IPPSA Intelligence

Alberta Electric System Operator (AESO)

Two planned projects – the Black Bear Combined Cycle Power Plant and the St. Albert Villeneuve Solar Project – have been cancelled, with no application under Section 501.3 to the AUC. Administrative amendments to Section 501.3 were approved by the AUC, effective April 7, streamlining the Abbreviated Needs Approval Process and clarifying interconnection procedures.

Work on ISO tariff redesign continues with stakeholder sessions on April 15–16 focusing on transmission reinforcement payment and connection process changes; relevant materials will be available on AESO Engage beforehand.

A series of workshops and deadlines are scheduled throughout April and May: internal demand rates (April 7–9), tariff connection obligations (April 10), cost claim submissions (April 13), reliability standards sync-up (April 21–22), cluster assessment feedback (April 24), and written comments on high-complexity and milestone RSWs (May 15).

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AUC consultation with municipalities on proposed standardized setbacks for renewable infrastructure

The Alberta Utilities Commission (AUC) announced it is launching a targeted consultation with municipalities on potential standardized setback requirements for renewable energy projects, following earlier province-wide engagement under its Rule 007 review. While broad stakeholder feedback did not support including fixed setback distances in the updated rule, the AUC is now seeking more focused input from municipalities to explore default setback standards for wind and solar developments.

For the electricity industry, this signals continued regulatory evolution around renewable project siting and approvals, with municipalities playing a larger role in shaping development conditions. The outcome could influence project timelines, land availability, and investor certainty, particularly as Alberta balances renewable growth with local concerns and land-use priorities.

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Revolve Renewable Power Moves Toward Monetization

Revolve Renewable Power (REVV) advanced development and potential monetization of wind and solar projects, securing an interconnection agreement with CFE and an initial SEMARNAT environmental permit for the 130 MW El 24 wind project in Tamaulipas. Management targets build‑ready status by end of 2026 and possible commercial operation in late 2028, while continuing engineering and pursuing a potential sale.

In Alberta, the 15.7 MW Bright Meadows solar moved to AESO Stage 3; completing Stage 3 and securing a PPA would make it build‑ready and add an asset with projected annual EBITDA of US$2.5–2.8 million and margins above 85%. The company operates run‑of‑river, wind and solar across Canada, the United States and Mexico.

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Olds Data Centre Town Hall Raises Concerns

A proposed $10 billion data centre in Olds, Alberta has sparked wide community and regulatory scrutiny following Synapse Data Center Inc.’s initial application closure by the Alberta Utilities Commission (AUC). The AUC halted the process on March 6, citing missing environmental and noise impact assessments and an incomplete participant involvement program. On April 7, around 150 residents gathered at Olds College for a town hall hosted by MLA Tara Sawyer, where Alberta’s Minister of Technology and Innovation, Nate Glubish, listened to local concerns.

He emphasized that while the province supports data centres in principle, each project must comply fully with regulations to proceed. Residents voiced worries about the facility’s proximity to housing, potential environmental effects and noise levels. Synapse plans to address these gaps, resubmit its application, and continue in-person consultations. The provincial government has stressed neutrality, focusing on transparent rule enforcement rather than advocating for the project’s approval.

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UCalgary’s Rudiger Tscherning on SMRs, Policy Reform and Decarbonization

Dr. Rudiger Tscherning’s work at the University of Calgary drives a transdisciplinary push to integrate small modular reactors (SMRs) into Alberta’s energy mix by linking legal, policy and technical research with provincial advisory roles and international institutions.

His research targets regulatory and governance barriers to nuclear deployment, explores industrial SMR applications to replace coal and decarbonize oil-and-gas operations, and highlights how nuclear-generated heat and electricity could free gas for export markets, aiding global coal-to-gas displacement.

