Bedrock Energy Corp.
Technology
Ontario has spent fifteen years building wind and solar. The hard part was never generating clean power. The hard part is having it available at six o’clock on a still January evening, when the province wants it most and the wind has dropped. That is the problem this site is built to solve.
Our approach
Making clean power dependable enough to build on
Decarbonising a grid was never one technology replacing another. It is a question of what gets built, where it sits, and what covers the hours the weather does not. The computing infrastructure going up alongside it asks the same question, in a hurry. Both need the same three answers at once: consistency, so the power is there in every hour of the year; diversity, so no single resource has to carry the load alone; and cost that falls rather than rises as the system gets cleaner.
No one technology delivers all three. A combination can: four assets on one connection, sized so a continuous load can be served around the clock and the surplus sold to the grid. Each covers a weakness in the others, which is what turns intermittent generation into power somebody can sign a contract for.
It is also where the cost case comes from. Wind and solar charge the storage instead of being curtailed, so energy already paid for is sold rather than spilled. The reservoirs are already underground and the transmission already crosses the site, so two of the largest costs in a project of this kind are never incurred at all.
Bedrock Energy Centre
Generating and storage capacity on the site
Capacity by asset
The wind is blowing and the province does not need the power. Surplus goes underground as compressed air and into the batteries instead of being curtailed, and the campus runs on what was stored earlier. The turbines stand down.
Demand across Ontario is at its highest. The turbines hold the campus steady behind the meter while stored air and the batteries sell into the peak, the hour the grid is short and the power is worth most. Whatever wind and solar are producing still trickles into the batteries behind it.
Days of cold, still weather with little wind or sun. Storage alone cannot carry a week, so the turbines carry the campus and the batteries absorb the swings. What renewable output there is still goes to the batteries, and off-peak power refills the reservoir for the next peak.
Solar is at full output. The batteries take the sharp edges off it, air is compressed with what is left over, and the campus runs on renewable power as it arrives. Nothing is burned.
Illustrative. Capacities are the figures filed with the IESO; how the assets share the work in any given hour depends on weather, price and what the system needs.
Why four assets, and not one
Put long-duration storage, firm generation, fast batteries and a single grid connection on the same ground and they cover each other’s weaknesses. Storage carries the daily cycle. Generation carries the long calm. Batteries carry the seconds. The connection lets all three act as one resource rather than three competing ones.
That combination does three useful things at once.
It makes power dependable. A hospital, a plant or a computing campus needs the same electricity every hour of the year, and will pay for the certainty. A single clean resource cannot promise that. A mixed fleet can, which is what turns intermittent generation into a product somebody can sign a contract for.
It stops good energy going to waste. Ontario regularly produces more electricity than it can use, and when the grid cannot take it, that output is curtailed – spilled, unpaid for, gone. Storage is the place to put it. Energy bought when it is abundant and returned when it is scarce is cheaper energy, and a system with somewhere to put its surplus does not have to build as much capacity for the few hours a year when demand peaks.
It makes the renewables already built work harder. This is the part that matters most for emissions, and it is easy to miss. Every megawatt-hour of wind or solar that gets stored instead of spilled is a megawatt-hour that displaces something burning later in the day. The turbines and panels around this site do not change, but more of what they generate reaches somebody. Storage raises the productive output of renewable generation that already exists, which is a far cheaper way to cut carbon than building more of it and curtailing that too.
Compressed air energy storage
The oldest idea here, and the one nobody else in Canada can copy quickly.
When power is cheap and plentiful, the site buys it and runs it through compressors. Compressing air makes heat, and that heat is the thing most designs throw away. Here it is captured and held in insulated tanks beside the plant.
The compressed air itself goes underground, into depleted natural gas reservoirs more than 500 metres below the surface. These are porous rock formations sealed by geology that held natural gas under pressure for 450 million years. They are well below the aquifers that supply local wells, and they were licensed to hold gas for decades before the Ontario Energy Board de-designated them for this use in 2019.
The pools are separate, and they do not have to do the same job. One carries compressed air. The other can be returned to natural gas storage, which is the use it was licensed for until the Ontario Energy Board de-designated it in 2019, and restoring those approvals is part of the plan. Air in one reservoir and gas in the other is a flexibility very few sites have.
When the grid needs power back, the air comes up and meets its own stored heat on the way to the generating trains. Nothing is burned to reheat it. The plant reaches full load in about ten minutes from a standing start, holds 500 megawatts for eight hours, and in an emergency can hold 75 megawatts for three days – a reserve the system can draw on when it matters most.
Firm generation
Natural gas turbines cover the hours storage cannot: a week of still, grey weather in February, or an outage somewhere else on the system.
They are designed from the outset to run on blended hydrogen and to accept carbon capture, so the asset has somewhere to go as both become practical rather than being stranded when they do.
This is the part of the plan that has changed most, and it deserves a straight answer rather than a quiet one. A campus that promises a customer firm power every hour of the year cannot be built on storage alone, and a project that claimed otherwise would not survive its first hard winter. The compressed air plant remains non-combustion. The turbines are what make a round-the-clock commitment honest – and what make it possible to build the storage and the renewables that do the rest of the work.
Fast response batteries
Two blocks handling the duty measured in seconds and minutes: holding frequency steady, absorbing a sudden swing, covering the gap while a larger machine starts.
Without them the big equipment spends its life chasing the grid, running at part load where it is least efficient and wearing out faster. With them, the turbines and the storage plant run where they are meant to run. The batteries are also the first thing on site to be built, which is how the project starts earning before the rest of it is finished.
One connection, not four
All four assets terminate at a single Bedrock-owned switchyard on the Hydro One 500 kV corridor that already crosses the property. Any one asset can be taken out of service without tripping the others.
That matters more than it sounds. To the grid operator the site is one resource at one point of connection, with one set of studies behind it, rather than four projects queuing separately. And because the lines are already there, no new transmission corridor has to be acquired across anybody’s farm to reach it.
Reservoirs, not caverns
Most compressed-air proposals have to excavate or solution-mine a cavern before they can store anything. That is the largest construction cost in the technology and the largest thing that can go wrong with the schedule.
Bedrock’s reservoirs already exist. They have held gas under pressure since long before anyone thought to put energy in them, which is both the engineering argument and the environmental one: the formation is proven, and reusing it means the wells reaching it are properly characterised and maintained for decades.
Not a first of a kind
Compressed air storage has run on underground formations since Huntorf in Germany in 1978 and McIntosh in Alabama in 1991, some eighty years of combined operation between them. The engineering is understood and the equipment is made by companies that have been making it for a long time.
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