Natural gas futures have staged a rapid comeback, with the December Henry Hub contract trading at $3.29 per MMBtu on November 11 after touching an intraday high of $3.37. The move pushed prices above $3.241, a closely watched technical retracement level, and reinforced the market’s shift away from late-October lows.
The rally has been driven by a clear three-part catalyst: colder weather forecasts for the second half of November, weaker Lower 48 gas production, and record LNG feedgas demand of 19.3 Bcf/d. Together, those factors have forced traders to reprice winter risk after the contract traded as low as $2.90 on October 29.
Natural gas futures are now up 13.4% in eight sessions, highlighting how quickly sentiment can turn in a market where weather, exports and positioning all matter at once. With the December contract set to expire on November 25, investors are watching whether this breakout can hold under fuller market participation.
Key Facts
- The December Henry Hub contract traded at $3.29 per MMBtu on November 11, up 6.6 cents from the prior settlement, after reaching $3.37 intraday.
- Since falling to $2.90 on October 29, the contract has gained 39 cents, or 13.4%, in eight sessions.
- Average LNG feedgas flows reached a record 19.3 Bcf/d in November, up from 18.4 Bcf/d in October.
- Lower 48 dry gas production has averaged 112.2 Bcf/d in November, down from 115.0 Bcf/d in August.
- Working gas in storage stood at 3,801 Bcf for the week ending October 30, 109 Bcf below the year-ago level and 55 Bcf above the five-year average.
Natural Gas Futures
Natural gas futures moved higher after the market broke above $3.24, a level that traders had treated as a key upside threshold on the December contract. The advance followed a 5% jump earlier in the week, with the market responding first to colder weather expectations and then to confirmation that supply-demand balances are tightening. A second straight close near three-week highs also helped trigger trend-following buying.
The fundamental backdrop has become more supportive. Production has eased from summer highs, while export demand remains exceptionally strong as U.S. LNG terminals run near capacity. Average feedgas flows of 19.3 Bcf/d now absorb roughly 17.2% of Lower 48 dry gas output, reducing the buffer available for domestic storage and winter heating demand.
For utilities, producers and commodity-linked investors, the move matters because it shifts the market narrative from surplus risk to tightening winter balances. Prices remain far below the January peak of $7.46 per MMBtu, so this is not a return to crisis pricing. Instead, it is a repricing from depressed autumn levels as winter demand approaches and the market reassesses how much gas will be available into late November and December.
Record LNG demand, softer U.S. output and colder forecasts have turned $3.24 from resistance into the level bulls now need to defend.
Why LNG and Production Matter Now
The export side of the market is becoming increasingly important in determining domestic gas prices. At 19.3 Bcf/d, LNG feedgas demand is running above October’s record average and well above longer-term annual benchmarks. As long as export terminals continue operating near full utilization, a large share of U.S. gas supply is effectively locked in regardless of domestic weather patterns.
At the same time, supply has slipped. November dry gas production in the Lower 48 is averaging 112.2 Bcf/d, down 1.2 Bcf/d from October and 2.8 Bcf/d from the August peak. Some of that decline reflects seasonal maintenance and regional pipeline constraints, but weak late-October spot prices likely encouraged some producers to curb output. If prices stay above $3, part of that supply may return, which could cap further gains.
Implications for Investors
For investors, the main issue is whether this rally can extend toward the next resistance zone around $3.39 and potentially $3.60 before the December contract expires. The bullish case depends on three conditions holding together: production staying below 113 Bcf/d, LNG feedgas remaining above 19 Bcf/d, and weather forecasts preserving the colder late-November trend. If those inputs remain intact, the winter strip could continue to recover.
The near-term risk is the storage data and the weather model cycle. The next storage report, due on November 13 for the week ending November 6, will be critical because traders are looking for a build close to seasonal norms despite mild survey-week temperatures. A smaller-than-expected injection, especially near 60 Bcf or lower, would reinforce the tightening narrative. A larger print above 75 Bcf could revive concerns that the market still has enough supply cushion to absorb early winter demand.
Portfolio managers with exposure to gas producers, midstream operators or commodity-linked funds should also watch the December-January spread and contract roll dynamics. Large speculative short positioning has likely contributed to the speed of the rebound, meaning further upside could be amplified by short covering. But that same positioning can reverse quickly if forecasts turn warmer or LNG flows are disrupted by terminal outages. In practical terms, volatility is likely to stay high through expiry on November 25.
The next few sessions should show whether this is the start of a broader winter repricing or a sharp but temporary rebound from oversold levels. If weather stays supportive and export demand remains near records, natural gas futures may keep pressing higher into the second half of November.