Alberta Power Intelligence BriefingWeek of May 23 – May 29, 2026 |
Welcome to this week's edition of IPPSA Intelligence!
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Upcoming IPPSA Event
Join us for a luncheon on June 10th as expert market forecasters will share their views on the Memorandum of Understanding between the Federal and Alberta governments regarding changes to the Technology Innovation and Emissions Reduction Regulation. | |
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Alberta Electric System Operator
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AESO shelves centralized FTR market, schedules June 15 stakeholder session on congestion management tools Market & Regulation The AESO has decided not to advance a centralized Financial Transmission Rights market at this time. It has posted an FTR Update and Discussion Paper and will host a hybrid stakeholder session on June 15 to discuss data, reporting, and market metrics around financial congestion management.
Other active workstreams include the second Internal Demand Rates workshop (June 2–5), a Reliability Standards Discussion Group update on June 11, a Transferred Frequency Response RFP closing June 12, and stakeholder feedback on GRIP requirements due June 11.
The FTR decision is notable given industry interest in congestion hedging tools as Alberta's grid faces growing connection requests.
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Alberta Utilities Commission
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AUC updates Rule 027 penalty table with revised cybersecurity reliability standards CIP-004-AB-7 and CIP-011-AB-3 Market & Regulation On May 20, the AUC approved routine amendments to Rule 027, replacing CIP-004-AB-5.1 with CIP-004-AB-7 and CIP-011-AB-1 with CIP-011-AB-3 in the specified penalties table — both previously approved in Decision 28903-D01-2024.
Penalty categories are unchanged. The AUC again determined no consultative process was required, consistent with its approach on recent administrative updates. For market participants, this is housekeeping: the operative cybersecurity obligations stay the same, just under updated version numbers.
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Brooks amends land use bylaw to regulate data centre applications, as 1,200 MW Newell County project advances nearby Policy & Transition The City of Brooks amended its Land Use Bylaw to give the municipality discretionary authority over data centre development applications — a proactive move, as no applications are currently active in city limits. The changes allow the city to require project-specific studies on water, noise, and power before issuing permits.
Data centres in Brooks would connect to the existing Fortis grid rather than bring dedicated generation; any proposals would still require AUC and AESO approvals. A 1,200 MW data centre application is separately under review in neighbouring Newell County, signalling real near-term load growth pressure on local grid infrastructure.
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Spoke Resources seeks partners for AUC-approved 9.9 MW and 2.5 MW behind-the-fence gas generation sites near Valhalla and Rycroft Generation & Infrastructure Spoke Resources Ltd. has received AUC permits for two gas-fired generation projects — a 9.9 MW facility near Valhalla and a 2.5 MW facility near Rycroft — both in its Northern Alberta natural gas operating areas. The company is running an RFP to attract partners for high-performance computing, data centre, or digital asset mining loads behind the fence, using methane-rich dry sweet gas from existing production.
The projects are small-scale but reflect a broader trend of stranded or underutilized gas assets being repositioned to serve AI and crypto compute demand directly, bypassing the grid.
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Alberta opens public comment on draft CCS protocol update that would credit DAC projects for low-carbon electricity use Policy & Transition Alberta is consulting on proposed revisions to its CCS quantification protocol that would allow eligible direct air capture projects to account for low-carbon electricity consumption when calculating emissions reductions under the large-emitter system. The update also clarifies treatment of removal credits and storage reversals.
For Alberta generators, particularly those supplying low-carbon power, this creates a potential new offtake avenue if DAC developers can formally attribute grid electricity attributes to their carbon accounting — a development worth tracking as DAC projects advance in the province.
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Saskatchewan First Nations push for equity ownership in wind, solar, biomass, and nuclear projects alongside SaskPower Renewables At the Saskatchewan First Nations Energy & Natural Resource Forum in Saskatoon, SFNRCE president Sheldon Wuttunee said First Nations are actively pursuing equity ownership and infrastructure partnerships, not just consultation roles, in wind, solar, biomass, and nuclear energy projects.
