December 22, 2025 — Natural gas markets are starting the holiday-shortened week with a familiar winter tug-of-war: early-season cold boosted prices and withdrawals, but a shift toward milder forecasts is now cooling bullish momentum even as LNG export demand remains elevated.
In the U.S., front-month NYMEX natural gas futures slipped close to 2% in morning trade as forecasters leaned warmer into early January and Lower 48 production continued to surprise to the upside. Overseas, European gas prices edged lower in thin pre-holiday trading as steady supply from Norway and LNG flows helped offset expectations of stronger heating demand. Meanwhile, a wave of policy and geopolitics headlines—from Australia’s new gas reservation framework to fresh Russia-to-China pipeline and sanctioned LNG shipping developments—kept global traders focused on 2026–2027 contract risk and supply security.
Natural gas price today: U.S. futures ease as warmth returns to the forecast
U.S. natural gas futures fell by roughly 1.9% in the morning session, with the January contract around $3.901 per MMBtu at 09:40 a.m. ET, pressured by both higher production and forecasts that point to warmer-than-normal temperatures into early January—conditions that typically reduce heating demand. [1]
This pullback follows a sharp early-December run-up that briefly pushed Henry Hub pricing to multi-year highs. The American Gas Association’s latest market indicators describe a clear shift in sentiment: after an early cold snap, demand has eased and futures have been “retreating,” with weather remaining the dominant driver of daily volatility. [2]
Key U.S. price context (December swing):
- The AGA notes the January prompt-month contract settled at $3.98/MMBtu on Dec. 19, down materially from early-month levels and well below the early-December peak (AGA cites a $5.29/MMBtu three-year high on Dec. 5). [3]
- Intraday trade on Dec. 22 briefly pushed toward ~$4.14/MMBtu in the AGA’s “time of writing” snapshot, underscoring how quickly prices can whipsaw on forecast changes. [4]
Weather forecast: the market is trading January warmth, not last week’s cold
The near-term narrative has shifted from “how cold did it get?” to “how warm will it be next?” Meteorologists cited in today’s market reporting expect the U.S. to remain mostly warmer than normal through early January, which would limit space-heating demand relative to seasonal norms. [5]
The AGA likewise points to holiday-period moderation, citing NOAA Climate Prediction Center outlooks that tilt above-normal across much of the country into the first week of the new year, with some regional exceptions. [6]
What matters for traders is not just temperature direction, but the speed and confidence of model changes. A single forecast shift can reprice the entire front of the curve, especially when liquidity thins around Christmas and New Year’s.
Production: record output is the bear case that won’t go away
Even in winter, it’s hard for prices to sustain a rally when supply keeps setting new highs.
Financial firm LSEG data referenced in today’s reporting shows average Lower 48 output climbing to a record 109.9 Bcf/d so far in December, eclipsing November’s monthly record. [7]
The AGA similarly notes that after hitting an all-time daily high late last month, production dipped briefly and then rebounded; as of Dec. 22, output remained meaningfully higher than the same period last year (AGA cites +4.8% year over year). [8]
Why this matters for “natural gas price today” searches:
When supply is printing records, bullish weather needs to be consistently colder than normal—not just briefly cold—to keep prices elevated. Otherwise, the market tends to sell rallies and reward storage comfort.
Demand and storage: withdrawals rose early, but inventories still look “okay”
Demand cooled week over week, but it’s not collapsing. The AGA reports total demand (including exports) for the week ending Dec. 22 fell 11.5% week over week while still running slightly above last year’s level for the comparable week. [9]
On the storage side, the latest widely cited U.S. weekly pull was sizable: the EIA reported a 167 Bcf withdrawal for the week ending Dec. 12, leaving working gas inventories at 3,579 Bcf. The AGA states stocks were about 0.9% above the five-year average at that point, though below year-ago levels. [10]
Bottom line: the early-winter drawdown was real, but strong production and still-comfortable inventories are limiting the urgency premium—especially when warmer forecasts appear.
LNG exports: record feedgas is still the structural bullish pillar
If there’s a consistent floor under U.S. gas demand, it’s LNG.
Today’s reporting puts average feedgas flows to the eight large U.S. LNG export plants at 18.5 Bcf/d so far this month, up from a prior monthly record in November. [11]
AGA’s December 22 indicators add more color:
- Feedgas deliveries were materially higher year over year (AGA cites +32.6% versus the first three weeks of December 2024). [12]
- U.S. LNG shipping set a weekly record earlier this month, with 40 vessels departing in the week ending Dec. 10 and a combined carrying capacity of 151 Bcf (as cited by AGA from EIA shipping data). [13]
In other words: even if residential/commercial heating softens on warmth, export pull can keep the overall balance tighter than it looks from weather alone.
