December Henry Hub natural gas futures settled near $3.23 per MMBtu on November 13, giving back part of the week’s sharp rally as the U.S. storage surplus widened again. The pullback came despite one of the strongest support factors in the market: LNG feedgas demand holding around 20 Bcf/d.
The contract had climbed as high as $3.397 on November 11, its strongest level since mid-October, before warmer forecasts and rebounding output triggered selling. With the December contract expiring on November 25, each storage report and weather-model shift is having an outsized impact on front-month pricing.
The market is now balancing two opposing forces. On one side, record export demand and still-heavy short positioning offer support. On the other, above-average injections, a mild November outlook and a fast supply response from producers are capping rallies.
Key Facts
- December Henry Hub natural gas futures traded at $3.23 per MMBtu late on November 13, down 10.7 cents or 3.2% from the prior settlement.
- The latest U.S. storage report showed a 61 Bcf injection, lifting inventories to 3,862 Bcf, or 54 Bcf above the five-year average.
- LNG feedgas deliveries reached a daily record of 20.3 Bcf/d on November 7 and averaged about 19.3 Bcf/d in early November.
- Lower 48 dry gas production recovered to roughly 112.2 Bcf/d after briefly falling to 109.2 Bcf/d on November 3.
- The December contract expires on November 25, leaving a narrow window for weather forecasts to influence final settlement.
Henry Hub Natural Gas
The immediate driver behind the latest price retreat was the storage trend. Although the 61 Bcf injection came in slightly below consensus expectations near 65 to 66 Bcf, it was still well above the five-year average build of 40 Bcf for the same week. That pushed inventories to 3,862 Bcf and widened the surplus to 54 Bcf, or 2.0% above the five-year norm. For traders, that trend mattered more than the small miss versus expectations.
At the same time, the demand backdrop remains constructive. LNG feedgas flows have repeatedly topped 20 Bcf/d, with forward indications touching 21 Bcf/d. That is historically high and reflects expanding U.S. export capacity and strong overseas pricing incentives. With European benchmark gas near €89.86 per megawatt-hour, U.S. export facilities have strong economic reasons to run close to full utilization whenever maintenance or weather disruptions do not interfere.
The result is a market stuck between a floor and a ceiling. Record export demand helps defend prices near $3.00, while surplus storage and recovering production make it difficult for futures to sustain levels much above the mid-$3.30s unless colder weather becomes more persistent. That tension is especially important for utilities, producers, LNG-linked companies and power generators heading into the core winter season.
Record LNG demand is keeping a floor under Henry Hub, but storage is still building fast enough to cap rallies until colder weather proves durable.
Why storage and weather are dominating the December contract
The December contract is unusually sensitive because of timing. It expires on November 25, which means traders are pricing not the entire winter, but a short stretch of late-November fundamentals. Forecasts showing colder temperatures in the eastern United States between November 16 and November 20 helped fuel the rally early in the week, but revised models suggesting a return to seasonal temperatures triggered long liquidation.
The official winter baseline also leans cautious. The U.S. Energy Information Administration expects November heating degree days to run 13% below the 10-year average and forecasts end-November storage at 3,840 Bcf, which is 67 Bcf above its prior projection. It also sees Henry Hub spot prices averaging $2.87 per MMBtu from November through March, below where December futures traded in mid-November. That gap highlights how much current pricing still depends on whether cold weather broadens beyond a short-lived burst.
Implications for Investors
For investors, the natural gas setup remains highly tactical in the near term. Front-month futures are likely to stay volatile as weather models update and traders react to the next storage report on November 19. A colder pattern extending beyond November 20 could quickly push December gas back toward $3.30 to $3.40, especially if speculative shorts are forced to cover. A return to warmer conditions would increase the odds of a retreat toward the low-$3.10s or even the upper-$2s.
Energy equities may respond differently than futures. LNG exporters and companies with Gulf Coast exposure could benefit from the structural growth in feedgas demand even if prompt-month gas prices remain choppy. By contrast, upstream producers are still facing a market where higher prices can quickly bring curtailed production back online, limiting upside. That is particularly relevant in regions such as the Haynesville, where supply can respond faster to stronger pricing.
Longer term, the story is more balanced than the front-month volatility suggests. LNG expansion, power demand growth and rising electricity needs from data centers are supportive for U.S. gas demand over the next several years. But investors should watch three variables closely: whether storage surpluses keep widening, whether production returns toward 114 to 115 Bcf/d, and whether export flows remain consistently near 20 Bcf/d or higher. Those factors will determine whether winter rallies can persist beyond short-term weather swings.
For now, Henry Hub natural gas remains a market of competing signals rather than a clear trend. The next several trading sessions before the November 25 expiry will likely decide whether December futures retest $3.40 or slip back toward levels more consistent with a mild-start winter outlook.