- Dutch TTF futures rose above €73/MWh, up more than 130% since the start of the year and equivalent to roughly $24.80 per MMBtu.
- The price spread between European gas and Henry Hub is about $21.90 per MMBtu, meaning Europe is paying roughly 8.6 times the U.S. price.
- Lower 48 dry gas production is running near 115.0 Bcf/d, while U.S. inventories were 5.2% above the five-year seasonal average as of August 28.
- U.S. end-October storage is projected at a record 3,985 Bcf, even as LNG feedgas flows recovered to 18.3 Bcf/d in early September from 17.2 Bcf/d in August.
Henry Hub natural gas
The central question in Henry Hub natural gas is why domestic prices remain below $3 while overseas buyers are paying nearly $25 per MMBtu. The answer is infrastructure rather than supply. The United States is producing gas at close to record levels, but only a limited share can be moved abroad through LNG export terminals. Until more liquefaction capacity is built, U.S. gas prices will continue to reflect domestic balances more than global scarcity.
That limitation matters because feedgas demand has already recovered materially. The return of Texas LNG facilities and the completion of maintenance at Freeport lifted flows to about 18.3 Bcf/d in early September. But that increase mostly restored existing capacity rather than adding new export capability. New LNG trains take years, not months, to build, which means the arbitrage between Henry Hub and TTF cannot close quickly even when the spread becomes extreme.
Who is affected depends on where they sit in the value chain. LNG exporters and infrastructure owners benefit most directly from high overseas prices. Domestic gas producers gain more gradually as each new export outlet tightens the U.S. market over time. Meanwhile, U.S. consumers and power generators continue to enjoy relatively cheap fuel, at least until winter weather materially tightens the balance.
U.S. gas is not disconnected from the world by price; it is disconnected by liquefaction capacity.
Why record storage is capping the rally
The domestic storage picture remains a major brake on prices. Forecasts point to 3,985 Bcf in storage by the end of October, which would set a record for the close of injection season. A market entering winter with that kind of cushion needs either unusually strong heating demand or an export surge to sustain a sharp rally.
At the same time, production near 115.0 Bcf/d is limiting upside. A key structural factor is associated gas from oil drilling. With crude prices elevated, oil-directed activity remains attractive, especially in the Permian Basin, and that adds gas supply even when standalone gas prices are weak.
Implications for Investors
For commodity investors, the current setup argues for caution on the front-month contract. Henry Hub has support from stronger LNG feedgas flows, late-summer cooling demand and four consecutive weekly gains, but record storage and abundant supply are still capping near-term upside. Unless injections begin running consistently below seasonal norms or feedgas rises sustainably above current levels, rallies may continue to struggle around the $3.00 area.
The more compelling exposure may remain in export-linked equities and infrastructure names rather than in spot gas itself. Companies tied to liquefaction volumes and contracted export capacity are better positioned to capture the global price dislocation. Producers with strong Gulf Coast access also stand to benefit, but their upside depends more on winter strip pricing than on the prompt-month Henry Hub contract.
Investors should also watch the forward curve closely. December gas above $4 per MMBtu shows the market is pricing a tighter winter balance than the current prompt contract implies. That creates opportunity, but also risk, especially in leveraged products where contango can erode returns through roll costs. Key watch points now include weekly storage data, LNG facility reliability, European storage trends and weather forecasts for October through December.
The next phase for Henry Hub will hinge less on headline international prices than on whether colder weather and firm export demand can chip away at the U.S. storage surplus. Until then, the global gas crunch is likely to keep benefiting infrastructure and winter contracts more than the domestic spot market.