Electricity demand is climbing faster than expected, and legacy hydro alone will not keep pace. Ontario’s grid planner now sees provincial demand rising 75 percent by 2050 as EV supply chains, population growth, and data centres add large new loads.
That leaves provinces stitching together nuclear, wind, solar, storage, and some gas to keep the lights on. Reservoirs help manage peaks, but prolonged droughts and limited new large dam sites constrain output. Ontario needs new supply in the 2030s, not the 2040s, according to its latest forecast, which puts the growth burden squarely on projects that can be permitted and built on time. The numbers are getting bigger, and the timelines are tight.
Ontario leans on nuclear build
Ontario is doubling down on nuclear for dependable, round‑the‑clock power. Ontario Power Generation says, “Our planning goal is to complete construction of the first SMR by the end of this decade,” a signal the utility wants new nuclear on the grid before 2031.
The small modular reactor at Darlington anchors that push, with follow‑on units staged to apply lessons from the first build. Gas plants remain in the mix to backstop peaks and cover lulls, while storage projects and conservation shave demand at the margins. The Independent Electricity System Operator’s latest outlook calls for demand to grow 75 percent by 2050, underscoring how electrification and data processing are reshaping supply needs. Ontario must balance speed, cost, and reliability as it adds capacity.
Quebec and B.C. add renewables
Quebec is spreading its bets across wind, upgrades to existing dams, a pumped‑storage project, and targeted solar. Hydro‑Québec estimates the province will need an extra 60 terawatt‑hours by 2035, including 8,000 to 9,000 megawatts of new capacity.
The plan would triple wind by integrating more than 10,000 megawatts and add 3,800 to 4,200 megawatts from hydro improvements and new facilities. As Hydro‑Québec’s Claudine Bouchard put it, “we must also generate more electricity,” stressing the scale of the buildout to keep rates affordable and service reliable. New transmission will be commissioned in stages from 2031 to 2036 to move that power to load centres.
British Columbia, facing its own demand surge from industry and population growth, has moved first with contracted new supply. BC Hydro’s 2024 call for power yielded ten projects, nine wind and one solar, accepted by the regulator in August.
Those contracts will add about 4,830 gigawatt‑hours a year, roughly an 8 percent boost to present supply, at a weighted average price of C$74 per megawatt‑hour. The province says this price is about 45 per cent lower than the last clean‑power call in 2010 after inflation, a result that helps ratepayers and gives developers a clearer path to financing. Deliveries start later this decade as projects clear permits and interconnections.
Hydro remains a backbone, but plans across provinces show it cannot do the heavy lifting alone this time. Ontario’s forecast of demand to grow 75 percent by 2050 reflects a structural shift tied to manufacturing, housing, and digital infrastructure, not a temporary spike. Quebec’s move to triple wind and add pumped storage, and B.C.’s wind‑first build, point to a common playbook, diversity over single‑fuel dependence. Nuclear in Ontario provides firm capacity that complements variable renewables, while gas remains a reliability tool when weather and demand do not cooperate.
For Canadian grids, the near‑term task is clear, turn signed contracts and announced plans into megawatts on schedule and on budget.
