IPPSA Intelligence

Alberta Electric System Operator 

Market participants must prepare for AESO’s switch from Mountain Daylight Time to Mountain Standard Time on Nov. 2 by adjusting their Energy Trading System submissions to include an extra hour-ending (HE 02*) while noting that Daily System Measurement transactions will instead adopt a 25-hour numbering convention. Failure to incorporate HE 02* could lead to dispatch errors.

Meanwhile, AESO is inviting stakeholder input on a spectrum of initiatives spanning optimal transmission planning, tariff redesign, connection process amendments, dispatch variance parameters, market power mitigation costs, data-centre connection requirements and reliability standard synchronization. Key milestones include recommendations and feedback deadlines on Oct. 31 for the OTP framework, Nov. 3 on incumbency treatments, Nov. 12 on ISO rules, Nov. 20 on tariff amendments, and Dec. 19 on reliability standards. Stakeholder sessions will address the 2025 RSDG update on Oct. 30, allowable dispatch variance on Nov. 5, market power mitigation opportunity costs on Nov. 6, and transmission-connected data-centre requirements on Nov. 27.

By actively engaging in these consultations and adhering to ETS submission guidelines for the daylight-savings transition, stakeholders can influence rule development, ensure compliance and mitigate operational risk.

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MSA Comments on AESO REM Draft Rules

Following the AESO’s request for feedback on the proposed REM ISO rules (issued September 4, 2025) and a stakeholder session held October 9, the MSA reviewed the draft rules to evaluate whether they are clear and concise, complete (to the extent possible), practically implementable, and consistent with the statutory scheme.

The MSA raises three broad areas of concern:

1. Use of Information Documents (IDs/MIDs): The MSA warns that relying on non-rule documents for key methodologies undermines certainty and enforceability—these details should instead be embedded in the ISO rules themselves.

2. Excessive Discretion and Subjective Requirements: Many rules allow the AESO to “may” rather than “must” act, and contain vague notions such as “reasonable period,” or “best data available,” which the MSA says weaken predictability and fairness.

3. Drafting Gaps and Implementation Risks: The MSA identifies undefined terms, missing timelines, and unspecified methodologies (for example in cost allocation, dispatch order, reference levels, price correction) that could hamper practical implementation or lead to unintended market outcomes.

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Residents back engagement but oppose proposed Peace River nuclear plant

Residents of Northern Lights County and nearby Manning voted in a non-binding plebiscite to gauge local appetite for Energy Alberta’s proposed Peace River Nuclear Power Project, which would deploy two to four Candu Monark reactors, produce up to 4,800 MW over roughly 70 years (about 25% of Alberta’s current generation) and feed federal/provincial review.

Northern Lights voters backed engaging governments and residents (489–260) but rejected hosting the plant (338–450); Manning showed similar splits (engagement 155–61; plant 101–112). Turnout was about 32–34%. Many respondents said they wanted more information; Indigenous and local opponents questioned the need for nuclear given regional gas supplies and raised trust and transparency concerns.

Energy Alberta called early opposition expected. The plebiscite is advisory—the authority for approval, licensing and construction rests with federal and provincial regulators—with a federal review expected by 2028 and possible construction in 2029 if approved. 

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Capital Power Q3 Results: cautious on Alberta nuclear, secures MCV recontract and pursues 250‑MW data‑centre opportunity

Capital Power is engaging with Alberta’s nuclear consultations, expressing interest but withholding capital until market and contracting frameworks in the province’s energy‑only market are clarified. Management emphasised commercial due diligence rather than near‑term deployment. In parallel the company is executing a commercial‑optimization strategy by recontracting existing thermal assets: a new Consumers Energy agreement for the Midland Cogeneration Venture in Michigan to 2040 will cover three quarters of capacity from June 2030 and is projected to boost gross adjusted EBITDA by about $140 million, materially improving cash flow without new‑build exposure.

Capital Power is also pursuing adjacent customer-led opportunities, signing a term sheet for a potential 250‑MW data‑centre near MCV under a PPA of up to 15 years, reflecting rising demand for stable power and the strategic value of reliable gas generation for grid stability. Q3 results showed higher revenues and adjusted funds from operations but lower net income year‑over‑year.

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Smith’s mandate to Nally: attract blockchain miners using wellhead-generated power

Alberta’s new mandate for the minister responsible for Service Alberta and Red Tape Reduction outlines regulatory modernization, industry promotion and consumer‑facing service changes designed to accelerate approvals and attract investment.

Key initiatives include extending the Automatic Yes permitting framework to speed low‑risk permits; promoting on‑site conversion of excess wellhead natural gas into electricity to power blockchain/bitcoin mining (noting an existing partnership with Bitdeer). The mandate frames on‑site power for digital infrastructure as a way to monetize flared or stranded gas without new pipelines, potentially generating local royalties and new tech‑sector jobs.

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Wonder Valley’s $70B AI data‑centre stalled

Kevin O’Leary’s proposed $70 billion Wonder Valley AI park in Greenview on the Montney formation remains aspirational nearly a year after a high‑profile launch: no confirmed land purchase, financing, design or required provincial, AUC, water and municipal approvals.

Alberta’s government actively promoted an AI‑data centre strategy and concierge assistance, but the project’s energy plan relies initially on on‑site natural gas generation paired with a carbon‑capture corridor (with geothermal cited as a later option), needing roughly 1.4 GW for phase one and scaling toward 7.5 GW.

