IPPSA Intelligence

Alberta Electric System Operator (AESO)

Alberta’s electric grid operator is fast-tracking the integration of data centres and other large loads by advancing Phase II of its Large Load Integration Program, seeking stakeholder input via pre-engagement surveys on connections, planning, market frameworks, tariffs and reliability. Concurrently, an updated interactive Transmission Capability Map provides developers and investors with site-specific estimates of available capacity for new generation, aiding siting and investment decisions.

Regulatory engagement is intensifying across multiple workstreams: technical sessions on the restructured energy market’s ISO rules are scheduled throughout October, with deadlines for comment contributions and in-person attendance requests; a Reliability Standards Discussion Group meeting will address emerging operational requirements; and workshops on tariff redesign, cost allocation, incumbency treatment, GUOC refunds, and connection process amendments will run through month-end.

These consultations signal potential shifts in market participation rules, cost responsibilities and connection protocols. Stakeholders are urged to review published materials, adhere to key deadlines—from cost claim submissions on October 1 to Large Load survey responses by October 15—and register via AESO Engage to influence outcomes.

References:

1. AESO Stakeholder Update — Data Centre/Large-Load Integration, Transmission Capability Map, REM ISO Rules & October Engagements

U of A & FortisAlberta test AC/DC converters to power EVs over existing home wiring

Rapid electrification, driven by electric vehicles and high-power DC devices, is stressing distribution grids designed for AC power. A University of Alberta and FortisAlberta collaboration led by Professor Ryan Li is developing AC/DC converters that deliver higher-voltage DC over existing AC wiring, enabling homes to support fast EV charging without costly rewiring.

Tests at FortisAlberta’s “fake house” training centre simulate real residential loads and evaluate impacts on transformers, cables and protection equipment. The approach promises to avoid roughly $50,000 per-home rewiring in older properties, reduce transformer churn, and lower utility upgrade costs. Utilities beyond Alberta are watching, signaling potential for broader adoption if trials confirm reliability, safety and cost-effectiveness.

References:

1. U of A–FortisAlberta test AC/DC converters to power EVs over existing home wiring

U.S. subsidy rollback drives CarbonCapture to Alberta’s Deep Sky direct air-capture test site

CarbonCapture, a Los Angeles firm, shifted a planned direct air capture (DAC) project from Arizona to Deep Sky’s test facility in Innisfail, Alberta, and will base operations there after testing its fan‑based CO2 extraction technology. CEO Adrian Corless said the move follows U.S. policy changes that reversed earlier flows of projects toward U.S. incentives and prompted relocation to Canada.

Deep Sky, which opened the Alberta DAC test site in August, has positioned itself as a regional testing hub, attracting multiple clients including General Electric and CarbonCapture to trial varied capture approaches. The relocation underscores how subsidy and regulatory shifts can quickly reshape investment and siting decisions in the cleantech supply chain, steering technology validation and scale-up across borders.

References:

1. U.S. subsidy rollback drives CarbonCapture to Alberta’s Deep Sky direct air-capture test site

Hitachi Energy’s $270M Varennes expansion to nearly triple transformer output

Hitachi Energy is investing $270 million to expand its power-transformer factory in Varennes, Quebec, adding to a $140‑million upgrade announced in April 2024, and together these projects aim to nearly triple annual production and more than double site employment to at least 900. The plant manufactures large power transformers and specialized units for static compensators, HVDC systems and nuclear applications, serving utilities such as Hydro‑Québec and industrial clients like Bruce Power.

Federal and Quebec governments are contributing a combined $26 million. The expansion is part of Hitachi’s broader US$9‑billion global investment program and follows a US$1‑billion U.S. expansion amid surging transformer demand driven by data centres, AI computing and electrification. Large transformers are costly, heavy and long‑lead, so boosting domestic capacity can shorten supply chains, strengthen energy sovereignty and support regional transmission plans.

References:

1. Hitachi Energy’s $270M Varennes expansion to nearly triple transformer output and boost Quebec jobs

NuARC Partnership to Deploy ARC‑100 Sodium‑Cooled SMRs 

NuARC, a partnership between Calgary’s Nucleon Energy and ARC Clean Technology Canada, aims to commercialize the ARC-100 sodium‑cooled fast small modular reactor across North America, initially targeting Alberta and potential Texas and New Brunswick sites. ARC-100 is a 100 MW integrated sodium‑cooled fast reactor using a metallic uranium‑alloy core and traces its heritage to EBR‑II; ARC has completed Phase 2 of the Canadian Nuclear Safety Commission’s Vendor Design Review. Nucleon will provide project development, siting and operations expertise while ARC supplies reactor technology.

The companies promote the design for electricity, industrial heat and medical isotope production, touting modular construction, safety and energy‑security and economic benefits. Public technical documentation is limited, with most available material being conference presentations rather than detailed design reports. The partnership has an ambitious deployment timeline—Point Lepreau eyed for 2030—which the article frames as challenging given historical multi‑decade development of sodium‑cooled fast reactors and the technical and regulatory hurdles remaining.

References:

1. NuARC Partnership to Deploy ARC‑100 Sodium‑Cooled SMRs Across North America

SaskPower’s Estevan Plan: Coal Life-Extensions, Potential SMR, Turning Sun 100 MW Solar and Major Transmission Upgrades

Saskatchewan is positioning Estevan as a continued energy hub by extending about 1,500 MW of coal-fired generation beyond 2030 while simultaneously advancing renewables, transmission upgrades and preliminary small modular reactor siting work. SaskPower has launched assessments of Boundary Dam, Shand and Poplar River units to guide coal life-extension procurement and will seek industry expert input before advancing plans.

