Alberta
Alberta solar screening starts with micro-generation class and the full bill.
Direct answer
Alberta micro-generation is sized to the customer's own electricity needs. Systems under 150 kW are small; systems from 150 kW are large. The government page states a 5 MW maximum. Credit treatment and delivery costs differ by class and retailer.
· Province guide
Code-native diagram
Alberta decision path
A generalized province diagram routes load-matched generation through micro-generation class, retailer terms, and delivery charges.
| Step | Evidence question |
|---|---|
| 1 | Customer load |
| 2 | Small or large class |
| 3 | Credit treatment |
| 4 | Full bill |
Conceptual geometry only. The official source basis and verification date are listed in the evidence rail on this page.
Small and large micro-generation receive different credits
The Alberta government defines small micro-generation below 150 kW and large micro-generation at 150 kW or above. Small systems receive retail-rate monthly credits unless the hourly-wholesale option applies. Large systems receive hourly wholesale market pricing.
- OfficialSmall micro-generation is below 150 kW. Large micro-generation starts at 150 kW.Verified 2026-07-17
- OfficialThe current government page states a maximum micro-generation system size of 5 MW.Verified 2026-07-17
Rule 024 controls the application path
A project connects through the distribution company. AUC Rule 024 and the current application guideline govern the process. The screen does not imply approval, available feeder capacity, or a connection timeline.
Use the reviewed municipal resource value
Natural Resources Canada photovoltaic potential varies by location and model basis. Enerwav uses the selected reviewed municipality record as a preliminary yield input and does not describe one province-wide solar yield.
The retail energy rate is not the full avoided bill
The Utilities Consumer Advocate lists Rate of Last Resort examples for residential and small-business consumers and states that billing and delivery costs are excluded. Those figures are not used as a province-wide commercial default.
Transmission, distribution, local-access fees, and riders can respond differently to generation. The customer's current bill and retailer agreement remain the input source.
Reviewed Alberta records show different scales
The project library includes EPCOR's solar-plus-storage work in Edmonton and the Fort Chipewyan Solar Project. Their official records establish selected capacities and operating states, but they do not publish a transferable commercial payback.
Review export, price, and operating exposure
Confirm load matching, export treatment, retailer terms, distribution requirements, curtailment exposure, hourly market value for large systems, roof or land conditions, and project-specific tax treatment.
Start with the customer's own electricity needs
The Alberta government describes micro-generation as renewable or alternative generation sized to meet the customer's own electricity needs. The project team should reconcile annual consumption, expected generation, current operations, planned load changes, and any storage charging. A developer's proposed array size does not by itself establish that the project fits the micro-generation framework.
A screening yield can use the selected reviewed municipality record, but the connection application needs the actual site, equipment, design, and distribution-company process. The owner should retain the load evidence and assumptions used to size the project because a later operational change can alter the relationship between generation and customer need.
The 150 kW boundary changes credit treatment
The current Alberta page defines small micro-generation below 150 kW and large micro-generation at 150 kW or above. Small systems generally receive retail-rate monthly credits unless the hourly-wholesale option applies. Large systems receive hourly wholesale market pricing. The published maximum is 5 MW.
That distinction affects export value and data requirements. A retail-rate monthly credit and an hourly wholesale settlement cannot be represented by one annual electricity price. A large project needs an hourly production and market-value method, while a small project still needs the retailer's actual terms and the customer's bill.
Separate retailer energy from delivery charges
Alberta retail choice does not make the energy rate the full avoided bill. The Utilities Consumer Advocate explains transmission, distribution, local-access fees, rate riders, and other delivery components. Each charge needs its own unit and response to behind-the-meter generation.
The Rate of Last Resort page can orient a named residential or small-business default example, but it excludes billing and delivery costs and should not be used as a large-commercial payback input. A commercial model should use the customer's retailer contract, distributor tariff, riders, fees, and effective dates.
