Key Takeaways
- LNG Canada Phase 1 began commissioning in early 2025 with 14 Mt/year of export capacity, the largest LNG facility in Canadian history.
- Phase 2 was sanctioned in late 2025 and is expected to double export capacity to 28 Mt/year by 2030.
- The AECO–Henry Hub basis differential has narrowed significantly as LNG demand absorbs excess Montney production.
- Tourmaline Oil Corp, ARC Resources, and Peyto Exploration are the primary Canadian beneficiaries of higher netback pricing.
For decades, Canadian natural gas producers were trapped. The Montney and Deep Basin plays of British Columbia and Alberta sat on world-class reserves some of the lowest-cost gas in North America but had nowhere to sell it except a continent that was rapidly becoming self-sufficient. The AECO benchmark traded at a persistent, painful discount to Henry Hub, reflecting pipeline congestion, storage constraints, and a lack of export optionality. That structural disadvantage is now unwinding.
LNG Canada: Phase 1 Delivers, Phase 2 Sanctioned
LNG Canada’s Phase 1 facility at Kitimat, BC, is now operational, marking the first time Canada has exported liquefied natural gas to international markets at scale. The facility has a nameplate capacity of 14 million tonnes per year (Mt/year), drawing feed gas from the Coastal GasLink pipeline, which traverses 670 kilometres from the Montney basin to the coast. The $18 billion project led by Shell with partners Petronas, PetroChina, Mitsubishi, and Korea Gas represents the single largest private-sector infrastructure investment in Canadian history.
Phase 2 was sanctioned in late 2025, with final investment decisions supported by long-term offtake agreements from Japanese and South Korean utilities. Full Phase 2 capacity of an additional 14 Mt/year is expected online by 2030, bringing total Kitimat export capacity to 28 Mt/year. That volume, annualized, represents roughly 3.7 billion cubic feet per day (Bcf/d) of Canadian gas demand a substantial and structural new market for Montney producers.
The AECO Basis Story: From Discount to Premium
The AECO–Henry Hub basis differential historically as wide as negative $1.50 to $2.00/MMBtu has compressed sharply since LNG Canada’s commercial ramp began. Analysts at ARC Energy Research Institute estimate the sustainable basis improvement at $0.60–$0.90/MMBtu, with further tightening expected as Phase 2 takes shape. For producers whose cost of supply sits at $0.80–$1.20/mcf, even a $0.50/mcf improvement in realized pricing translates directly into margin expansion.
Asian LNG spot pricing (JKM index) has ranged between US$10–14/MMBtu over the past 18 months, and LNG Canada’s tolling structure allows producers to capture approximately 60–65% of JKM pricing as netback a meaningful premium over domestic AECO when LNG markets are tight. The Pacific Basin export route also provides Canadian producers with a natural hedge against US Gulf Coast competition, diversifying revenue streams beyond the North American benchmark.
Who Benefits Most: Tourmaline, ARC, Peyto
Tourmaline Oil Corp (TOU.TSX) is Canada’s largest natural gas producer with approximately 620,000 boe/d of production and 2.5 Tcf of annual gas output. The company has contracted approximately 1.5 Mt/year of LNG Canada tolling capacity, which at full utilization would represent roughly 200 MMcf/d of premium-priced gas. Tourmaline’s scale, low cost structure, and existing Coastal GasLink access make it the clearest beneficiary.
ARC Resources (ARX.TSX), with a focused Montney position straddling the BC-Alberta border, has both the production scale (~350,000 boe/d) and the geographic positioning to benefit from LNG optionality. ARC’s Attachie Phase 1 project adds ~60,000 boe/d of low-cost Montney production that is well-suited for LNG markets.
Peyto Exploration (PEY.TSX) benefits more indirectly its Deep Basin assets are connected to the AECO hub, and a tighter AECO-Henry Hub basis directly improves realized pricing without requiring dedicated LNG tolling agreements.
Export Revenue: The Numbers
At 14 Mt/year of LNG exports and a JKM price of US$12/MMBtu, LNG Canada Phase 1 generates roughly US$8 billion in gross export revenue annually though tolling, liquefaction, and shipping costs consume a substantial portion before producers see netback improvement. Still, the directional impact on AECO is unambiguous: demand has been added structurally, and supply-demand dynamics have shifted in producers’ favour.
| Company | Production (boe/d) | Gas Weighting | LNG Exposure | Dividend Yield |
|---|---|---|---|---|
| Tourmaline Oil (TOU) | 620,000 | 78% | Direct (1.5 Mt/yr toll) | 2.1% + specials |
| ARC Resources (ARX) | 350,000 | 72% | Indirect via AECO | 3.4% |
| Peyto Exploration (PEY) | 110,000 | 90% | Indirect via AECO | 5.2% |
| Paramount Resources (POU) | 95,000 | 65% | Indirect via AECO | 1.8% |
The Bottom Line
Canada’s LNG export era has arrived, and its consequences for the natural gas sector are durable. The AECO basis improvement, while modest in individual quarters, compounds significantly for high-volume producers. Tourmaline is the most direct beneficiary, but the entire Montney producer universe stands to benefit from the structural demand increment LNG Canada has introduced. Phase 2 construction should keep the story in front of investors through the end of the decade.
The Boreal Brief
Canadian markets intelligence every morning before the open. Free.
