Henry Hub Climbs to $3.19 as AI Datacenters and LNG Canada Tighten North American Gas Supply

Henry Hub natural gas futures settled at $3.19/MMBtu on October 7, 2026, a gain of 2.57% on the session — the sharpest single-day move in three weeks. At the USD/CAD rate of 1.4250, that translates to approximately $4.55/MMBtu in Canadian dollars, a meaningful tailwind for domestic producers whose costs are largely denominated in CAD while revenues track the North American benchmark.

AECO Basis Holds Narrow as Demand Pulls West

The AECO spot price at the Alberta hub tracked Henry Hub closely, trading at an estimated $3.72/GJ — a historically tight differential reflecting strong westbound pipeline flows toward the LNG Canada terminal at Kitimat, British Columbia. LNG Canada’s Phase 1 export capacity of 14 million tonnes per annum (Mtpa) has been absorbing significant Montney and Deep Basin volumes since commercial ramp-up began earlier this year. When LNG Canada draws hard, AECO basis tightens, and producers in the Western Canadian Sedimentary Basin (WCSB) capture economics closer to the global LNG netback price rather than the traditional, depressed Alberta in-basin price.

Tourmaline Oil: Canada’s Gas Heavyweight Positioned to Benefit

Tourmaline Oil Corp. (TSX: TOU), Canada’s largest natural gas producer with output exceeding 600,000 BOE/day, is among the primary beneficiaries of the tightening basis. The Calgary-based company holds firm transportation agreements on the Coastal GasLink pipeline, giving it preferential access to LNG Canada offtake volumes. Tourmaline’s Montney and Deep Basin assets carry some of the lowest all-in supply costs in North America — estimated at under $1.00/GJ — meaning the current $3.72/GJ AECO price represents exceptional operating leverage. The company has not issued guidance revisions as of publication, but analysts widely expect free cash flow generation to accelerate materially in Q4 2026 if prices hold.

AI Datacenter Load: The Structural Demand Story No One Is Ignoring

Beyond the seasonal weather narrative, a structural shift is reshaping North American gas demand. AI datacenter construction has accelerated dramatically across the U.S. and Canada through 2025–2026, and grid operators in Texas, Virginia, and Ontario are increasingly relying on gas-fired peaking capacity to backstop intermittent renewables powering these facilities. The U.S. Energy Information Administration (EIA) estimates that power-sector gas burn in September 2026 ran approximately 4% above the five-year seasonal average, a direct consequence of elevated baseload electricity demand from hyperscale compute clusters operated by major cloud providers.

Storage Context: Below Average, Supportive of Prices

The latest EIA weekly storage report showed U.S. working gas in storage at 3,512 Bcf, roughly 4.1% below the five-year average for this time of year. The injection season is entering its final weeks, and the storage deficit — combined with LNG export demand and AI-driven power load — has materially narrowed the ceiling for a late-season price pullback. Canadian storage operators in Alberta face similar dynamics, with NGTL system linepack running lean ahead of the November heating season. For investors in Canadian gas equities, the setup into year-end is the most constructive it has been since the 2022 energy price spike.