Treat Rule 024 as an application process
The project connects through the distribution company under AUC Rule 024 and the current micro-generation application guidance. The applicant should confirm the required forms, equipment information, single-line diagram, protection, metering, operating limits, approvals, inspections, and agreements for the proposed class and site.
A completed screen does not establish feeder capacity, export permission, technical acceptance, construction schedule, metering configuration, or energization. The utility response can change project size, equipment, cost, schedule, and operating mode. Those changes should flow back into the economic model before a decision.
Use municipal resource data without claiming a province average
Natural Resources Canada publishes photovoltaic-potential information with an explicit model basis and geographic resolution. Enerwav uses the selected reviewed municipality value for preliminary production. It does not describe one Alberta yield, guarantee output, or replace site geometry and engineering.
A study should refine orientation, tilt, shading, snow, soiling, temperature, equipment, losses, clipping, availability, curtailment, and operating constraints. The municipal value is a starting reference. The project team should document every change from that reference and retain the resulting production range.
Use Alberta records as evidence, not benchmarks
The EPCOR and Fort Chipewyan records demonstrate that sourced Alberta solar and storage projects can be described with field-level provenance. Their published capacities, operating states, and project contexts remain tied to their own sources. Missing cost, tariff, dispatch, and realized-savings fields remain unknown.
Those records should not populate a commercial project's payback or equipment design. A municipal or utility project can have funding, operating, load, interconnection, procurement, and community conditions that do not transfer to another site. The useful comparison is the evidence structure and the list of unknowns.
Do not invent an Alberta commercial payback
A commercial worked example would require a project cost, reviewed municipality resource, system and loss assumptions, load coincidence, retailer energy terms, distributor charges, export settlement, operating cost, tax treatment, interconnection scope, and project schedule. The current official sources do not provide that complete site-specific set.
Enerwav therefore leaves the Alberta worked payback suppressed. The owner can use the Explorer with declared inputs and then replace them with account, study, budget, utility, and adviser evidence. The guide states which source controls each question without presenting a default commercial rate.
Close the Alberta decision in a fixed order
Confirm customer need and preliminary size first. Determine small or large class next. Obtain the retailer and distributor evidence that controls import and export value. Review Rule 024 and the distribution-company application. Refine production and load coincidence. Then add project cost, operating cost, and professional tax treatment.
A project remains review required when the class is uncertain, the export value uses the wrong settlement basis, delivery charges are treated as fully avoidable without support, the utility process is incomplete, or a small-business default rate is used for a different commercial account. These are calculation boundaries, not editorial cautions.
Large micro-generation needs hourly export evidence
Large micro-generation receives hourly wholesale market pricing for exported electricity under the current government description. A project screen therefore needs an hourly production profile and the applicable market-price treatment rather than one annual retail rate. The model should also separate energy used behind the meter from energy exported.
A production estimate based on annual photovoltaic potential can support total generation, but it cannot allocate exports by hour. The analyst needs interval load, interval generation, operating limits, curtailment, outages, and settlement data. If those records are unavailable, export value should remain a range or be suppressed.
Review retailer and distributor changes over the project term
Retail contracts, default arrangements, distribution tariffs, riders, local-access fees, and market conditions can change during a long project term. The economic model should state the current source date and show which future changes are user assumptions rather than official forecasts.
A sensitivity case can vary an entered electricity value, but it should not present the result as a guaranteed hedge. The owner should also review termination, renewal, credit, and assignment terms in the retail contract where they affect the project's imported or exported electricity treatment.
The closeout record should name the distributor, retailer, contract expiry, tariff effective date, export settlement method, project class, and next review date. If any of those items changes before procurement, the owner should reopen the value model and interconnection assumptions instead of relying on the earlier screen.
The final Alberta screen should also list the selected municipality resource record, annual-load source, proposed capacity, small or large classification, expected import and export split, application status, delivery-charge treatment, operating-cost source, and tax-review status. These fields give the next reviewer enough context to reproduce the result and identify which assumptions still depend on a future utility or commercial response.
Record unresolved items.