Henry Hub natural gas remained pinned near $2.94 per MMBtu on November 5, underscoring a sharp split between the U.S. market and the global gas crunch. While Dutch TTF hovered near €85 per MWh and Asian LNG prices stayed close to $29 per MMBtu, U.S. futures barely moved after the latest federal storage data.
The key reason is domestic balance. U.S. inventories reached 3,801 Bcf after a 77 Bcf weekly injection, leaving storage slightly above the five-year average even as overseas prices remain many times higher. For traders, the immediate focus is whether Henry Hub can hold a floor around $2.90 without a meaningful cold-weather catalyst.
That divergence matters well beyond weekly trading. It highlights how U.S. gas prices are being set by storage, weather and production trends rather than by the geopolitical shock that has destabilized Europe’s gas market.
Key Facts
- December NYMEX natural gas futures traded near $2.94 per MMBtu on November 5, down about 0.5% on the session.
- The Energy Information Administration reported a 77 Bcf storage injection for the week ended October 30, below the 81 Bcf market expectation.
- Total working gas in storage rose to 3,801 Bcf, which is 109 Bcf below last year but 54 Bcf above the five-year average.
- Dutch TTF traded near €85 per MWh, or roughly $28 per MMBtu, while the JKM Asian LNG benchmark stood at $29.35 per MMBtu.
- Henry Hub cash gas traded at $2.63 on November 3, leaving December futures at roughly a 30-cent premium to spot prices.
Henry Hub Natural Gas
The latest price action shows a U.S. market struggling to respond to bullish headlines abroad. Even though European and Asian benchmarks remain near multi-year highs, Henry Hub futures are still trading in a relatively narrow band because export capacity, not global demand alone, determines how much U.S. gas can leave the domestic market. With LNG terminals already running near full utilization, higher overseas prices cannot immediately absorb additional U.S. supply.
Storage is reinforcing that pressure. The 77 Bcf injection came in slightly below expectations, which would normally be supportive. But the more important signal is that the build still exceeded the seasonal norm, widening the surplus versus the five-year average. At 3,801 Bcf, inventories appear comfortable enough to cover a typical start to winter unless weather turns materially colder.
Weather remains the most important near-term variable. Forecasts for early to mid-November have favored above-normal temperatures across much of the continental United States, keeping heating demand unusually soft for the season. That has allowed injections to continue at a healthy pace and limited the urgency for buyers to bid futures materially above the current range.
Henry Hub is not ignoring the global gas crisis; it is simply being priced by domestic weather, storage and export constraints rather than overseas panic.
Why U.S. Gas Is Decoupled From Global Prices
The spread between Henry Hub and global benchmarks is unusually wide. At about $2.94 per MMBtu in the U.S. versus roughly $28 to $29 internationally, the same fuel carries dramatically different valuations depending on where it is delivered. That gap persists because natural gas can only be exported as LNG, and liquefaction capacity cannot be expanded quickly in response to a price spike.
In practical terms, that means U.S. producers and LNG operators benefit from exceptional export economics, but the domestic benchmark still responds primarily to Lower 48 fundamentals. Until new export trains enter service in 2026 and 2027, the international crisis is more likely to support long-term demand for U.S. gas than to create an immediate breakout in Henry Hub futures.
Implications for Investors
For investors, the current setup suggests that weather risk remains the dominant short-term catalyst. If late November turns colder, the December contract could recover quickly as the market reprices winter demand and trims the storage cushion. If warmth persists, futures may drift toward the low end of the recent range, especially as the front month converges toward softer cash prices.
Energy equities and commodity-linked funds may also react differently from the headline move in global gas benchmarks. U.S.-focused producers are facing a domestic price environment below many earlier expectations, with front-month futures 15.5% under the federal full-year forecast of $3.48 and below the projected 2027 average of $3.16. That limits margin expansion for gas-heavy drillers unless colder weather or production restraint tightens the market.
Investors should also distinguish between upstream gas exposure and LNG infrastructure exposure. Exporters and companies tied to liquefaction capacity stand to benefit from wide international spreads and firm long-term contracting demand, while exchange-traded products linked to front-month gas futures remain vulnerable to contango. With December futures above spot and winter contracts carrying additional premiums, roll costs can erode returns even if headline gas prices appear stable.
The next major watch points are weekly storage changes, any shift in NOAA temperature forecasts, and signs that production is either easing or staying near record levels. Unless a colder pattern arrives soon, Henry Hub is likely to remain trapped by comfortable inventories and limited export upside.