⚡Natural Gas MarketWatch — November 4, 2026: December Rebounds as Crude Steadies, but Warmth Still Caps Winter Premiums
December natural gas bounced back Tuesday, recovering almost all of Monday's slide — but the rebound stopped well short of $3.00, and the story has not changed: a warm start to the heating season, ample supply, and comfortable storage are keeping winter premiums in check, even as global energy tensions keep a floor under the broader complex.
Market Recap
The NYMEX December 2026 contract settled Tuesday at $2.895 per MMBtu, up 3.9 cents (+1.37%) from Monday's $2.856 close. That leaves December essentially flat versus Friday's $2.898 settlement — a round trip, not a breakout. Resistance sits near $2.93, then $3.00; support is near $2.80, which held through late October. Early Wednesday trading was again hovering near the high-$2.80s, a reminder that buyers are stepping in on dips but are not yet willing to chase prices higher on weather that has not turned cold.
Key Bullish and Bearish Drivers
Bearish forces still dominate the near term. NOAA's updated November outlook, issued October 31, expanded above-normal temperature probabilities across the northern U.S. and both coasts, with 60–70% odds of warmth over the Northern Plains and Upper Mississippi Valley. Its November 8–12 outlook favors above-normal temperatures across the West, north-central U.S., Northeast, and Great Lakes, with below-normal readings favored only in parts of the Southeast. Forecasts for mostly milder-than-normal weather through November 18 point to heating demand staying below seasonal norms.
The tropics are not adding support. The National Hurricane Center's 1:00 a.m. EST outlook Wednesday reported no active tropical cyclones, with only a low south of Bermuda given a 20% formation chance over 48 hours and 40% over seven days — and that system is tracking eastward over the open Atlantic, not toward the Gulf Coast.
On the bullish side, supply is easing at the margin, and global competition for LNG remains intense. LSEG data cited by Reuters put average Lower-48 production at 110.0 Bcf/d so far in November, down from 113.4 Bcf/d in October, while flows to nine major U.S. LNG export plants averaged 17.7 Bcf/d early this month, down from 18.4 Bcf/d in October but still a powerful demand floor. Meanwhile, Dutch TTF gas traded near €93/MWh Wednesday and EU storage sat near 74–75% of capacity — historically lean for early November — as traders weighed U.S. midterm results and the next move on Iran, with Strait of Hormuz transit still constrained.
That global tightness does not automatically lift Henry Hub, but it limits how far U.S. prices can fall while export pull stays strong.
Storage Fundamentals
The latest EIA Weekly Natural Gas Storage Report — released Thursday, October 29, covering the week ended October 23 — remains the most recent print; the next report arrives Thursday, November 5, covering the week ended October 30. The October 29 report was bearish: an 80 Bcf injection, above consensus expectations of roughly 70–75 Bcf and the first build above the seasonal average since early August. Total working gas in storage stands at 3,724 Bcf — 147 Bcf (−3.8%) below last year's 3,871 Bcf, but 38 Bcf (+1.0%) above the five-year average of 3,686 Bcf.
The regional split still matters. The East region holds 913 Bcf and the Midwest 1,088 Bcf, while the South Central region, at 1,168 Bcf, remains below its five-year average, with salt-dome stocks about 11.6% below normal — the fastest-cycling storage, and the cushion that matters most in a cold snap. Consensus for Thursday's report centers on a 60–75 Bcf injection for the week ended October 30; a print at or above that range would extend the injection season further into November and reinforce the bearish near-term case.
Regional Basis Markets
The Northeast remains a market of two realities. Spot gas is cheap right now — Algonquin Citygate traded near $2.09 in late October, and Transco Zone 6 New York near $0.88 in mid-October, deep discounts to Henry Hub as mild weather and trapped Appalachian supply weigh on the region. But January 2027 forwards at Algonquin still top $20/MMBtu, more than five times the national benchmark. The problem is not supply; it is pipe. With heating oil averaging a projected $5.26 per gallon this winter and oil-heated homes facing roughly 21% higher heating bills, per EIA, dual-fuel generators have less cushion than usual if a cold snap triggers the familiar New England basis blowout. A proposed Algonquin expansion, Project Beacon, would add about 300 MMcf/d of firm capacity — but with service targeted no earlier than November 2030, it offers no relief this winter.
Production Trends
Lower-48 dry gas production has eased from the record pace of late summer, when output ran near 113.3 Bcf/d, to about 110.0 Bcf/d so far in November, according to LSEG. That is still near all-time levels, and EIA's October outlook expects 2026 dry production to average 112.2 Bcf/d, rising to 116.2 Bcf/d in 2027. The key question is whether the November dip is maintenance, economics, or the start of a response to sub-$3.00 prices. If output holds near 110 Bcf/d while LNG feedgas stays near 18 Bcf/d, the market tightens faster than the warm forecasts suggest — but only if heating demand actually arrives.
Broader Energy Context
Tuesday's settlements showed a split complex. WTI crude for December delivery eased 0.38% to $96.09 per barrel, a second straight decline, as hopes for U.S.–Iran diplomacy trimmed the war premium built up over the prior week. Brent held near $104. Heating oil, by contrast, jumped 2.47% to $4.5306 per gallon, and RBOB gasoline rose 1.22% to $2.9355 per gallon — a reminder that refined-product tightness, especially distillates, is a separate and more acute problem than crude itself.
Early Wednesday, crude firmed again, with Brent near $104.36 and WTI near $96.72, as markets awaited Washington's next move after the midterm elections. For gas buyers, the message is that oil volatility is not currently driving Henry Hub — weather and storage are.
What Energy Buyers Should Watch
Thursday's EIA storage report (November 5): does the surplus to the five-year average hold, widen, or start to narrow?
NOAA outlook updates: any shift from warm to cold in the 6–10 and 8–14 day windows is the fastest upside trigger.
The first sustained cold snap in the Northeast: watch Algonquin basis, not just Henry Hub — basis can move from $2 to $10+ in days.
LNG feedgas: sustained flows near or above 18–20 Bcf/d tighten the domestic balance quickly if demand picks up.
Production: whether the November dip toward 110 Bcf/d persists or reverses as maintenance ends.
Premier Energy Management Perspective
The market enters November balanced on paper and fragile in practice. Storage is slightly above the five-year average, production is near record levels, and LNG exports are running at a strong pace — a setup that argues for patience on long-term purchases, but not complacency on winter coverage. The Northeast basis market is the clearest example: a buyer who only watches Henry Hub will miss the risk that actually hits their bill. Locking in a strategy now — with defined triggers for layering in winter and January coverage if forecasts turn cold or Algonquin basis starts to lift — beats chasing the market after the first cold snap reprices it.
Market Bottom Line
December gas is stuck in a range: warm forecasts and comfortable storage cap rallies below $3.00, while easing production, strong LNG pull, and tight global markets keep dips toward $2.80 well bid. That range breaks on weather, not headlines — and Thursday's storage report is the next test of whether the injection season is truly over.
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