IPPSA Intelligence

AESO

Alberta’s electricity system is undergoing coordinated enhancements in market design, grid infrastructure and broader regulatory frameworks. Quarterly long-term adequacy metrics will be published Feb 2, detailing generation projects, reserve margins and supply cushions to inform reliability planning.

Engagement on Financial Transmission Rights accelerates with the Feb 4 information session—including publication of the Brattle Report on FTR models—and a two-day hybrid stakeholder workshop Feb 25–26 to shape enduring congestion management tools. Grid planning signals continued integration of solar and battery projects, with Needs Identification Documents released for Castor North and Red Willow connections, while the Meadowlark substation upgrade enters the Abbreviated Needs Approval Process on or after Feb 12.

Northland Power’s Luna Solar + Phase One connection has been withdrawn, altering local capacity forecasts. ISO tariff redesign efforts focus on internal demand rates, with a revised rate-design longlist, scorecard and stakeholder submissions due by Feb 17.

An updated engagement calendar outlines steps to refine ongoing cost allocation, bill structures and evaluation criteria. Stakeholders can access materials, register for sessions and submit feedback through AESO Engage.

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AUC Approves Korkia’s 430 MW Uk Solar East and West Projects

Alberta’s solar sector is poised for growth following the regulator’s green light for two large-scale projects near Oyen, totaling 430 megawatts. Finnish investor Korkia received approval for Uk Solar East (268 MW) and Uk Solar West (162 MW), marking a crucial advance before final investment decisions and potential construction. The Alberta Utilities Commission’s mandate includes coordinated environmental reviews with the provincial parks and environment department to ensure minimal ecological impacts, reflecting heightened scrutiny over land-use and habitat disruption.

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Alberta Town Selected for Canada’s Largest Data Centre

The Town of Olds, Alberta, has been chosen as the site for what is planned to be Canada’s largest data centre, with Synapse Data Centre Inc. announcing a $10 billion investment to build a one-gigawatt facility there over the next two years. The centre would span about 2 million square feet on roughly 300 acres, create an estimated 2,000 construction jobs and 1,000 permanent positions, and significantly boost the region’s digital infrastructure to support artificial intelligence, cloud computing and data-intensive operations.

The proposed project—one of two data centre developments recently announced for Olds—would be powered by an on-site closed-cycle natural gas system designed for low emissions and not connected to Alberta’s main grid, reducing strain on public infrastructure while maintaining reliability. Synapse cited Olds’ industrial gas access, strong fibre connectivity, and strategic location between Calgary, Edmonton and Red Deer as key reasons for its selection.

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B.C.'s Power Dilemma

British Columbia faces a policy crossroads as surging, energy‑intensive AI and data‑centre demand collides with constrained electricity supply, prompting the province to shift from promotion to rationing through competitive allocations and permanent exclusion of cryptocurrency mining. Government leaders justify prioritizing projects that deliver broader public benefit — such as mines — to avoid higher household costs and stranded transmission — but that approach risks sidelining AI investment that delivers few local jobs yet large economic spillovers.

Tightening grid math, growing reliance on imports, and slow transmission builds create a shortfall that renewables alone may not fill quickly; the author argues B.C.’s two major assets, hydro and natural gas, should be used more flexibly, with gas as a pragmatic bridge to meet baseload needs while decarbonization progresses.

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Provinces have too much power, and Canada’s economy suffers as a result

Economist Kevin Yin argues that Canada’s system of federalism—while essential at Confederation—is increasingly ill-suited to today’s economic challenges. Strong provincial autonomy creates coordination problems that fragment the national economy, particularly through interprovincial trade barriers, regulatory differences, and limits on labour and services mobility. The IMF estimates eliminating these barriers could raise Canada’s GDP by 7%, yet key sectors like services, food, alcohol, trucking, finance, and health care remain constrained by provincial rules that add costs and reduce productivity.

Yin also contends that federalism hampers nation-building infrastructure, such as pipelines and electricity transmission, by incentivizing provinces to protect short-term local interests over long-term national gains. This fragmentation raises costs, slows renewable energy adoption, and increases investor uncertainty—exacerbated by provincial-first political rhetoric. 

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Saskatchewan to Evaluate Large Nuclear Reactors While Advancing SMR Development

Saskatchewan is initiating a formal evaluation of large nuclear reactor technologies while advancing small modular reactor (SMR) plans, signaling a long-term pivot toward nuclear-informed energy security. Under the provincial Energy Security Strategy, SaskPower will assess large reactors in parallel with ongoing SMR development, emphasizing use of Saskatchewan uranium, partnerships with experienced nuclear operators, and continued engagement with Indigenous rightsholders, communities and businesses.

Government frames nuclear as safe, reliable and non-emitting, capable—together with expanded intertie capacity—of meeting growing domestic demand and enabling electricity exports. Practical hurdles are acknowledged: large reactors carry 15–20 year timelines, requiring extensive regulatory approvals, siting studies, infrastructure upgrades and sustained public engagement before construction. SMR progress continues, with a site decision for an initial SMR near Estevan expected later in 2026.

