Canada's first major liquefied natural gas export terminal is planning to double its capacity, a move that would materially lift the country's presence in the global LNG trade from a standing start.

The project, on British Columbia's coast at Kitimat, entered service as the country's debut large-scale LNG export facility after years in which Canada watched US Gulf Coast and East Coast terminals capture Atlantic and Pacific cargoes alike. A capacity doubling would position the terminal — and the Montney and other Western Canadian Sedimentary Basin gas behind it — as a sustained, larger-volume supplier to Asian buyers rather than a single-phase entrant.

The expansion plan signals confidence in both the feedgas resource base and the demand outlook in Pacific markets. Western Canada holds decades of proved and probable gas supply, and pipeline takeaway to the West Coast had long been the missing link between those reserves and LNG importers in Japan, Korea and China. The first terminal changed that equation; a second phase of comparable scale would roughly double the volume of basin gas pulled toward export duty.

For producers in the Montney play, the arithmetic is straightforward. Every million tonnes per annum of liquefaction capacity requires roughly 0.14-0.2 bcfd of feedgas, depending on train efficiency and shrinkage. Doubling the terminal's capacity therefore implies a step-change in gas demand at the plant gate, with implications for drilling programs, completion activity and takeaway pricing across northeast British Columbia and northwest Alberta.

The timing of an expansion decision will hinge on the usual variables: LNG offtake contracting, engineering procurement and construction pricing, labour availability in British Columbia, and the regulatory pathway for a second phase. Coastal gasLink-style pipeline capacity, indigenous partnership arrangements and federal and provincial permitting will each shape the schedule. Those considerations separate a sanctioned project from a stated intent, and for now the doubling sits in the planning and evaluation stage rather than the construction ledger.

Market context matters for any capacity decision. Asian spot LNG prices have swung from the 2022 highs to softer 2024-25 levels, and long-term offtakers weigh expansion commitments against a growing queue of US and Qatari supply due late this decade. A Canadian expansion competes in that queue. Supporters of the project argue its West Coast location shortens shipping distance to North Asia relative to Gulf Coast loading, trimming voyage time and freight cost per cargo — an advantage the sponsor will lean on in securing additional offtake for a second phase.

There is also the domestic angle. Canadian gas producers have fought a structural discount at AECO and Station 2 for years, a function of export pipeline constraints. LNG demand at Kitimat draws gas west rather than south, and analysts have long argued that each phase of West Coast liquefaction narrows that discount. Attribution caveat: that price impact remains analyst commentary, not a guaranteed outcome, since expanded supply and pipeline builds can offset demand gains.

For the service sector, a sanctioned second phase would mean more than terminal steel. It would mean additional compression on the feeder pipeline system, more drilling rigs running in the Montney, more frac crews, and more plant construction in a province where labour competition is already tight. Contractors who delivered phase one hold the incumbent advantage.

The watch item is the formal sanction decision: the sponsor's final investment call on the expansion phase, the offtake agreements that underpin it, and the construction timeline that follows. Until that FID lands, the doubling remains a plan with strong logic behind it — and no steel ordered. Watch as well for provincial and federal permitting milestones and for the pace of offtake contracting with Asian buyers, which will determine whether the doubled capacity reaches a final go in this investment cycle or the next.