Crown Investments Corp. Minister Jeremy Harrison confirmed SaskPower's door is open for First Nations to lead on renewables. The province is also pursuing transmission upgrades in northern communities and studying natural gas extension into northwest Saskatchewan. The shift from consultation to ownership signals growing Indigenous influence over Saskatchewan's generation mix and project economics.
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Western Premiers call for faster infrastructure approvals, trade corridor investment, and federal respect for provincial electricity jurisdiction Electricity, Generation & Infrastructure At the Western Premiers' Conference, all six premiers issued a joint communique calling on Ottawa to accelerate major project approvals, implement one-project-one-review regulations, and invest in energy and transmission infrastructure. On electricity specifically, they endorsed the federal goal of doubling Canada's grid by 2050 but insisted that implementation respect provincial jurisdiction and protect ratepayers.
They also called for bilateral federal engagement on electricity priorities — a direct signal to Ottawa not to impose a one-size-fits-all national grid approach. For Alberta, the communique reinforces provincial control over generation mix decisions and supports faster permitting for pipelines, LNG, and critical minerals exports.
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SaskPower net loss climbs to $187M as NDP demands rate review restart and independent regulator Market & Regulation New documents filed with the Saskatchewan Rate Review Panel show SaskPower's net loss for 2025–26 at $187 million — $40 million worse than the $147 million figure in the original rate application. The NDP's Aleana Young called for the entire rate review consultation to be restarted, citing what she described as incomplete and shifting financial disclosures.
The government countered that the $187 million figure appeared in the 2026–27 Provincial Budget and that the variance reflects lower commercial electricity sales and higher fuel costs — standard forecast movements. SaskPower is seeking a 3.9 percent rate increase for 2026 and 2027. The episode illustrates the political volatility of Crown utility finances, a contrast Alberta's market-based generators won't miss.
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Canada Strong Fund: CAD 25B sovereign vehicle targets domestic infrastructure, with Gulf co-investment potential flagged Economic & Finance The federal government's Canada Strong Fund — a CAD 25 billion sovereign wealth fund financed through borrowing over three years — is structured to co-invest with private and foreign partners in domestic priority sectors including energy, critical minerals, and clean infrastructure.
An analysis from ORF Middle East identifies GCC sovereign wealth funds as natural co-investment partners given overlapping interests in conventional energy, renewables, critical minerals, and nuclear. For Alberta generators and project developers, the CSF represents a new potential federal capital channel, though questions persist about duplication with existing vehicles like the Canada Infrastructure Bank and the risk of politically driven capital allocation.
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Fraser Institute critiques federal Powering Canada strategy for centralizing energy choices and mandating household electrification Policy & Transition Senior Fellow Kenneth Green published a critique of Ottawa's Powering Canada Strong national electricity strategy, acknowledging its premise — that Canada will need to double electricity generation by 2050 — while criticizing provisions that would steer Canadians away from natural gas for home heating, cooking, and water heating through grants and incentives. Green also flags demand management provisions that could allow governments to draw power from household battery storage and electric vehicles. For Alberta, the commentary reflects ongoing tension between a federal decarbonization agenda and provincial jurisdiction over energy choices, particularly given natural gas's dominant role in both residential heating and Alberta's generation fleet.
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PJM considers three structural reforms to break the cycle of capacity price spikes and political intervention Market & Regulation PJM Interconnection, facing capacity price increases exceeding 1,000% across its last two auctions driven primarily by data centre interconnection requests, has outlined three reform pathways to its stakeholders. Options include mandatory long-term bilateral contracts with a reduced capacity market, a tiered reliability model allowing buyers to cap capacity costs in exchange for reduced supply guarantees, and a significantly downsized capacity market with energy market revenue recovery.
PJM's framing — that political price suppression destroys investment confidence and perpetuates shortages — is directly applicable to Alberta, where similar debates over price signals and intervention have shaped the market. The PJM exercise is worth watching as a stress test of competitive market design under extreme demand growth.
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