Forecast: what EIA expects for winter prices, withdrawals, and 2026 supply
For readers looking beyond today’s tick-by-tick move, the EIA’s Short-Term Energy Outlook provides the clearest baseline forecast widely used in the market:
- EIA expects the Henry Hub spot price to average about $4.30/MMBtu this winter heating season (Nov–Mar), citing early-December cold and stronger space-heating demand than previously assumed. [14]
- Based on NOAA data, EIA assumes December will have more heating degree days than the 10-year average, boosting residential and commercial consumption and reducing storage. [15]
- EIA forecasts December withdrawals totaling ~580 Bcf and expects end-of-winter inventories around 2,000 Bcf (still above the five-year average in their outlook). [16]
- For 2026, EIA projects U.S. dry gas production averaging about 109 Bcf/d, with higher gas-to-oil ratios in the Permian contributing to supply growth. [17]
This is the macro framework traders are testing daily against real-time weather and production data.
Europe natural gas today: TTF edges lower as Norway and LNG supply offset cold risk
European prices opened the week slightly softer, with trading described as narrow and holiday-thinned.
Reuters reporting cited Dutch February TTF down modestly to about €27.70/MWh in morning trade, while UK day-ahead prices also eased. Market participants pointed to steady Norwegian pipeline supply and LNG availability offsetting the colder-demand outlook. [18]
Storage remains the key European risk variable. Reuters also cited Gas Infrastructure Europe data putting EU storage around 67.24% full, and noted that lower inventory levels could encourage additional LNG procurement into January and February if winter demand strengthens. [19]
European takeaway: the region is not “out of gas,” but it is more sensitive to cold snaps and supply disruptions than it would be with storage closer to last year’s levels.
Australia gas policy: mandatory domestic reservation set to reshape 2027 contracts
One of the biggest policy headlines of Dec. 22 comes from Australia, where the government unveiled a domestic gas reservation framework aimed at preventing future east-coast shortages and smoothing price spikes.
Reuters reports the plan would require LNG exporters on Australia’s east coast to allocate 15% to 25% of output for domestic use starting in 2027, with the mechanism designed around new contracts rather than existing long-term commitments. [20]
Australian media reporting frames the move as a “historic” shift for the east coast and suggests reserved volumes could reach hundreds of petajoules annually, with the policy intended to slightly oversupply the domestic market and put downward pressure on prices. [21]
Why this matters globally: Australia is a top-tier LNG exporter into Asia, and any policy that changes how incremental supply is marketed can ripple into longer-dated LNG pricing, portfolio contracting strategy, and buyer diversification plans.
Russia and global supply: China pipeline volumes rise, sanctioned LNG cargoes move
Two Russia-linked gas developments reported on Dec. 22 underscore the market’s geopolitical undercurrent:
1) Russia-to-China pipeline gas is rising fast—but it doesn’t replace Europe
A Reuters report says Russian pipeline exports to China via Power of Siberia are expected to reach ~38.6–38.7 bcm in 2025, up from 31 bcm in 2024, and roughly at/above the pipeline’s planned annual capacity. The report also notes discussions on additional projects (including Power of Siberia 2), with pricing still a major hurdle. [22]
2) A tanker loaded LNG from a sanctioned Russian project
Reuters also reported that the LNG tanker Kunpeng loaded a cargo from Russia’s Portovaya LNG plant—despite Western sanctions—based on ship-tracking data. The vessel arrived Dec. 18 and departed with a cargo on Dec. 21, according to the report. [23]
For the market, these stories are less about today’s Henry Hub tick and more about future trade flows, enforcement risk, and how quickly supply can be rerouted when traditional buyers reduce purchases.
Natural gas outlook: 7 things traders are watching next
With Christmas approaching and liquidity thinning, the next moves could be driven by a small number of catalysts:
- U.S. temperature model volatility into early January (warmth vs. renewed cold shots). [24]
- Lower 48 production—whether record output persists or freeze-offs/maintenance tighten supply. [25]
- LNG feedgas and shipping cadence—any new daily/weekly export records, or outages that cut flows. [26]
- Storage trajectory—whether withdrawals meaningfully slow if warmth dominates late December. [27]
- European storage and wind/weather patterns—which affect both gas-fired generation and LNG bidding intensity. [28]
- Australia’s reservation design details—especially how “15%–25%” is applied across projects and contract types. [29]
- Russia-related trade and sanctions enforcement—pipeline expansion negotiations and sanctioned LNG cargo movements. [30]
References
1. www.bairdmaritime.com, 2. www.aga.org, 3. www.aga.org, 4. www.aga.org, 5. www.bairdmaritime.com, 6. www.aga.org, 7. www.bairdmaritime.com, 8. www.aga.org, 9. www.aga.org, 10. www.aga.org, 11. www.bairdmaritime.com, 12. www.aga.org, 13. www.aga.org, 14. www.eia.gov, 15. www.eia.gov, 16. www.eia.gov, 17. www.eia.gov, 18. www.tradingview.com, 19. www.tradingview.com, 20. www.reuters.com, 21. www.theguardian.com, 22. www.reuters.com, 23. www.reuters.com, 24. www.bairdmaritime.com, 25. www.bairdmaritime.com, 26. www.bairdmaritime.com, 27. www.aga.org, 28. www.tradingview.com, 29. www.reuters.com, 30. www.reuters.com
