Canadian LNG Exports Draw Asian Buyers as Iranian Strikes Cut Qatar Supply Capacity 20 Percent

Canada's sole liquefied natural gas export facility is drawing renewed buyer interest from Japan, South Korea, and other Asian energy importers after Iranian military strikes against Qatar's export infrastructure cut the Gulf state's LNG supply capacity by roughly 20 percent, accelerating a global realignment toward Pacific supply corridors.

The LNG Canada facility at Kitimat, British Columbia, operated by a consortium led by Shell and including Petronas, PetroChina, Mitsubishi Corporation, and Korea Gas, shipped its first cargo in June 2025 and brought a second production train online in November 2025. With both trains operational, Canada now exports approximately 1.8 billion cubic feet per day of LNG, representing the first Pacific-facing export capacity the country has ever built.

The geopolitical premium attached to Canadian LNG is sharpening. Unlike shipments from Qatar, which must transit the Strait of Hormuz, or Australian cargoes that move through the Lombok Strait, LNG from Kitimat travels directly across the Pacific without passing through any major maritime chokepoint. That geographic advantage has become tangible for buyers in a market where Brent crude traded at approximately $96.83 per barrel on April 15, up nearly 49 percent from a year ago, and Middle East supply routes face unprecedented disruption.

"We import around 90 per cent of our total energy," Hideaki Ishii, deputy chief of mission at the Japanese Embassy in Ottawa, said at a recent industry event. "What is taking place in the Middle East has a big impact on our energy and economic security."

Canada's position is buttressed by a pipeline of additional LNG capacity coming in the next two years. Cedar LNG, a floating liquefaction project backed by Pembina Pipeline and the Haisla Nation near Kitimat, is scheduled to begin exports in 2027. Woodfibre LNG, located near Squamish, British Columbia, is targeting 2028. Both projects have reached final investment decisions, and together they are expected to push Canada's total LNG export capacity to roughly 19 million tonnes per annum by 2030.

Federal and industry projections point to approximately 6 percent growth in Canadian natural gas output during 2026, providing the upstream feedstock to keep new export terminals supplied. Canada's natural gas production hit historic highs in 2025, reaching around 19.1 billion cubic feet per day, driven largely by producers in northeastern British Columbia and Alberta.

The stakes for moving quickly are also rising on the competitive front. The Alaska LNG project would transport approximately 3.5 billion cubic feet of gas daily through a 1,300-kilometre pipeline to a liquefaction terminal at Nikiski on the Kenai Peninsula, potentially reaching Asian markets in the early 2030s. Analysts warn that if major Canadian LNG projects such as LNG Canada Phase 2 and Ksi Lisims do not take final investment decisions soon, Alaska LNG could secure long-term Asian supply contracts first.

"Canada has a real opportunity here, but it needs to move," said Barrett Bingley, a fellow at the Asia Pacific Foundation of Canada. "If that Alaska project comes online before the next couple of major Canadian projects, we've got a problem."

The economics for Canadian producers remain tied to global benchmarks. Brent crude's surge to nearly $97 per barrel reinforces the value of gas production linked to global LNG pricing, even as AECO spot prices in Alberta face domestic oversupply pressure. Western Canadian natural gas producers selling into export markets through LNG Canada receive prices indexed to Asian LNG benchmarks, effectively decoupling a portion of Canadian gas from the historically weak AECO basis differential. The CAD has strengthened modestly against the USD, which reduces the Canadian dollar value of LNG export revenues, though high global prices are offsetting that headwind.

The federal government has referred LNG Canada Phase 2 and Ksi Lisims LNG to its Major Projects Office, signaling Ottawa's intent to streamline approvals. That aligns with Alberta's separate push to cut major project approval timelines to 120 days, part of a broader effort to attract capital to Canadian energy infrastructure at a moment when Ottawa and Edmonton are both sending investment-friendly signals. For context on that provincial initiative, see our earlier coverage of Alberta's 120-day fast-track approval framework.

The Persian Gulf supply shock has sharpened the contrast between geopolitically exposed LNG routes and Canada's comparatively stable export corridor. As OPEC+ grapples with 230 tankers stranded in the Persian Gulf and Qatar scrambles to maintain remaining export capacity, energy ministers in Tokyo and Seoul are accelerating conversations with LNG Canada and potential future Canadian suppliers about long-term offtake agreements.

"Energy is our superpower," said Heather Exner-Pirot, director of energy, natural resources, and environment at the Macdonald-Laurier Institute. "But our kryptonite is complacency."

With WTI crude trading near $90.72 per barrel and global LNG spot prices rising in tandem with Brent, the financial case for accelerating Canadian LNG capacity has rarely been stronger. The question is whether Ottawa and the country's energy sector will move fast enough to lock in market share before competing Pacific supply projects close the window.