⚡Natural Gas MarketWatch — October 28, 2026: November Bounces Into Expiry as the Curve Refuses to Follow
The November NYMEX contract refused to go quietly into expiration. After sliding to a six-month low on Monday, the prompt month rebounded Tuesday, settling at $2.697/MMBtu, up 9.5¢ (+3.65%) — its largest one-day gain since October 13. The bounce, however, was confined to the expiring contract. December — which takes over as the front month after today's expiry — and the rest of the curve barely budged, and the winter strip actually slipped. The message from the curve is blunt: Tuesday was position-squaring ahead of expiry, not a change of heart about a warm, well-supplied market heading into winter.
Market Recap: A Prompt-Month Bounce, Not a Rally
November natural gas settled Tuesday at $2.697/MMBtu, up 9.5¢ (+3.65%), snapping a two-session losing streak. Even after the rebound, the contract remains down about 27¢ over the past week and 53¢ over the past month, down 10.87% month-to-date and 26.83% year-to-date, and still just 6.9% above its 2026 low of $2.523 (April 24). December, the incoming front month, traded near $3.02 — roughly flat on the day — while the full Winter 2026–27 strip slipped a penny to $2.95/MMBtu and Summer 2027 finished near $2.77. Technicians put December support near $2.932, with resistance near $3.234: today's expiry handoff will test whether that support holds once the roll is complete.
Key Bullish Drivers
Expiry short-covering: traders squared positions ahead of today's November final settlement, lifting the prompt month while leaving the rest of the curve untouched — the classic signature of a technical bounce, but one that can still run further if December catches a bid.
Global gas is at crisis pricing: Dutch TTF touched €97.64/MWh intraday Tuesday, its highest since late 2022 and roughly $31.87/MMBtu, on Hormuz shipping disruptions, Norwegian field outages, and colder European forecasts — with EU storage near 74.6%, more than 10 percentage points below a year ago.
LNG feedgas is running hot: flows to U.S. export terminals averaged 18.3 Bcf/d in October to date, up from 17.9 Bcf/d in September, and rebounded Tuesday after the selloff — keeping a floor under demand even as domestic weather disappoints.
Cold snaps abroad: colder weather in Europe and Asia next week could keep U.S. LNG terminals at maximum output as buyers rush to refill gas burned during the early chill.
Key Bearish Drivers
Forecasts still favor warmth: above-normal temperatures are expected across the eastern two-thirds of the U.S. through November 9, and warmer-than-normal weather is favored well into the first half of November, with the strong El Niño historically pointing to a milder northern winter.
Production is back near records: Lower-48 output averaged roughly 113.3 Bcf/d over the past week and 111.9 Bcf/d for October to date — matching the August–September record pace — after recovering from an early-October dip.
No tropical threat: the National Hurricane Center's 2:00 AM ET outlook Wednesday expects no tropical cyclone formation in the Atlantic, Caribbean, or Gulf over the next seven days; Pacific Tropical Storm Vance's remnants bring rain, not Gulf supply risk.
The curve is voting bearish: the winter and summer strips both slipped Tuesday, confirming that traders still see a loose balance once expiry noise fades.
Storage Fundamentals: Above Average, Below Last Year
The most recent EIA report — released Thursday, October 22, covering the week ended October 16 — showed a 77 Bcf injection, just below analyst expectations near 80 Bcf and below last year's 86 Bcf build. Working gas totals 3,644 Bcf: 4.0% below year-ago levels (3,796 Bcf) but 1.0% above the five-year average (3,609 Bcf). The next report arrives Thursday, October 29, covering the week ended October 23, with early expectations centered near a 71–73 Bcf build — close to the five-year average pace. A leaner print would extend the run of below-average builds and support December; a larger build would reinforce the bearish case. Note that the EIA's October outlook still expects inventories near 3,850 Bcf by month-end, with injections possibly extending into mid-November if mild weather persists.
Regional Basis Markets: Northeast Cash Rebounds, Winter Premiums Intact
Northeast spot prices staged a sharp rebound Monday even as futures fell: Algonquin Citygate surged 71.5¢ to $2.085/MMBtu, and Transco-Leidy jumped 61¢ to $1.740, largely on reduced regional flows rather than demand. That is the Northeast in miniature — soft on average through a mild October, but capable of violent upside on any flow disruption. Winter forwards still carry large premiums to Henry Hub, pricing in the pipeline-constraint risk that defines New England on the coldest days. The backup-fuel picture offers only partial comfort: heating oil (ULSD) settled Tuesday at $4.7752/gallon, down 2.79% on the day, but winter heating costs remain elevated versus last year. For New York and New England buyers, the risk is not supply — it is deliverability when it matters most.
Production Trends: Prolific, With LNG as the Offset
Lower-48 dry gas output is running at 111.9 Bcf/d for October to date, essentially matching the record 113.3 Bcf/d set in August and September. Against that, LNG feedgas at 18.3 Bcf/d is absorbing a growing share of supply — and with global prices near $32/MMBtu, every available cargo is being pulled abroad. The balance stays loose until heating demand actually shows up, but the export pull is the reason this market has not fallen further: domestic weakness is being exported, one cargo at a time.
Broader Energy Complex: Crude Slides Below $100 on Diplomacy Hopes
Crude retreated Tuesday as Tehran talks between Iranian officials and Saudi, Turkish, and Pakistani mediators raised hopes of de-escalation, though no formal ceasefire emerged and Hormuz shipping remains impaired — Gulf crude exports are running near 65% of pre-conflict levels. WTI (December) settled at $99.90/barrel, down 1.83%, slipping below $100, and Brent (December) settled at $113.88, down 1.67%.
Heating oil (ULSD, November) fell 2.79% to $4.7752/gallon, and RBOB gasoline (November) fell 2.51% to $3.1376/gallon, snapping gasoline's four-session winning streak. The oil market's risk premium is intact; it simply took a breather on diplomacy headlines.
What Energy Buyers Should Watch
Today's November contract expiry and how December behaves as the new front month — support near $2.932 is the first test.
The October 29 EIA storage report (week ended October 23) — expectations near a 71–73 Bcf build.
The 11- to 15-day weather forecasts: a cold shift for early November could add 20–30¢ to December quickly, and the crowded short trade would amplify the move.
LNG feedgas trends as new export capacity ramps into year-end, and whether European cold snaps pull even more cargoes.
Middle East developments: the oil bid is already there; gas follows if LNG shipping routes are threatened further.
Premier Energy Management Perspective
Expiry-day bounces are noise; curve behavior is signal — and Tuesday's signal was that the market is not yet ready to pay up for winter. That leaves buyers with a familiar but valuable setup: prompt prices near six-month lows, a winter strip that has shed 45¢ in a month, and three live upside risks — a cold forecast shift, the South Central storage deficit, and a global gas market priced near $32 — that can reprice the curve in days. The disciplined move is to use softness like this to layer in winter coverage, rather than waiting for the first cold snap to do the negotiating for you.
Market Bottom Line
A 3.65% bounce into expiry does not change the story — warm forecasts, record-level production, and adequate storage still rule — but it does remind the market how quickly an oversold, heavily shorted contract can snap back. Until the weather changes, rallies should be treated as buying opportunities, not trend changes — and today, with December taking the front-month baton, is when that discipline starts to pay.
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