Work toward a potential small modular reactor includes multi-year project development, licensing and regulatory steps; no final investment decision has been made. Renewable growth includes multiple wind projects and the 100 MW Turning Sun solar development west of Estevan, expected to begin construction before year end and create up to 150 direct construction jobs. The strategy balances short-term government direction to keep coal online with a net-zero-by-2050 goal, offering near-term local economic and procurement opportunities.

References:

1. SaskPower’s Estevan Plan: Coal Life-Extensions, Potential SMR, Turning Sun 100 MW Solar and Major Transmission Upgrades

Pincher Creek's wind capital in peril after Alberta’s 35‑km Rocky Mountain buffer

Alberta’s shift in renewable rules, a 2023 moratorium followed by a regulation banning new wind and solar projects within a 35-kilometre Rocky Mountain buffer, has transformed Pincher Creek from Canada’s “wind capital” into an uncertain local economy. The buffer, framed as protection of prairie viewscapes and enacted under Premier Danielle Smith, applies only to renewables; exemptions exist for in-buffer projects and the Alberta Utilities Commission can still approve developments case by case, but regulatory ambiguity has chilled investment.

Pincher Creek hosts roughly 255 turbines producing about 511 MW, and a Pembina Institute analysis estimates wind revenues account for about 30% of the district’s budget while landowners receive lease payments. Local leaders report backlash over transmission lines and visual impacts; some now favor repowering, replacing many older machines with fewer larger turbines, to preserve capacity, reduce visual clutter, and sustain municipal income.

References:

1. Pincher Creek's wind capital in peril after Alberta’s 35‑km Rocky Mountain buffer

IESO opens 18‑month public engagement to shape regional electricity plan as northwestern Ontario demand could double by 2050

The Independent Electricity System Operator (IESO) has launched an 18‑month public engagement to develop a regional electricity plan for northwestern Ontario, responding to forecasts that electricity demand north of Dryden could more than double by 2050 as mining activity and community growth accelerate. IESO recommends new transmission corridors to move power from generation sites to growing load centres and enable mine siting and expansion.

Engagement seeks broad input from Indigenous communities, municipalities, developers, industry and consumers on timing, scale, siting and local characteristics to refine regional technical recommendations. If forecasts materialize, timely transmission and generation investments are essential to avoid constraints, shape project locations, influence economic and workforce plans, and ensure Indigenous and municipal priorities are reflected.

References:

1. IESO opens 18‑month public engagement to shape regional electricity plan as northwestern Ontario demand could double by 2050

Western Canadian Gas Producers Curtail Output Amid Pipeline Bottlenecks and Slow LNG Ramp-Up

Record low and even negative spot prices at Western Canada's AECO hub have prompted producers to sharply curtail natural gas output as oversupply meets weak demand and pipeline constraints. AECO briefly hit −$0.18/MMBtu and averaged about −$0.05 recently, while year‑to‑date prices are near $1.03/MMBtu and storage sits at last year’s record highs.

Planned and unplanned maintenance on TC Energy’s NGTL and Great Lakes systems has trapped gas in Alberta, limiting flows to other markets, and the slow ramp‑up of LNG Canada has failed to absorb excess volumes producers had anticipated. 

References:

1. AECO Plunges Negative: Western Canadian Gas Producers Curtail Output Amid Pipeline Bottlenecks and Slow LNG Ramp-Up

Drought Drives Manitoba Hydro Losses and Power Imports

Manitoba Hydro’s finances have been squeezed by consecutive drought years that cut hydroelectric output, forcing costly power imports and contributing to a consolidated net loss of $63 million in 2024–25 following a $157 million loss the prior year. Low precipitation constrained wholesale sales and pushed the utility into import markets; Hydro already recorded a $61 million loss in April–June 2025.

Electric operations lost $49 million and natural gas $27 million, partially offset by $13 million from subsidiaries. Year‑over‑year improvement reflected lower fuel and purchase costs plus higher domestic and gas revenues, while operating, maintenance, administrative and finance expenses rose. The provincial government has budgeted a $200 million contingency to cushion expected shortfalls and is advancing an “affordable energy plan” that includes 600 MW of Indigenous‑owned wind to diversify supply and reduce hydrology risk.

References:

1. Drought Drives Manitoba Hydro Losses and Power Imports; Province Announces $200M Contingency and 600 MW Indigenous Wind Plan

Proposed Chinook Feeders Biodigester in Foothills County

The proposed biodigester at Chinook Feeders would convert organic waste into biogas and digestate, offering a local waste‑to‑energy solution that could reduce landfill inputs and greenhouse gas emissions while producing renewable heat or electricity and nutrient‑rich biofertilizer. Proponents highlight resource recovery and potential economic benefits from energy production and digestate sales; suppliers and off‑takers could create new regional value chains.

The project also raises practical community and infrastructure considerations: increased truck traffic may accelerate wear on rural roads, while neighbours could experience odour, noise and visual changes. Environmental risks, groundwater protection, digestate management and emissions would require careful siting, operational controls and ongoing monitoring.

References:

1. Proposed Chinook Feeders Biodigester in Foothills County: Renewable Biogas Potential and Local Impact Concerns

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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.