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Mapping Canada's 309 Data Centres

Canada’s data‑centre landscape has shifted from many small, legacy facilities to a wave of AI-focused proposals that are vastly more power-hungry, reshaping provincial strategies, grid planning and community debates. The Logic identified 309 operating and proposed centres clustered in urban corridors, with new AI projects measured in hundreds of megawatts to gigawatts and estimated construction costs of roughly $19.5–$33.5 million per MW driven by specialized chips.

Provinces are diverging: Alberta aggressively markets acreage and saw dozens of gigawatts pitched but only a few approvals amid grid limits; Quebec’s hydro advantage is tempered by Hydro‑Québec rate changes and tighter control; B.C. capped new allocations and banned crypto mining; Ontario remains the hub of legacy capacity with selective large‑site interest. Many megaprojects lack anchor tenants or confirmed power, making financing and regulatory approvals decisive.

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BTC Digital and Aurora Energy to Build 5–10 MW Off‑Grid Natural Gas‑Powered ‘Energy‑to‑Compute’ Facility

BTC Digital and Aurora Energy announced a joint development agreement to build a 5–10 MW off‑grid computing facility in Alberta that will use locally stranded natural gas to generate electricity for Bitcoin mining and future AI/data‑center workloads. The project tests an "Energy‑to‑Compute" model that directly converts stranded gas into on‑site power to lower costs, boost utilization, and enable modular, high‑performance compute capacity where grid connections are limited or expensive.

BTC Digital will provide mining hardware, operations and digital infrastructure; Aurora supplies on‑site gas and generation. The approach aligns with broader industry trends toward energy‑backed compute platforms and modular data centers positioned close to fuel or renewable sources.

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Proposed 400 MW AI data‑centre in Vulcan County sparks rezoning debate over power, water and community impact

Eric Steeves, a fifth‑generation Vulcan County farmer, is proposing a large AI data‑centre campus on about 340 hectares rezoned from rural general to rural industrial, aiming to begin construction in Q3 2027. The first phase targets 400 MW of dedicated compute capacity (with potential to expand to 800–1,000 MW), drawing power from grid upgrades and water from Travers Reservoir for cooling. Steeves plans initial financing by offering local farmers first investment opportunity before courting a major corporate partner.

Municipal rezoning, provincial permits and formal grid‑connection agreements are required, and Vulcan County council will consider the rezoning in May.

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Ottawa and Saskatchewan invest $911,100 to build SMR nuclear supply-chain capacity

Federal and provincial governments announced investments to prepare Saskatchewan businesses and communities for participation in Canada’s small modular reactor (SMR) supply chain. Ottawa provided $625,100 to SIMSA, OCNI and SETH, and Saskatchewan added $286,000 via Crown Investments Corporation to fund education, industry connections, micro-credentials and accreditation support so local firms can meet nuclear standards and link with vendors.

The initiative aims to capture economic and workforce opportunities: Canada’s nuclear sector already employs about 89,000 people, contributes $22 billion to GDP and is 89% high-skill; Saskatchewan alone will need roughly 2,500–3,500 skilled workers for SMR construction and operation, with more roles across manufacturing and services. Saskatchewan’s world-class uranium deposits—supplying nearly a quarter of global reactor uranium—position the province as a strategic hub for a made-in-Canada nuclear supply chain.

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How Policy, Markets and Data Centers Drive West Virginia's Soaring Electric Bills

Rebecca Michalski’s $940 February electric bill and other West Virginians’ mounting statements illustrate an affordability crisis driven by multiple forces. Electricity prices rose 4.8% year‑over‑year in February while piped natural gas climbed 10.9%, and geopolitical tensions and expanding LNG exports have magnified fuel‑market volatility. West Virginia’s generation remains about 87% coal, and state policy and a Public Service Commission aligned with industry interests have favored keeping coal plants online, contributing to higher costs as utilities seek billions — nearly $31 billion in requests nationally — in rate increases to pay for aging grid upgrades and new load capacity.

