Henry Hub natural gas futures climbed to $3.26 per MMBtu on October 13, 2026, recovering from an intraday dip and reasserting support near the closely watched $3.10 level. The rebound came as traders balanced tightening winter weather expectations against a domestic supply picture still defined by record output and strong storage inventories.
The contrast with Europe is stark. Dutch TTF gas futures rose to €86.93 per megawatt-hour, the highest level since December 2022, leaving an international premium of roughly $26 per MMBtu over U.S. gas. That spread underscores why U.S. LNG export facilities are running near capacity, even as Henry Hub remains restrained by local fundamentals.
For investors, the central question is whether Henry Hub natural gas can break above recent resistance near $3.30 to $3.41, or whether record production above 111 Bcf per day and roughly 3.5 Tcf in storage will keep prices anchored in the low-$3 range.
Key Facts
- November Henry Hub natural gas futures traded at $3.26 per MMBtu on October 13, 2026, up 9.3 cents, or 2.94%, on the session.
- Dutch TTF gas futures climbed 3.06% to €86.93 per megawatt-hour, their highest level since December 2022.
- Lower 48 dry gas production averaged a record 111.5 Bcf per day in August, above July’s prior record of 110.7 Bcf per day.
- U.S. working gas in storage stood near 3,500 Bcf as of October 2 after an 85 Bcf weekly injection, the largest build since late June.
- The November contract has repeatedly held support around $3.10, while a move above $3.298 could open a path toward $3.396 to $3.41.
Henry Hub Natural Gas
The latest price action reflects a market caught between bullish global demand and bearish domestic supply. On one side, Europe’s gas market has tightened sharply as supply disruptions around the Strait of Hormuz have kept Qatari LNG flows constrained, lifting TTF prices into territory not seen since 2022. On the other, the U.S. market remains buffered by abundant production, solid late-season storage injections, and export capacity limits that prevent all of Europe’s price stress from feeding directly into Henry Hub.
That disconnect matters. With TTF near €86.93, equivalent to roughly $30 per MMBtu, U.S. LNG cargoes remain highly profitable. Feedgas demand at U.S. export terminals has been running near annual highs, around 19 Bcf to 19.6 Bcf per day, supported by the return of facilities from maintenance and the ramp-up of new capacity. But once terminals are effectively full, incremental overseas demand cannot absorb much more U.S. supply. As a result, Henry Hub gains support from global tightness without fully participating in Europe’s rally.
Domestic balances remain the decisive force. Storage near 3.5 Tcf is above the five-year average, and projections for end-October inventories approach 3.985 Tcf, potentially the highest level in a decade. Add record production above 111 Bcf per day, and the market has a sizable cushion against isolated cold snaps or short-term export surges. That leaves weather as the principal swing factor for the front-month contract heading into November.
Europe’s gas crisis is lifting the floor under Henry Hub, but record U.S. production and high storage are still capping the ceiling.
Why the $3.10 to $3.41 Range Matters
Technically, the market has built a clear near-term framework. The November contract has held the $3.10 to $3.105 zone for four straight sessions, an area reinforced by the 200-day moving average and a 50% retracement of the prior advance. Monday’s low of $3.092 effectively defined the lower edge of support.
On the upside, resistance near $3.298 is the immediate hurdle. A convincing break above that level would likely shift attention to the $3.396 to $3.41 area, where winter premium expectations become more visible in the curve. The November-December spread of roughly $0.315 shows that the market is already assigning greater value to later winter demand, even as prompt-month prices stay constrained.
Implications for Investors
For commodity investors, Henry Hub natural gas remains a market driven by asymmetry. The downside is limited to some extent by robust LNG demand, a firmer international backdrop, and producer economics that become challenging when prices fall too far below $3.00. But upside is also limited unless colder U.S. weather materially increases withdrawals or production slips meaningfully from record levels. In the near term, storage data and forecast revisions are likely to matter more than geopolitical headlines alone.
For energy equities, the split inside the sector is becoming more pronounced. LNG exporters and gas infrastructure companies are better positioned than pure-play producers if Henry Hub remains subdued while global benchmarks stay elevated. Exporters benefit from strong liquefaction margins and full utilization, while pipeline operators benefit from throughput. By contrast, upstream gas-focused producers still face margin pressure when domestic benchmarks lag the international market, even if the broader energy sector remains supported by stronger oil prices.
Exchange-traded products tied to front-month gas futures also deserve caution. In a market where winter contracts trade above nearby contracts, roll costs can erode returns for long-only vehicles. Leveraged funds amplify those effects, especially when prices remain range-bound and volatile around weekly storage releases. Investors using futures-linked products need to separate the global gas story from the mechanics of U.S. benchmark exposure.
The next major catalyst is the October 15 storage report covering the week ended October 9. A smaller-than-expected injection would strengthen the case for a breakout above $3.298, while another large build could send Henry Hub back toward the $3.10 floor. With winter approaching, the market’s balance of risk is shifting from storage accumulation to weather-driven demand.