01The Setup
NE/NY gas markets have historically priced at significant winter premium to Henry Hub due to pipeline constraints into the region. Demand spikes during cold weather; pipeline capacity to deliver doesn't expand on call. Spot prices respond accordingly.
Recent winters have seen variable outcomes: severe (Storm Elliot 2022 produced multi-day extreme prices, persistent cold winters with sustained premium), mild (warm December-February 2024-25 with limited spot price spikes). Weather is the dominant variable.
Storage levels exiting summer 2025 are within normal range; national gas production has been adequate. The setup isn't structurally tighter than prior years on supply — the question is demand-side weather and competing demand from LNG export (see BR-11).
02The Data
- Algonquin Citygates peak (expected): $25–40/MMBtu
- Tennessee Z6 200L peak: Similar
- Storage entering Nov 2025: ~3,700 Bcf
- vs 5-year average: Slightly above
- Henry Hub winter strip: +8–12% over 90d
- Pipeline expansions: Minimal
Pipeline constraints into the region haven't improved meaningfully since 2022. Same physical bottleneck. The basis premium that develops on cold days is mechanical — not enough pipe to deliver — and won't improve with planning or contracting alone.
LNG export demand continues to compete with domestic gas use, including heating demand. Gas that could flow to New England in a cold snap might instead clear into export terminals, depending on price signals and pipeline routing.
Weather is the unknown. Current outlooks favor cold winter for Northeast — La Niña pattern signals trend toward colder than normal — but weather forecasts at the seasonal scale have substantial error bars. The asymmetric exposure is the planning issue, not the central forecast.
03The Implication
Customers on fixed-rate winter contracts are protected through the term, but renewal pricing for winter 2027-28 will reflect this winter's outcome. A severe winter prices into next year's curves; a mild winter resets them lower.
Customers on indexed contracts are exposed to weather. Cold winter = bill shock. Mild winter = no impact. The asymmetry favors hedging for risk-averse customers — the downside is severe; the upside of being unhedged in a mild winter is modest.
04The Recommendation
- Audit customer winter exposure (indexed vs fixed) and run cold-winter scenarios. Quantify the dollar impact of a Storm Elliot-style week against the current contract structure.
- For indexed customers, evaluate winter-only hedge structures. Full-term fixed is often overkill; targeted winter protection captures the asymmetric risk at lower cost.
- Watch storage withdrawals through Dec-Jan. Outliers signal cold-weather impact and tighten the back of winter. Adjust customer guidance as data arrives.
- For 2027-28 procurement, this winter's outcome will price into next year's curves. Customers planning multi-year procurement should watch how this winter unfolds before locking far-dated tenors.
Northeast gas in winter is the region's least-modernized market — same pipeline constraints, same weather exposure, same customer risk profile as a decade ago. The structural problem hasn't been solved. Customers who hedge it survive cold winters without bill surprises. Customers who don't hedge get a learning experience. We've had one mild winter in three; that's not a trend.