For years, the primary constraint on British Columbia’s clean-power economy was not ambition—it was electrons. Industrial operators, data centre developers, and fleet electrification programs all faced the same hurdle: grid capacity that could not keep pace with demand. Site C changes that calculus. With approximately 1,100 megawatts of new firm, dispatchable hydroelectric power now flowing onto the provincial grid, BC has its first major supply-side unlock in a generation. The practical question for operators is no longer whether to pursue it, but how quickly they can secure their place in the queue.

That queue is already forming. BC Hydro's large-load interconnection process—the formal pathway for industrial and commercial customers seeking grid connections above certain thresholds—has seen rising application volumes as the Site C completion date approached. Sectors leading the queue include liquefied natural gas processing, mining electrification, and, increasingly, hyperscale data infrastructure.

The rate advantage

Energy cost is the single largest operating variable for data centres, electrolysis-based hydrogen production, and large-scale EV charging infrastructure. BC holds a structural competitive advantage that many operators outside the province have yet to fully price in. BC Hydro's industrial Rate 1823—a transmission service rate for customers who provide their own transformation equipment—delivers power at approximately $0.05 to $0.06 per kilowatt-hour, among the lowest tariffs in North America. By comparison, industrial rates in California, Texas, and the US Northeast often run two to four times higher and carry carbon costs that BC’s hydroelectric supply avoids.

For a hyperscale data centre drawing 100 MW continuously, the annual electricity bill at BC Hydro's industrial rate runs roughly $44 million to $53 million. The equivalent load in a high-rate US jurisdiction can exceed $120 million. Energy cost differentials of this magnitude have historically driven siting decisions, and the AI infrastructure buildout, with its extraordinary power density, amplifies the effect.

Strategic positioning

Data centre developers with existing BC operations have been monitoring the Site C timeline closely. Firm, dispatchable hydropower is a distinct grid product compared to intermittent renewables; for operators running 24/7 AI inference and training workloads, this dispatchability is a technical requirement. Several developers active in the Metro Vancouver and interior BC markets have structured their site acquisition strategies around the dam’s commissioning, completing preliminary engineering while awaiting confirmed interconnection capacity.

Fleet electrification operators face a similar challenge. Large depot charging requires guaranteed grid capacity, often in industrial areas where existing infrastructure was not built for such high loads. Operators who have engaged BC Hydro's large-load team early report significantly shorter timelines than those who treat grid connection as a late-stage procurement item. The lesson is clear: grid access strategy belongs in the business case, not the implementation plan.

Green hydrogen represents a third major demand vector. Electrolysis-based hydrogen production is power-intensive—a commercial-scale facility can require 50 to 200 MW of continuous load—and economics are acutely sensitive to electricity cost. At BC Hydro's industrial rates, green hydrogen produced in BC can approach cost parity with grey hydrogen in markets where carbon pricing is applied consistently.

Capacity realities

Site C's 1,100 MW is sufficient to power approximately 450,000 homes, but it will be competed for by multiple high-demand sectors simultaneously. The $16 billion final project cost, nearly double the original $8.8 billion budget, means BC Hydro faces capital constraints that will influence how it pursues additional transmission and distribution build-out. Operators seeking large loads in areas without existing high-voltage infrastructure should expect longer timelines and potentially significant contribution costs for new transmission.

The interconnection queue also introduces sequencing risk. Applications are processed in order, and a single very large load can absorb a disproportionate share of available capacity in a given substation area. Operators who have not yet engaged BC Hydro's key accounts team risk waiting behind projects that will consume the incremental capacity Site C provides in their target geography.

The next 12 months are critical. The end-to-end interconnection process—from pre-application to a signed service agreement—can take 18 to 36 months. Operators who begin engagement now are positioning for service agreements in 2027 and 2028, the years when AI infrastructure investment, fleet electrification mandates, and industrial decarbonisation commitments will translate into operating assets.