Canada Brokers BC LNG Terminal Deal With German Utility as Ottawa Pushes Export Diversification

Canada Brokers BC LNG Terminal Deal With German Utility as Ottawa Pushes Export Diversification A proposed British Columbia liquefaction plant gains a European offtaker as Canada seeks to reduce trade dependence on the United States. Canada has brokered a deal between a German state-owned utility and a yet-to-be-built liquefied natural gas terminal in British Columbia, according to two sources familiar with the agreement. The federal government continues to hunt for opportunities to diversify the country's exports away from the United States, and an LNG facility on the Pacific coast would open a direct route to both European and Asian buyers. The deal fits a pattern of German utilities locking in long-term gas supply from North American producers. Uniper, the German state-owned energy company, recently extended its gas partnership with ConocoPhillips to cover supply of up to 10 billion cubic metres of natural gas over the next ten years to north-west Europe. Germany accounts for just 0.1 percent of global natural gas production, making long-term import contracts essential to its energy security.⁷ The Strait of Hormuz closure on February 28 sharpened European urgency. Futures prices for LNG delivery to the Title Transfer Facility, the European benchmark, increased to $14.80 per million British thermal units as natural gas prices in Europe and Asia diverged sharply from those in the United States. European buyers who relied on Middle Eastern supply now face a structural need for alternative sources that do not transit contested waterways.⁶ A BC terminal would give Canada a second LNG export corridor alongside the existing east coast options. For Germany, it would add a Pacific-routed supply line to complement the Atlantic deliveries already contracted through deals like the ConocoPhillips-Uniper extension.^7,6 The timing coincides with a US natural gas market that is increasingly well-supplied. Marketed natural gas production in the Lower 48 states averaged 117.2 billion cubic feet per day in the first quarter of 2026, a 4 percent increase compared with the same period in 2025, according to the EIA. The agency forecasts Lower 48 production will increase 3 percent this year, driven mainly by the Permian region, which the EIA expects to produce 29.2 Bcf/d in 2026, some 6 percent more than in 2025.³ Rising US production puts competitive pressure on Canadian LNG economics. The Haynesville region, a natural gas-dominant play, is forecast to grow output by 6 percent this year and 8 percent next year, according to the EIA. More American gas looking for export outlets means a BC terminal would need to compete on both cost and contract terms.³ But US domestic prices suggest the market may be loosening faster than producers would like. NYMEX June natural gas settled at $2.96 per million British thermal units on Friday, gaining 2.3 percent for the day and about 7.4 percent for the week, according to Globe and Mail data. That weekly rally came despite bearish storage numbers.² Working gas in storage fell by 52 billion cubic feet for the most recent reporting week, well below the five-year average withdrawal of 168 Bcf. Inventories are now 141 Bcf higher than a year ago, about 8 percent above last year's level. A separate EIA storage report revealed higher-than-expected injections, putting further pressure on market sentiment.^1,4 Warmer-than-normal weather now forecast to cover most of the US east and west coasts is pulling some seasonal demand forward into power generation. But the storage surplus and rising production suggest the supply side of the US gas market is outrunning demand growth.^5,3 For Canada, the strategic calculus extends beyond gas market fundamentals. Ottawa's push to diversify away from US trade dependence gives a BC terminal political backing that pure economics might not justify on their own. The German deal provides an anchor offtaker, but the terminal still needs to be built, permitted and financed in a market where multiple North American LNG projects are competing for the same pool of long-term buyers. The contrarian view is that European gas prices could stay elevated long enough to make the project economics work. TTF front-month remains supported by supply-side risks, and any further disruption to Middle Eastern flows would widen the Atlantic-Pacific arbitrage that makes new Pacific export capacity attractive.⁶ What to watch is whether this deal triggers additional offtake commitments from European or Asian buyers, and whether the spread between TTF and NYMEX Henry Hub stays wide enough to justify the capital expenditure of building greenfield liquefaction capacity on Canada's west coast.^6,2