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Canada’s electricity strategy is finally becoming specific enough to test. Ottawa is no longer speaking only about clean power, energy security, nation building and doubling grid capacity. The federal government has started naming provincial boundaries where new electricity infrastructure may cross: British Columbia–Yukon, Alberta–British Columbia, Alberta–Saskatchewan, Saskatchewan–Manitoba and Prince Edward Island–New Brunswick.
That is progress. Five named interties are more useful than another national strategy made entirely of aspirations. They still do not constitute a national grid.
The relevant denominator is not the number of lines mentioned in an announcement. It is how much power each project can transfer, how often electricity is expected to flow, which generation it displaces, which reliability constraint it resolves, who pays, who owns it, how Indigenous governments participate and when the asset is expected to enter service. Until those questions have answers, an intertie remains a policy intention rather than an operating electricity asset.
Canada has long treated fossil-fuel infrastructure as a national economic concern while leaving electricity largely inside provincial boundaries. Pipelines, rail corridors, export terminals and ports were discussed as nation-building assets. Transmission was treated as a utility matter, despite electricity becoming the platform for industrial development, mining, data centres, transport, building heat and household affordability.
Electrification reverses that hierarchy. Long-distance energy transport increasingly means moving electrons rather than molecules. That is the logic behind the argument that HVDC is the new pipeline, although not every new provincial intertie should use high-voltage direct current. The technology choice depends on distance, capacity, grid synchronization, terrain and the systems being connected. The larger point is that wires are becoming strategic energy infrastructure.
Canada’s first transcontinental railway was symbolically completed by a golden spike. The electricity equivalent will not be one heroic line from Victoria to St. John’s. It will be a sequence of interties, reinforced corridors, substations, converter stations, grid-enhancing technologies, storage and market agreements that allow provincial systems to operate less like islands.
The first five links therefore matter because they begin to turn the national-grid idea into a build order. They are not equally valuable for the same reasons.
Saskatchewan–Manitoba is likely the most strategically important of the five. Manitoba has flexible hydroelectric generation. Saskatchewan has a fossil-heavy grid along with substantial wind and solar potential. A stronger connection can allow hydroelectricity to balance variable renewable generation, move clean surplus power when it has value and reduce the amount of backup capacity each province must maintain separately. The asset’s value would come from changed system operation, not from the existence of the transmission line itself.
The Alberta links address a different problem. Alberta has growing loads, strong renewable resources, a competitive electricity market and a grid still materially dependent on natural gas. Stronger ties to British Columbia and Saskatchewan could expand clean import and export options, improve balancing and reduce the province’s isolation during stressed periods. They would not decarbonize Alberta automatically. Market rules, generation investment, transmission tariffs and operating agreements would determine whether the new capacity displaced fossil generation or merely created another trading option.
British Columbia–Yukon is partly an energy-security and development project. Northern communities, mines and industrial projects remain exposed to diesel logistics and limited local generating capacity. Extending grid electricity may reduce fuel dependence where distance, loads and construction costs justify the investment. The project should still be assessed against distributed renewables, storage, local generation and efficiency rather than assuming that every remote load belongs on a continental grid.
Prince Edward Island–New Brunswick concerns Maritime reliability, subsea-cable vulnerability and the larger question of whether Atlantic renewable resources become operational grid assets. Atlantic Canada has repeatedly produced promising studies, export visions and regional plans. The practical test is whether transmission capacity, operating agreements and generation development arrive together.
None of the five projects, however, closes Canada’s most important east-west gaps. A serious national electricity map would place stronger Ontario–Quebec and Manitoba–Ontario connections near the centre of the strategy. It would examine how Atlantic wind could work with hydroelectric flexibility, how northern diesel systems should be replaced and where grid-enhancing technologies can release capacity faster than entirely new corridors.
Canada’s grid is already roughly 80% non-emitting in aggregate, but that national number hides sharply different provincial systems. Hydro-rich provinces, nuclear-heavy Ontario, fossil-heavy Alberta and Saskatchewan, wind-rich Atlantic provinces and diesel-dependent northern communities do not share the same resources, costs or political constraints. Canada has relatively clean electricity without having a coherent Canadian electricity system.
That distinction matters as electricity demand grows. Ottawa has discussed doubling grid capacity by 2050, but annual electricity consumption and peak demand are different planning problems. Electric vehicles, industrial loads and some heating demand can be shifted or managed. A handful of severe winter hours can drive far more infrastructure spending than average annual demand if buildings are inefficient and loads remain unmanaged.
Transmission is only one part of that system. Batteries can buffer constrained connections, shift solar output and provide frequency and voltage services. Dynamic line ratings can safely increase the capacity of existing lines when weather conditions permit. Reconductoring can replace old conductors with higher-capacity materials while using existing towers and rights of way. Power-flow controls can redirect electricity around bottlenecks.
These options do not remove the need for major new lines. They change the build order by separating constraints that require decade-long transmission projects from those that can be relieved faster on existing corridors.
The delivery problem is institutional as much as technical. Electricity remains provincial in law, regulation, utility ownership, system operation and politics. Ottawa can lower financing costs, adjust tax credits, use the Canada Infrastructure Bank, support Indigenous equity and place nationally significant projects into federal approval machinery. It cannot simply order provincial utilities and regulators to operate as one system.
That makes project governance central rather than administrative. Cost allocation can stop a line even when its national value appears obvious. One province may pay for an asset whose reliability benefits accrue elsewhere. An exporting province may worry about local electricity prices. Utilities may resist losing operational autonomy. Indigenous governments may be treated as consultees when they should be equity partners and decision-makers.
Canada needs a public project ledger for each priority intertie. It should identify transfer capacity, expected annual energy flows, capital cost, cost allocation, avoided fossil generation, reliability contribution, permitting milestones, Indigenous ownership or benefit structures, target service date and the specific constraint each line resolves.
Such a ledger would make it possible to distinguish political priority from delivery progress. It would also give manufacturers, construction firms, utilities and training institutions something concrete against which to plan. A trillion-dollar electricity strategy cannot scale transformers, cables, converter stations, engineering teams and skilled trades through general commitments alone.
The five proposed links should not be dismissed because they are incomplete. Serious infrastructure programs usually begin with projects that are easier to underrate than to build. Naming the crossings makes it harder for the strategy to remain abstract.
But five wires are still the beginning, not the spine. The professional test is whether they acquire capacities, owners, financing, permits, Indigenous equity structures, construction schedules and operating agreements—and whether Ottawa then proceeds to the next set of interties required to connect Canada’s uneven electricity strengths.
Read The Second Golden Spike Starts With Five Wires at TFIE Strategy Briefing for the project-denominator, build-order and national-grid analysis behind the five proposed links.
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