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SaskPower Keeps Grid Stable, Exports 500 MW During Continent-Wide Winter Outage

Saskatchewan’s power system held steady through a severe continental winter storm, maintaining customer service and exporting electricity to neighbouring markets. Over the weekend the utility sold 150 MW into the Southwest Power Pool and roughly 350 MW into MISO via interties with Manitoba and Alberta while much of central and eastern North America experienced outages.

During the cold peak near −30°C, average system demand stayed above 3,500 MW and about 61% of generation came from natural gas and 29% from coal, together supplying roughly 90% of output; facilities such as the Great Plains Power Station exemplify the dispatchable thermal capacity that met that demand. SaskPower frames the outcome as validation of its Energy Security Strategy, which emphasizes grid strengthening, transmission investment and preserving export capability to ensure long‑term energy stability for communities and businesses.

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Court Backs Saskatchewan Plan to Run Three Coal Plants Until 2050

Saskatchewan has decided to refurbish and extend three coal-fired plants — Shand, Boundary Dam and Poplar River — to operate until 2050, framing the move as a short- and medium-term strategy to safeguard grid reliability, affordability and energy security while the province develops nuclear options such as small modular reactors and pursues a net-zero grid by mid-century.

The extension conflicts with the federal 2016 commitment to phase out conventional coal by 2030, prompting a judicial review by environmental groups and residents; the Court of King’s Bench dismissed the challenge, ruling the decision a political policy matter beyond judicial review. Legally, the ruling underscores limits on courts intervening in provincial energy policy; politically, it sharpens federal–provincial tensions over climate implementation.

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WECC Warns Pacific Northwest Could Face Power Shortages by 2028

WECC’s assessment warns the Pacific Northwest faces growing electricity shortfalls as rapid electrification and heavy additions of wind, solar and batteries outpace firm capacity and transmission. Shortages could begin as early as 2028, with modeled shortfall hours ranging from 445 to 1,294 over a decade depending on how many planned projects are built; high-load scenarios show multi-day loss-of-load events by 2035.

Roughly 90% of planned Western Interconnection capacity is weather-dependent, creating seasonal and timing mismatches—solar underperforms in winter while wind is highly variable—while about 80% of Northwest projects are labeled speculative. Transmission constraints and limited import capability from California, British Columbia and Alberta reduce flexibility.

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NB Power Announces 500 MW RIGS Peaking Plant and $300M+ Transmission Upgrades

New Brunswick is moving to strengthen its electricity system with a coordinated package of generation and transmission investments aimed at integrating renewables and improving reliability. NB Power’s Renewable Integration and Grid Security (RIGS) initiative will add a 500 MW dual‑fuel peaking plant in Westmorland County—expected online by 2028—using natural gas primarily and incorporating synchronous condensers to stabilize frequency and support variable wind and solar output.

Complementing generation, more than $300 million in transmission upgrades approved by the provincial regulator will reinforce high‑voltage lines into the Saint John area, add a major transformer and a STATCOM voltage‑stabilizing device, and improve compliance with reliability standards.

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Urgent Action Needed to Secure New Brunswick’s Electricity Future

Energy security in New Brunswick has become an urgent, multifaceted challenge as rising demand, aging infrastructure and a regional squeeze on surplus power converge. NB Power’s leadership emphasizes that keeping lights on now requires both near-term operational resilience and longer-term capacity additions. Recent cold spells and the temporary offline status of Point Lepreau exposed vulnerabilities even as a diversified portfolio helped meet demand. With neighboring provinces also experiencing constraints, historic reliance on imported surplus is no longer dependable.

NB Power is pursuing several practical responses: contracts for about 675 MW of renewable generation, deployment of battery energy storage, a new generating station planned at Centre Village to firm intermittent resources, and continued investments to refurbish existing facilities such as Point Lepreau and Mactaquac. Those steps aim to balance reliability, emissions reductions and cost impacts, but they demand coordinated policy support, capital investment and customer engagement.

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Manitoba Hydro’s reported $25‑billion deficit could push up electricity bills

Manitoba Hydro faces a reported $25-billion deficit that has prompted political alarm and raises the prospect of higher electricity bills for residents and businesses. An opposition MLA used testimony from the finance minister and Hydro officials at a legislative committee to warn that growing Crown-corporation debt could force rate increases unless management or policy changes. The report spotlights a broader trend of mounting public-utility liabilities, increased scrutiny of Crown governance and potential strain on provincial finances.

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IPPSA's Mandate

IPPSA's mission is to convene industry, providing information, resources, and a forum for knowledge sharing, and to create opportunities for dialogue, collaboration, and education. This newsletter is meant to inform members but not advocate for specific outcomes. We always appreciate your feedback at info@ippsa.com.