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Canadian Commercial Solar Economics: July 2026 source snapshot

A dated source snapshot covering 14 added Canadian project records, business-rate distinctions in British Columbia, Saskatchewan, and Quebec, and evidence limits.

Owner Published 2026-07-17

Contents

  1. Fourteen added project records and explicit unknown fields
  2. British Columbia, Saskatchewan, and Quebec tariff distinctions
  3. Inputs required before a site result can be tested
  4. Suppressed forecasts, benchmarks, and transferable outcomes
  5. Source appendix verified on 17 July 2026

Snapshot scope

This 17 July 2026 snapshot covers 14 newly added Natural Resources Canada project records and reviewed business-rate evidence for British Columbia, Saskatchewan, and Quebec. It supports early evidence gathering, not an investment decision. The source set does not establish a national installed-cost or payback benchmark, a market forecast, supplier quality, future performance, or a result that can be transferred from one project or account to another.

14 newly added project records

Natural Resources Canada reports that Energy OASIS in Burnaby used 250 kW of solar and 500 kWh of battery energy, with operation described through the reported study period. The Lasqueti record reports 42 kW and 13 kW solar installations with flooded lead-acid batteries, but does not state battery capacities or current operating state. The Field record reports a 1 MW battery that became operational in 2013, while the Nemiah Valley record reports 250 kW of solar and 1 MWh of storage without a current facility state.

Other source-reported capacity records include the 189 kW solar and 334.5 kW / 669 kWh battery system commissioned at Mary's Harbour in 2021, the West 5 project's approximately 2 MW of distributed solar and 0.99 MW / 2 MWh battery, and the Toronto integrated urban microgrid's 3 kW solar and 100 kVA / 125 kWh battery. The automotive-battery demonstration reports a 150 kW system connected for testing but does not state its current operating condition or energy capacity.

Coral Harbour and Naujaat, Sayisi Dene, EQUS, Sky Smart EV Charging, Nemiah Valley, and Gull Bay use an operating-state value of Not stated because their project-page status does not prove facility operation. The A-CAES record describes design and feasibility work rather than an operating full-scale facility. Every record keeps missing capacity, deployment, current availability, and realized financial savings visible as unknown instead of converting them to zero or a positive result.

British Columbia tariff distinctions

BC Hydro's General Service page, effective 1 April 2026, separates small, medium, and large business classes using published peak-demand and annual-energy boundaries. The classes have different daily, demand, and energy structures, so no single British Columbia business rate can stand in for the account. Recheck the current bill and rate schedule for class, billing demand, blocks, riders, taxes, minimums, and power-factor treatment before assigning avoided value.

BC Hydro states that Rate Schedule 2289 starts for new eligible self-generation customers on 1 July 2026 and purchases excess generation at 10 cents/kWh each billing cycle. That amount is dated export context, not the import rate or a calculator default. Existing-account transitions, connection approval, eligible capacity, actual exports, and rebate interactions remain account specific. Recheck the current utility page, bill, and applicable schedule before using the value.

Saskatchewan tariff distinctions

SaskPower's supplied-transformation schedule is effective 1 February 2026 and applies to the stated service configuration and rate class. Its monthly, recorded-demand, and energy components cannot be substituted for customer-owned transformation or another account class. Recheck the current bill and rate schedule for the rate code, transformation ownership, kVA demand, energy blocks, service conditions, surcharges, taxes, and minimum bill before modelling.

SaskPower's net-metering page states a 7.5 cents/kWh credit for eligible excess generation until 31 March 2029. The credit offsets the energy charge and is not a cash payment, full import price, or whole-bill value. The application also requires an interconnection study and can produce project-specific meter, study, and upgrade costs. Recheck the current program page, connection terms, bill, and rate schedule before entering any credit or connection cost.

Quebec tariff distinctions

Hydro-Québec's Rate G and Rate M chart is effective 1 April 2026. Rate G has monthly, demand-above-threshold, and energy-block components, while Rate M combines demand and energy blocks for its applicable account class. The Régie de l'énergie decision supplies regulatory context, not a customer tariff row. Recheck the current bill and rate schedule for classification, billing demand, minimums, power factor, taxes, and blocks before calculating avoided value.

Hydro-Québec directs Rate G and Rate M business customers to its self-generation path. The business customer must own and operate the equipment, while a building owner submits the application for a rented site. Hydro-Québec analyzes the project and issues authorization only after satisfactory verification. This process does not prove suitable capacity, expected exports, savings, or connection cost. Recheck the current self-generation documents, ownership, account rate, metering, connection approval, and surplus treatment for the proposed site.

Information still required

A site screen still needs the current bill and rate schedule, interval electricity data, generation and load profiles, service and meter configuration, site and electrical constraints, target capacity, export and interconnection terms, storage duty, cost evidence, operating costs, procurement structure, and decision dates. Missing inputs remain unknown. Tariff figures in this snapshot are dated page context only, with no silent tariff assumptions or province-wide defaults.

Source and timing limits

The future Q4 2026 research results are not claimed because that quarter has not occurred. Market forecasts are not provided, project performance is not transferable, and this snapshot states no national installed-cost benchmark, national payback benchmark, supplier assessment, or live facility status beyond what each source reports. Readers should reopen every linked official source and verify its effective date, account applicability, and current correction state when making a real decision.

The on-page sections, source appendix, and local Markdown export use the same 14 project records and nine tariff or province source identifiers. The export is generated entirely in the browser after format validation and purpose consent. The address is not transmitted, stored, logged, subscribed, or written into the file, and the exported source list contains no legacy federal, Ontario, or Alberta evidence from the earlier snapshot.

Review all projects on the generalized map.

Source appendix

Full local export

The full July 2026 source snapshot is available as a browser-generated Markdown file. Valid email format and purpose consent unlock it locally; the address is not transmitted, persisted, logged, or included in the file.

Source timing boundary

The planned Q4 2026 economics findings do not yet exist. This July source snapshot uses only evidence verified by 17 July 2026 and does not claim future-quarter results.