Canada has one of the world’s largest and most developed natural gas industries. Production is concentrated in Western Canada, where large sedimentary basins support extensive drilling, processing and pipeline operations. For decades, the industry was built mainly around domestic consumption and pipeline exports to the United States. That structure remains important, but the start of large-scale liquefied natural gas exports from British Columbia has introduced a second direction for Canadian gas trade.
Canadian production reached another record in 2025, averaging about 19 billion cubic feet per day. The industry has continued to increase output despite periods of weak regional prices, supported by productive formations, improved drilling methods and growing demand from oil sands operations, power generation and LNG facilities.
The main question is no longer whether Canada has enough natural gas. It is whether pipelines, export terminals and emissions policies will allow producers to reach a wider range of customers while maintaining the competitiveness of the domestic market.
Western Canada Remains the Centre of Natural Gas Production
Alberta is the largest natural gas-producing province, supported by a mature network of fields, processing facilities and pipelines. Production also plays a major role in British Columbia, particularly in the northeastern part of the province. Smaller volumes are produced in Saskatchewan and several other regions.
The Montney Formation, which extends across northeastern British Columbia and northwestern Alberta, has become the most important source of growth. It contains large quantities of tight gas and natural gas liquids, including condensate used by Canada’s oil sands industry. The combination of high well productivity, established services and liquids revenue has made many Montney projects competitive even when gas prices are low.
British Columbia produced an average of about 6.7 billion cubic feet per day in 2023, equal to more than one-third of Canadian output. Almost all of the province’s production came from the Montney. Output has increased quickly as companies prepared to supply new LNG demand on the Pacific coast.
Canada also has extensive shale and tight gas resources beyond the Montney. However, the commercial value of a resource depends on more than its physical size. Producers must have access to gathering systems, processing plants, pipelines and reliable customers. Development has therefore remained concentrated in regions where infrastructure and drilling expertise are already available.
The industry includes major Canadian producers as well as international companies. Tourmaline Oil, Canadian Natural Resources, ARC Resources, Ovintiv, Shell and other operators hold substantial positions in Western Canadian gas. Their investment decisions are influenced by well productivity, liquids content, transportation costs and expected demand from export facilities.
LNG Canada Creates a New Route to Asian Markets
The opening of LNG Canada at Kitimat, British Columbia, represents a structural change in the Canadian natural gas market. The facility began exporting LNG in June 2025, allowing large volumes of Western Canadian gas to reach overseas customers directly for the first time.
Before LNG Canada, almost all major Canadian gas exports moved through pipelines to the United States. This created a highly integrated continental market, but it also limited the number of buyers available to Canadian producers. Gas from Alberta and British Columbia often traded at a discount when local production exceeded pipeline capacity or regional demand.
LNG Canada connects the Montney and other Western Canadian resources to the Pacific coast through the Coastal GasLink pipeline. The approximately 670-kilometre pipeline carries gas across British Columbia to the liquefaction facility, where it is cooled, loaded onto ships and transported mainly to Asian markets.
The first phase of LNG Canada has two processing trains and a planned production capacity of about 14 million tonnes of LNG per year. The facility has the potential to expand if its owners approve additional investment. Its location on Canada’s Pacific coast gives ships a relatively direct route to major importers such as Japan, South Korea and China.
Canada exported an average of about 295 million cubic feet per day from LNG Canada across the full year of 2025, although shipments only began in June. The volume is expected to rise as the terminal reaches its full operating rate.
Additional projects could broaden the market further. Woodfibre LNG near Squamish is under construction, while Cedar LNG near Kitimat is planned as a floating facility developed in partnership with the Haisla Nation. These projects are smaller than LNG Canada but could strengthen British Columbia’s position as an LNG-exporting region.
Pipeline Trade With the United States Still Defines the Market
Pacific LNG has added a new export channel, but the United States remains Canada’s largest natural gas customer. Canada exported about 8.6 billion cubic feet per day of pipeline gas in 2025, with nearly all of it moving to the United States.
Several major systems connect Western Canadian production to domestic and American markets. The NOVA Gas Transmission Limited network gathers gas across Alberta and northeastern British Columbia. From there, gas can move east through the Canadian Mainline, south through export pipelines, west toward British Columbia or into storage and processing facilities.
The Alliance Pipeline transports liquids-rich gas from Western Canada to the Chicago area. The Westcoast system carries gas through British Columbia, while several other connections supply markets in the Pacific Northwest, Midwest and northeastern United States.
Canada also imports gas from the United States, especially into Ontario and other eastern markets. Imports averaged about 2.5 billion cubic feet per day in 2025. This two-way trade reflects geography rather than a national shortage. Eastern Canadian consumers are often located closer to American production and pipeline systems than to fields in Alberta or British Columbia.
Domestic demand is also substantial. Natural gas heats homes and commercial buildings, supplies industrial facilities and supports electricity generation. Alberta’s oil sands use large volumes to produce steam, hydrogen and process heat. Gas-fired power generation has expanded in provinces reducing their use of coal, although renewable energy and nuclear power remain important competitors in several regional electricity markets.
Storage facilities help manage seasonal changes in demand. Gas can be injected during periods of lower consumption and withdrawn during cold weather, industrial disruptions or pipeline constraints. This flexibility is essential in a country where winter heating requirements can rise quickly.
Expansion Brings Emissions and Regulatory Pressure
The future of Canadian natural gas is closely connected to climate policy. Natural gas produces less carbon dioxide than coal when burned, but production, processing, pipelines and LNG facilities also generate greenhouse gas emissions. Methane leakage is a particular concern because methane has a strong warming effect over the near term.
Federal and provincial governments have introduced rules to reduce methane emissions from oil and gas operations. Producers are investing in improved measurement, leak detection, equipment replacement and electrification. Some LNG projects are also designed to use lower-emission electricity where sufficient power is available.
British Columbia’s LNG industry faces an additional challenge because liquefaction requires large amounts of energy. Electrically powered equipment can reduce direct emissions, but new power demand may require transmission expansion and additional generation. Projects using gas-powered equipment may be easier to develop in remote areas but can produce higher emissions.
Indigenous participation has also become an important part of major project development. The Haisla Nation’s role in Cedar LNG is one of the clearest examples of an Indigenous community holding a direct commercial position in a large Canadian energy project. Other First Nations have negotiated ownership interests, benefit agreements, employment commitments and procurement opportunities connected to pipelines and production.
These arrangements do not remove every disagreement over land, water or environmental effects. However, they can change the economic relationship between energy developers and communities located near major infrastructure.
Canada’s Gas Future Depends on the Scale of LNG Growth
Canada enters the next phase of its natural gas development with record production, large resources and extensive infrastructure. The addition of Pacific LNG exports reduces the industry’s complete dependence on the United States and gives Western Canadian producers greater access to global prices.
The scale of the change will depend on what follows LNG Canada. If existing terminals expand and additional projects enter service, production could continue growing well into the 2030s and 2040s. If costs, regulation, electricity constraints or weak global prices delay investment, Canada may remain primarily a continental supplier with a smaller overseas business.
The strongest advantage is the relationship between productive Western Canadian fields and relatively short shipping routes from British Columbia to Asia. The main test will be whether Canada can convert that advantage into reliable export capacity while controlling methane, construction costs and the emissions associated with LNG production.
