Key Takeaways
- Canadian natural gas storage sits at 350 Bcf entering summer 2026, approximately 35% above the five-year seasonal average.
- Mild winter 2025-26 temperatures reduced heating demand by an estimated 8–10% vs. normal, a key driver of elevated storage.
- LNG Canada’s growing export demand is absorbing production incrementally, but may not offset storage overhang entirely.
- AECO price bear case for winter 2026-27: $1.80/GJ; base case: $2.60/GJ; bull case: $3.40/GJ (weather-dependent).
The Canadian natural gas market enters the 2026 injection season with a storage overhang that is making producers and investors nervous. At 350 billion cubic feet (Bcf), total storage across Alberta, BC, and Ontario is approximately 35% above the five-year seasonal average, a surplus that reflects both a milder-than-average winter and the continued productivity gains of Montney drilling programs that keep outpacing demand growth.
How Did Storage Get So Full?
The winter of 2025-26 was the third consecutive year with above-average temperatures across Western Canada’s main natural gas consuming regions. Heating degree days for the season were approximately 8–10% below the 30-year normal, according to Environment and Climate Change Canada data. Residential and commercial heating demand, which represents approximately 35% of Canadian gas consumption in winter months, fell correspondingly.
Meanwhile, production from the Montney and Deep Basin plays continued to grow. Industry-wide Canadian dry gas production averaged approximately 18.2 Bcf/d through the winter a modest increase over the prior year driven by completions backlogs clearing in late 2024 and early 2025. The combination of below-normal demand and steady production pushed gas into storage at above-average rates from November through March.
LNG Demand as a Partial Offset
The key difference between 2026 and the prior storage overhang periods is the presence of LNG Canada’s Phase 1 export demand. At approximately 1.5 Bcf/d of throughput, LNG Canada is absorbing roughly 8% of Canadian gas production that would otherwise be competing for domestic storage or depressing AECO prices. This incremental demand is structurally supportive it exists regardless of temperature or economic cycles and represents a floor below which the storage-induced bear case is somewhat mitigated.
Analysts at ARC Energy Research Institute estimate that without LNG Canada, the current storage level would be approximately 15–20 Bcf higher, and AECO would be trading approximately $0.25–0.35/GJ lower. The LNG demand increment has meaningfully shifted the price floor, even if it hasn’t prevented the current storage surplus.
Demand Outlook: Industrial, Power Gen, Export
Beyond LNG, two other demand drivers will influence the storage draw-down through 2026. Industrial demand particularly from Alberta’s petrochemical sector and oilsands operations has been growing modestly as oil prices support upstream activity. Power generation demand is the more interesting swing factor: Alberta’s ongoing coal phase-out is creating incremental gas demand for dispatchable power, and BC’s electrification push is adding load that increasingly relies on gas peaking capacity during low-hydro periods.
Consensus estimates for 2026-27 winter demand sit approximately 3% above last year’s below-normal actuals, assuming a return to normal temperatures. If temperatures normalize, the storage surplus narrows by approximately 30–40 Bcf through the injection season, leaving storage at approximately 380–390 Bcf entering fall still elevated but less bearish than the current reading might suggest.
| Scenario | Winter Temperature Assumption | Storage Exit (Oct 31) | AECO Winter Avg ($/GJ) | Key Risk |
|---|---|---|---|---|
| Bear Case | 5% warmer than normal | 430 Bcf | $1.80/GJ | Prolonged storage glut |
| Base Case | Normal temperatures | 385 Bcf | $2.60/GJ | Demand normalization |
| Bull Case | 5% colder than normal | 320 Bcf | $3.40/GJ | Cold weather + LNG demand |
| LNG Phase 2 Bull | Normal + LNG ramp | 355 Bcf | $2.90/GJ | Phase 2 early capacity |
The Bottom Line
Elevated storage is a real headwind for AECO natural gas pricing through the summer of 2026, and the bear case for winter pricing is not trivial if temperatures remain mild. However, the structural demand increment from LNG Canada provides a meaningful floor that didn’t exist in prior storage surplus periods. Investors with exposure to low-cost Montney producers can find comfort in the fact that even in a $1.80/GJ AECO environment, the best operators Tourmaline, Peyto remain free cash flow positive. The storage overhang is a near-term headwind, not a structural break in the bull case.
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