Natural gas markets experienced a notable shift in December, with prompt-month NYMEX prices falling from $4.92/MMBtu on December 8 to $4.01/MMBtu by December 15. After a volatile November driven by cold weather risks, the market cooled off as milder temperatures spread across the southern and middle U.S., triggering a broad-based sell-off. Production continued its strong run, averaging 109.3 Bcf/day, up 5.2 Bcf/day compared to last year, while storage levels remained healthy, sitting 103 Bcf above the 5-year average. LNG exports reached record highs, but gains were tempered by a drop in exports to Mexico and weather-driven demand swings. In addition, the PJM Interconnection’s latest capacity auction results were released this month, revealing a significant shortfall in procured capacity relative to the reliability target. This has raised concerns about future generation adequacy in the Mid-Atlantic region and reinforced broader market focus on supply security—adding further support to forward energy pricing sentiment. As 2025 ended, markets recalibrated with a more balanced tone: solid demand met by robust supply, with weather once again the wildcard heading into the new year.

Bull Factors:

-LNG exports averaged 18.6 Bcf/day in December, up sharply from 13.9 Bcf/day in the same period last year. This sustained growth confirms that LNG is no longer a marginal demand source but a core pillar of the U.S. gas market. Even temporary disruptions or weather-driven price declines cannot fully offset the long-term tightening effect of export demand. Fundamentally, higher LNG flows reduce the amount of gas available for domestic storage and consumption, increasing the market’s exposure to winter weather volatility and supporting forward price expectations.

-Despite the mid-December weather-driven selloff, December demand remained materially stronger year-over-year across every major consumption category. Power generation demand averaged 37.9 Bcf/day, residential and commercial demand climbed to 47.3 Bcf/day, and industrial demand increased to 26.4 Bcf/day. This broad-based growth is critical because it indicates that underlying consumption is expanding beyond just weather effects. From a market fundamentals perspective, when structural demand rises across multiple sectors, it raises the baseline level of consumption required to balance the system—making the market more sensitive to future cold events and reducing the downside durability of price weakness.

–While mid-December warmth weighed heavily on prices, cold air remained entrenched across Canada with above-average snowpack for the time of year. Forecasts from Constellation’s weather desk continued to call for a return of colder conditions in January, holding population-weighted heating degree day expectations steady. From a market standpoint, this setup creates asymmetric risk: prices can fall quickly on warm forecasts, but they rebound just as quickly when cold materializes. With demand already elevated and LNG exports pulling supply, even a brief January cold wave could tighten balances rapidly and restore upside pressure.

Bear Factors:

–As of mid-month, updated NOAA forecasts projected widespread above-normal temperatures across major demand regions, including the Midwest and Northeast. This fundamentally reduced residential and commercial heating loads, causing the January natural gas contract to collapse 22% on December 13, the largest single-day drop in over three years. From a market perspective, when forecast demand disappears, traders unwind long positions, utilities delay purchases, and pricing power vanishes, leading to a freefall in front-month pricing.

–U.S. dry gas production remained strong, averaging 109.3 Bcf/day in December, up from 104.1 Bcf/day year-over-year, reinforcing oversupply conditions. The EIA reported 3,746 Bcf in underground storage as of December 5, which is 103 Bcf above the 5-year average. This surplus served as a critical psychological anchor for the market. While prices spiked early in the month due to cold snaps, the elevated inventory levels gave market participants confidence that supply adequacy was not at risk—even in a volatile winter. Fundamentally, strong storage levels act as a buffer, reducing the likelihood of price spikes and diminishing urgency among utilities and large end-users to lock in supply at elevated costs. 

–LNG export feedgas demand dipped below 12 Bcf/day at several points in December due to maintenance at key terminals and weak global pricing spreads, especially in Europe and Asia. This bottlenecked U.S. liquefied natural gas outflows, pushing more gas back into the domestic system. Since LNG is the largest and fastest-growing demand segment in the U.S. natural gas balance sheet, any disruption here has a disproportionate bearish impact. With feedgas volumes reduced, excess supply has nowhere to go—further saturating the market and suppressing prompt-month pricing.

Final Takeaways:

December offered a clear shift in tone for natural gas markets, price gains were driven by colder weather, strong exports, and a rapidly tightening storage surplus. While risks remain from elevated production and potential warm spells ahead, the market appears to be stabilizing and rebounding off its autumn lows. If January weather turns colder than current forecasts suggest, we could see continued upward price momentum. We recommend monitoring early Q1 demand trends closely, as the winter heating season is now the primary catalyst for market movement.