B.C. Oil and Gas Output Nearly Doubled in a Decade as Pipeline and LNG Investment Delivers, New Study Shows
Statistics Canada data confirm a decade-long production surge in British Columbia, underpinning Ottawa's push for a second Pacific oil corridor and expanded LNG exports.
A study published on Friday (2026-08-21) found that a decade of pipeline and LNG investment has nearly doubled British Columbia's oil and gas output, with Statistics Canada data now providing what the report calls "clear and incontrovertible evidence" of the gains.6
The data land at a useful moment. Canada is building new Pacific export infrastructure for both oil and LNG, betting that Asian buyers will absorb volumes that historically flowed almost entirely south to the United States. Producers and politicians now have a verified record, not a projection, to stand behind the next round of spending.6,1
The oil side of that push moved forward on July 3 (2026-07-03), when Alberta Premier Danielle Smith and Prime Minister Mark Carney jointly announced a new Pacific-coast pipeline to be built by Trans Mountain Corp. The conduit would carry 1 million barrels per day, with the federal government and Alberta as majority owners; Pembina will take a 10% stake, Reuters reported.2
Trans Mountain also has a separate expansion plan for its existing line, targeting an increase from 890,000 barrels per day to 1.2 million barrels per day by 2029. Canadian oil production is forecast to reach 5.3 million barrels per day this year, making new routes to Pacific tidewater a strategic priority for producers.2
Alberta's government applied on Thursday (2026-07-02) to have the West Coast Oil Pipeline designated a project of national interest, a status that fast-tracks federal review. The province estimates its oil reserves at 177 billion barrels, nearly nine times the size of Texas' proved reserves. In mid-July (2026-07-14), Canada's largest oil sands producers reached a new milestone alongside federal and provincial officials in advancing the project.3,4
The gas side runs in parallel. A Canadian energy industry report published on Thursday (2026-06-25) identified Asia as the primary destination for diversification away from the United States, anchored on expanded LNG exports from B.C.'s Kitimat terminal. Under a Phase 2 expansion, Kitimat's export capacity could reach 30 million tonnes per year, double the current level.1
Asian LNG spot prices on August 25 (2026-08-25) stood at $23.32 per MMBtu on the JKM benchmark, offering exporters a healthy margin above North American production costs. But spot levels and the long-term contract economics that underpin project financing are different things. B.C.'s LNG ambitions depend on Asian buyers signing multi-decade supply agreements, and those same buyers have a growing list of American LNG suppliers competing for their attention.1
RBAC Inc.'s second-quarter 2026 base case shows U.S. LNG exports more than doubling, from 14.9 billion cubic feet per day in 2025 to 32.4 billion cubic feet per day by 2035. The EIA separately estimated the U.S. could add 44.9 billion cubic feet per day of new pipeline capacity during 2026-27, with 31.6 billion cubic feet per day already under construction. NYMEX Henry Hub front-month traded at $2.76 per MMBtu on August 25 (2026-08-25), keeping U.S. feedgas costs competitive for LNG exporters.5
The recently completed Matterhorn Express, a 580-mile pipeline, added 2.5 billion cubic feet per day of Permian Basin takeaway capacity to the Katy Hub near Houston, expanding the supply base feeding Gulf Coast terminals. More such projects are advancing.5
The Statistics Canada record confirms that B.C.'s production model works when backed by infrastructure. Whether the Kitimat Phase 2 expansion can secure long-term Asian contracts before American projects fill that market is what B.C.'s next wave of LNG investment hinges on.6,1,5