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Alberta Could Unlock $11.1B in Benefits by Adopting Demand‑Side Management, Pembina Institute Says

Alberta could unlock significant economic and grid benefits by adopting demand-side management (DSM) programs that utilities elsewhere in North America already use effectively. 

Pembina Institute analysis suggests Alberta’s DSM deployment aligned with building retrofit programs could yield a cost‑benefit ratio of about 2.3, translating to roughly $11.1 billion in net benefits from 2019–2038. Beyond direct consumer savings, DSM lowers system peaks, defers infrastructure spending, improves reliability, and stimulates local retrofit and clean‑tech markets, supporting jobs and stronger regional economies.

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Eby Threatens Early Election as Legislature Considers Fast‑Track for North Coast Transmission Line

British Columbia’s government is pushing Bill 31 to fast‑track construction of the multibillion‑dollar North Coast Transmission Line to supply power for planned resource projects in northwestern B.C. Premier David Eby has tied his administration’s fate to the bill, warning he will call an early election if it fails, underscoring the legislature’s precarious one‑seat NDP majority and the decisive role of two Green MLAs.

A Conservative motion to delay the bill by six months was defeated 48–40. The government frames the project as “of crucial importance,” promising roughly 10,000 jobs and arguing delays threaten provincial economic prosperity. Bill 31 primarily advances procedural acceleration for major energy infrastructure, raising questions about reduced legislative scrutiny, stakeholder consultation and environmental assessment timelines not detailed in reporting. 

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Google Signs First U.S. Corporate Power Deal for 400MW Gas Plant

Google has signed an offtake agreement for power from a planned 400 MW natural-gas plant with carbon capture and storage (CCS) near Decatur, Illinois, a first-of-its-kind U.S. corporate purchase tied to a CCS-equipped power plant. Developed by Low Carbon Infrastructure at an Archer Daniels Midland (ADM) industrial site with existing CO2 injection experience, the Broadwing project aims to capture roughly 90% of CO2 and begin operations in the early 2030s. Financial terms were not disclosed.

The deal reflects Google’s strategy to secure reliable, low‑carbon, around‑the‑clock electricity for data centres alongside purchases of advanced nuclear, geothermal and hydropower and collaboration with grid operators to speed interconnections. Backing from a major corporate buyer can lower project risk, potentially mobilize private capital for more CCS plants and demonstrate commercial viability, particularly when sited at locations with injection infrastructure. 

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NDP Warns SaskPower Could Be Privatized Based on Nuclear Ownership Report

Saskatchewan’s political debate over the future of SaskPower centers on fears the Crown utility could be privatized, prompted by an NDP warning that cites a report exploring ownership models for future nuclear projects. The provincial government, led by Premier Moe, forcefully denies any intention to sell SaskPower, framing the exchange as political posturing rather than a policy shift.

At issue are alternative financing and governance options for large-scale, low-carbon generation—particularly nuclear—where private, public-private partnership, Indigenous or federal participation could change who controls assets and bears risk. That conversation raises tangible implications for electricity rates, long-term accountability, infrastructure stewardship, and local economic benefits from construction and operations.

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Manitoba Proposes Three Energy Megaprojects to Deliver $30B

Manitoba’s government is pitching three energy megaprojects—including an expansion of the Port of Churchill—as a platform for roughly $30 billion in economic activity, aiming to accelerate the province’s fiscal turnaround. The most concrete proposal is the Churchill port expansion, for which provincial officials are seeking federal funding; two other large projects remain undisclosed.

Manitoba Hydro warns of growing electricity demand that could require doubling or tripling current 6,100 MW capacity over coming decades and flags a risk of winter shortfalls within about four years. In response, Hydro is pursuing partnerships with Indigenous-led developers to add roughly 600 MW and has applied to build a roughly 500 MW fuel-burning plant as a near-term backstop. The push to attract data centres and AI investment highlights rising industrial power demand and wider tech-related economic opportunities.

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U.S. Backs Cameco–Brookfield Plan to Build $80B of Westinghouse Nuclear Reactors, Secures Profit Stake by Yahoo Finance

Cameco Corp., together with Brookfield Asset Management and the U.S. government, launched a major push to expand U.S. nuclear capacity by building Westinghouse reactors, a move that sent Cameco shares up over 20%. Following Brookfield and Cameco’s late‑2023 acquisition of Westinghouse, the new agreement commits the federal government to help arrange financing and streamline permitting for at least $80 billion of reactor projects, reflecting a strategic fusion of private capital and public support.

Under the deal the government would receive 20% of cash distributions above $17.5 billion from Westinghouse’s future profits, with an option to convert that interest into equity pending final investment decisions and supplementary agreements. 

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Babcock & Wilcox to Study 640 MW Marguerite Lake CAES and Hydrogen Hub

Babcock & Wilcox has been contracted to study the Marguerite Lake project in Alberta: a 640 MW compressed-air energy storage (CAES) and hydrogen hub planned in two 320 MW phases. The design stores renewable electricity by compressing air into underground salt caverns and later releases and reheats it — with natural gas or hydrogen options — to drive turbines for dispatchable generation.

B&W’s BrightLoop process is proposed to integrate hydrogen production (up to 60 tonnes per day) using oxide particles to produce steam, hydrogen or syngas while isolating CO2 for storage, enabling potential net‑zero operation. The hub combines long‑duration grid storage, local hydrogen supply and carbon capture in a single facility, illustrating an emerging trend of pairing storage with hydrogen and CO2 management to support grid stability and decarbonization. 

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