Large, power‑hungry data centers threaten to further strain supply and water resources, prompting local opposition. Households and small businesses face acute impacts: over one in three households are energy‑burdened, median incomes have fallen in real terms, customers face shut‑offs, and retailers or bakeries have closed.

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Net‑metering changes and federal tax credits drive 82% jump in Nova Scotia commercial solar

Commercial solar deployment in Nova Scotia accelerated in 2025, with commercial capacity rising 82% and ninety‑nine new commercial installations (a 41% year‑over‑year increase), bringing the province to at least 342 commercial systems while residential capacity totals about 110 MW and roughly 13,000 customers participate. Policy shifts allowing commercial systems up to ten times larger—capped at 1 MW—and a net‑metering credit for on‑site generation, combined with a 2023 federal corporate tax credit covering up to 30% of capital costs, improved project economics and spurred investment from municipalities, First Nations and corporations.

Nova Scotia Power reported about 42% renewables in 2025 but solar remains roughly 1% of the mix; the utility targets 80% renewables by 2030 by retiring coal and leaning on onshore wind and imports from Labrador’s Muskrat Falls via subsea cable. Longer‑term plans include the proposed Wind West offshore project, potentially 40 GW by 2050 with an initial 5 GW procurement, that has federal interest.

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DOE FY2027 Budget Request: $53.9B with Nearly $45B Targeted to Nuclear Energy and Deterrence

The U.S. Department of Energy’s FY2027 budget request totals $53.9 billion, with nearly $45 billion directed toward nuclear energy and deterrence programs, signaling a pronounced federal pivot to nuclear infrastructure, fuel supply and national security. The National Nuclear Security Administration would receive $32.8 billion, a roughly 12% increase to accelerate warhead life-extension programs, infrastructure upgrades, naval reactor R&D, emergency response capabilities and expanded HALEU production to support commercial advanced reactors.

Environmental Management is funded at $8.2 billion, sustaining legacy cleanup including about $3 billion for Hanford operations and low-activity waste processing. A separate $3.5 billion for rapid deployment of firm baseload power likely targets nuclear and geothermal demonstrations and fuel-cycle research. The proposal trims roughly $2.7 billion from programs characterized by the administration as “Green New Scam” and eliminates DEI funding, reflecting a reallocation away from certain renewable and social-program expenditures.

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ECP Reacquires EnergySolutions for $2B, Signaling Private Equity’s Bet on Nuclear Services

Energy Capital Partners’ re‑acquisition of EnergySolutions for roughly $2 billion underscores rising investor appetite for nuclear services and infrastructure as pragmatic exposure to a nuclear revival. ECP, which originally bought the firm in 2013 for about $1.1 billion and sold a majority stake in 2022, frames the move as entering the “early innings” of a growth cycle driven by rising electricity demand from AI, data centers and broader electrification, plus bipartisan U.S. policy and regulatory changes emphasizing energy security.

Investors are favoring lifecycle services—waste management, radioactive transport, decommissioning and operational support—because they avoid the high capital cost, long timelines and construction risk of new‑build reactors.

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EIA Outlook: AI Data Centers Push U.S. Power to Record 2026–27

U.S. electricity demand is projected to hit records in 2026 and 2027, driven by rapid growth in data-center loads from AI and cryptocurrency plus broader electrification of heating and transport. Total retail sales reach about 4,195 billion kWh in 2025, rising to 4,244 in 2026 and 4,381 in 2027. Residential sales are forecast near 1,520 billion kWh in 2026, commercial 1,528 billion kWh, and industrial about 1,053 billion kWh.

The generation mix shifts: renewables climb from roughly 24% in 2025 to 25% in 2026 and 27% in 2027, coal falls from 17% to 15%, natural gas holds about 40% with a slight dip to 39% in 2026, and nuclear remains near 18%. Natural gas sales for power are projected at about 36.1 bcfd in 2026, slightly below a 2024 peak; residential, commercial and industrial gas use remain below their historical highs.

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