Alberta’s data centre queue holds about 19,565 MW of requests, and the room already given out is 1,200 MW. That second figure is the one that runs this file. Phase 1 allocation is full, every megawatt spoken for since the first sorting. Everything behind it waits on a permanent framework, and the framework now has a shape and a clock.
The short answer. Alberta’s Data Centre Regulation has been in force since June 2026, and it directs the AESO to move projects to the front when a load arrives with new generation built for it, or storage alongside. The permanent Phase 2 framework is still being finalized. On October 30, 2026, a proponent with gas projects in the queue told investors the framework documents should land before the end of fall, followed by a six-week intake window. On the same account, every new large-load applicant will have to show signed contracts for new generation covering at least the full size of the load it requests.
The queue was always a waiting room. The window is the first door in this file that opens onto anything real.
- What did Alberta actually change in June 2026?
- Why does a six-week window matter more than the queue?
- Who arrives ready, and who arrives hopeful?
- What should a Canadian operator watch before the window opens?
What did Alberta actually change in June 2026?
Before the regulation, a connection request was mostly position and patience. The June rules changed the sorting principle itself. The province states the new order plainly on its data centre page. Projects paired with their own new generation or storage move first. The regulation also leaves room for a bridging approach, a limited set of early connections under strict conditions. Under one of those conditions, a bridged project can be required to cut its demand when the grid runs under stress.
Read that condition as the province’s insurance policy written in advance. Alberta wants the load, the construction and the tax base that follow it. It does not want a January cold snap turned into a public argument about who kept the lights on. The sorting rule and the curtailment condition are one decision seen from two sides.
Why does a six-week window matter more than the queue?
In Alberta’s site-selection meetings, the same queue figure now feeds two opposite stories. The first holds that 19,565 MW of requests means Alberta is winning the continental build-out. The second holds that a bring-your-own-power rule means Alberta has quietly closed the door. The queue figure counts requests, and a request costs a proponent a filing and a study retainer. The synthesis is plain arithmetic. The window will show how much of the 19,565 MW was a build in waiting, and how much was a placeholder parked against a better year.
Generation contracts take years to assemble. Land, turbines, interconnection studies and financing each run on their own slow clock. A proponent who began tying generation to load in the summer holds a finished hand when the window opens. A proponent who waited for the framework before starting holds a request and a rendering. Six weeks is enough time to file what already exists, and far too short to build what is missing.
Who arrives ready, and who arrives hopeful?
KALiNA Power reads like a company that started early. It holds two gas plants inside the queue, about 200 MW at Clairmont and 100 MW requested at Saddle Hills, and both were designed to serve large loads. Its October 30 quarterly report carries the window expectation, which tells its own story about preparation. The firm building the generation is the firm watching the framework calendar most closely. Saskatchewan’s file separates along the same line, between load that is real and load that is promised.
Meta’s Sturgeon County campus sits outside this contest entirely. It is already under construction at 1 GW, with its own funded generation inside the project fence. The window matters to the queue’s long tail, the projects still waiting for a way in. Somewhere inside the 19,565 MW sit serious projects with generation partners already signed. Beside them sit requests that amount to a line on a map and a hope about 2028. The intake window is the first instrument Alberta has built that can tell the two apart in public. (Saskatchewan Announced More Than $50 Billion. The Ground Outside Regina Holds 300 MW.)
What should a Canadian operator watch before the window opens?
Watch three things, in the order they land. First, the framework documents themselves, expected before the end of fall 2026, with the exact threshold a signed generation contract has to meet. Second, the bridging terms, and whether bridged projects keep the demand-cut condition. Third, the window dates once published, because six weeks from a standing start is a fixed deadline. The tax side of this same rulebook is already settled reading in Alberta’s data centre levy can drop to 0%. The host town can’t tax the servers.
For an executive siting power-hungry work in Alberta, the question to put to any developer has changed this fall. Do not ask how many megawatts the project has requested from the grid. Ask how many megawatts stand under signed generation contracts today, and ask to see the dates on them. The answer separates a project the window will admit from a project the window will expose.
The documents land before the end of fall, and then the clock runs for six weeks. A project that begins assembling its generation contracts on the day the window opens has already missed its opening. The window will ask what generation stands behind the request, in a signed contract, on the day the six weeks close.
Recap. Alberta’s queue holds about 19,565 MW of requests against 1,200 MW of allocated Phase 1 room. The June 2026 regulation sorts that queue by one test, generation brought with the load. The Phase 2 framework documents are expected before the end of fall, and a six-week intake window follows them. Readiness decides who gets in.
Follow the whole file as it moves: Canada’s data centre map: what is built, what is blocked, what is waiting.
