Henry Hub natural gas futures hovered near $2.775 per MMBtu in late October, stabilizing after a sharp selloff tied to unusually mild U.S. weather forecasts. The most important near-term data point was a 77 Bcf storage injection for the week ended October 16, below the 83 Bcf market expectation.
That smaller-than-expected build helped slow the decline, but it did not change the broader setup. U.S. gas prices remain under pressure because heating demand has been delayed, even as Europe faces a severe gas crunch and Asian LNG prices remain far above domestic benchmarks.
The disconnect is striking: Henry Hub is trading below $3 while Europe’s TTF benchmark climbed to €88.41 per megawatt-hour and Asian LNG reached $26.39 per MMBtu. For investors, the message is clear: U.S. natural gas is being driven by domestic weather, storage, and export capacity constraints rather than global spot prices.
Key Facts
- Henry Hub November futures traded at $2.775 per MMBtu after falling 4.5% in the prior session.
- The latest EIA storage report showed a 77 Bcf injection, 6 Bcf below the 83 Bcf consensus estimate.
- Lower 48 working gas inventories rose to 3,644 Bcf, or 1.0% above the five-year average and 4.0% below year-ago levels.
- U.S. LNG feedgas demand averaged 18.1 Bcf/d in October and reached a record 18.9 Bcf/d on October 16.
- Europe’s TTF gas benchmark hit €88.41 per megawatt-hour on October 19, up 214% for the year.
Henry Hub Natural Gas
Henry Hub natural gas has entered the heating season with conflicting signals. On one side, inventories remain adequate on a national basis, and exceptionally mild forecasts through late October and early November have reduced immediate heating demand. On the other, storage builds have recently come in lighter than expected, LNG export demand is running at record levels, and some key regional inventories appear tighter than headline totals suggest.
The market’s recent weakness reflects weather first and foremost. The November contract has fallen through several technical levels after forecasts pointed to above-average temperatures across major U.S. demand centers. When shoulder-season warmth persists, utilities can continue injecting gas into storage rather than drawing supplies out, which weighs on front-month prices.
What makes this episode more unusual is the gap between U.S. gas and international pricing. Europe is dealing with low storage relative to seasonal norms and reduced LNG supply from Qatar after disruptions at Ras Laffan affected two of 14 export trains, or roughly 17% of capacity. Yet that overseas tightness is not lifting Henry Hub in the same way it might have in a looser export market, because U.S. liquefaction facilities are already operating near full capacity. Without spare export capacity, higher global prices cannot immediately pull significantly more U.S. gas abroad.
Global gas prices may be surging, but Henry Hub will not fully respond until colder U.S. weather arrives or export capacity expands.
Why storage still matters
The latest storage data offered only mild support, but it was meaningful because the summer surplus has narrowed. Inventories stood 148 Bcf above the five-year average in early September and have since moved much closer to normal seasonal levels. By October 16, the surplus had shrunk to just 1.0% above the five-year average.
Regional balances are even tighter. South Central storage, which is especially important because it connects to Gulf Coast LNG demand, sits well below year-ago levels. Salt cavern inventories in that region are particularly valuable during winter cold snaps because they can be withdrawn quickly. If temperatures turn sharply lower in November or December, those regional constraints could matter far more than the national average suggests.
Implications for Investors
For commodity investors, Henry Hub natural gas remains a weather-driven market in the short term. The latest storage miss and record LNG feedgas flows help establish a floor, but they are not enough to trigger a sustained rally while forecasts remain warm. Key levels to watch include support near $2.73, then $2.64 and $2.52, with resistance around $2.83, $2.955 and $3.07.
For equities, the setup differs across the natural gas value chain. Gas-focused producers such as EQT and Coterra are more directly exposed to Henry Hub pricing and may remain volatile if warm weather persists. LNG-linked names such as Cheniere are better insulated because their earnings depend more on export volumes and contracted infrastructure economics than on the domestic spot price alone. With feedgas near record highs, exporters remain supported by strong utilization even as U.S. benchmark prices lag global markets.
ETF investors should also be selective. Front-month natural gas funds can be highly sensitive to shifting weather models and contract rolls, especially when the futures curve is in contango. Leveraged products amplify that effect and may see outsized daily swings if forecasts turn colder or if storage data surprises again. A move toward colder temperatures in the first half of November could quickly reprice the winter strip toward the EIA’s projected $3.30 fourth-quarter average, while continued warmth could keep spot-month futures pinned near recent lows.
Looking ahead, the next storage report and daily weather-model changes are likely to matter more than overseas headlines. If cold weather arrives before inventories reach more comfortable winter levels, Henry Hub natural gas could close part of the gap with official winter forecasts; if not, the market may remain capped despite record LNG demand.