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Applications for Power Plants, Substations, Transmission Lines, Industrial System Designations, Hydro Developments and Gas Utility Pipelines
This rule as amended was approved by the Alberta Utilities Commission on March 20, 2024, and is effective on March 28, 2024.
Applicants for new power plant applications (applications that are filed on or after May 2, 2024), including wind, solar, thermal, hydroelectric and other power plants and new energy storage facility applications, will be required to satisfy the existing information requirements in Rule 007: Applications for Power Plants, Substations, Transmission Lines, Industrial System Designations, Hydro Developments and Gas Utility Pipelines, as well as the current interim information requirements.
1. Purpose
2. Application process
2.1 Preparation of an application
2.2 Submission via the eFiling System
2.3 Application deemed complete
3. Application processing timelines
4. Power plants
4.1 Exemptions
4.1.1 Micro-generation
4.1.2 Power plants less than one megawatt
4.1.3 Isolated generating unit
4.2 Checklist applications for new power plants equal to or greater than one megawatt and less than 10 megawatts that are not proposed as micro-generation units under the Micro generation Regulation
4.2.1 Amendment process
4.3 Wind power plant applications
4.3.1 Applications where changes in equipment or layout are anticipated after the approval of the application
4.3.2 Information requirements
4.3.3 Amendment process
4.4 Solar power plant applications
4.4.1 Applications where changes in equipment or layout are anticipated after the approval of the application
4.4.2 Information requirements
4.4.3 Amendment process
4.5 Thermal power plant applications
4.5.1 Applications where changes in equipment are anticipated after the approval of the application
4.5.2 Information requirements
4.5.3 Amendment process
4.6 Other power plant applications
4.6.1 Applications where changes in equipment are anticipated after the approval of the application
4.6.2 Information requirements
4.6.3 Amendment process
4.7 Hydroelectric power plants and hydro developments
4.7.1 Information requirements
4.8 Community generation
4.8.1 Information requirements
4.8.2 Amendment process
5. Time extension applications for power plants
5.1 Information requirements
6. Decommission and salvage or cancellation of power plants
7. Transmission lines, substations and other transmission facilities
7.1 Needs identification document applications to construct or alter a substation or transmission line
7.1.1 Needs identification document application information requirements
7.1.2 Abbreviated needs identification document application information requirements
7.2 Transmission line, substation and other transmission facility applications
7.2.1 Information requirements
7.2.2 Amendment process
8. Time extension applications for transmission facilities
9. Decommission and salvage or cancellation for transmission facilities
9.1 Decommission and salvage information requirements
9.2 Cancellation information requirements
10. Energy storage facilities
10.1 Energy storage facility as part of an electric distribution system
10.2 Exemption
10.3 Energy storage facility information requirements
10.4 Amendment process for energy storage facilities
10.5 Decommission and salvage of energy storage facilities
10.6 Cancellation of energy storage facilities
10.7 Time extension applications for energy storage facilities
11. Interconnection applications
11.1 Information requirements
11.1.1 Connection to the distribution system
11.1.2 Connection to the transmission system
12. Industrial system designation applications
12.1 Information requirements
13. Gas utility pipelines
13.1 Exemptions
13.2 Certain pipeline installations
13.2.1 Certain pipelines and activities
13.3 Project need
13.3.1 Need assessment information requirements
13.3.2 Abbreviated need
13.3.3 Abbreviated need information requirements
13.4 Gas utility pipeline applications
13.4.1 Information requirements
13.5 Amendments
13.5.1 Amendment process
13.5.2 Checklist amendment application
13.5.3 Amendment application
13.5.4 Information requirements
13.6 Time extension applications for gas utility pipelines
13.7 Operational requirements
13.7.1 Pipeline flaring, incinerating and venting
13.7.2 Venting and fugitive emissions management requirements
13.7.3 Records of pipeline flaring, incinerating and venting
13.8 Storage requirements
14. Approval transfer applications
14.1 Information requirements
14.1.1 Electric facility approval transfer
14.1.2 Gas utility pipeline approval transfer
15. Abbreviations
16. Glossary
Appendix A1 – Participant involvement program guidelines
Appendix A1-B – Participant involvement program guidelines for Indigenous groups
Appendix A2 – Independent System Operator (ISO) participant involvement program guidelines
Appendix B1 – Economic comparison format – requirement ISD9
This rule applies to applications for the construction, alteration, operation and connection of power plants, hydro developments, substations, transmission lines, energy storage facilities and industrial system designations, pursuant to the Hydro and Electric Energy Act, and for approval of a needs identification document, pursuant to the Electric Utilities Act and the Transmission Regulation.
This rule also applies to applications for the construction, operation or modification of gas utility pipelines or pipeline installations, pursuant to the Pipeline Act and the Gas Utilities Act.
Any person intending to construct, alter, operate, or connect, power plants, hydro developments, substations, transmission lines, energy storage facilities or industrial system designations, including ownership changes and construction or alteration time extensions, or construct, operate or modify a gas utility pipelines or pipeline installations must file an application with the Alberta Utilities Commission in accordance with this rule.
This rule groups information requirements together for each specific application type. For example, an applicant for a wind power plant can find all the relevant information requirements in subsection 4.3, while an applicant for a time extension related to a power plant can find all the relevant information requirements in Section 5.
This rule also contains appendixes that an applicant must be familiar with before submitting an application.
If you are accessing this rule online, it contains hyperlinks to reference other sections and definitions of certain words and phrases.
Text boxes that contain supplemental information to meet the rule requirements are found throughout this rule.
The following section describes the application process. It provides guidance for preparation of an application, an overview of the eFiling System and the AUC’s process for deeming an application complete.
Prior to filing an application, an applicant must follow the participant involvement program guidelines set out in Appendix A1 – Participant involvement program guidelines, Appendix A1-B – Participant involvement program guidelines for Indigenous groups and/or Appendix A2 – ISO participant involvement program guidelines. An applicant must include documentation describing its notification and consultation program in its application.
An applicant must file its application electronically using the AUC’s eFiling System. The eFiling System is accessible via the AUC website at act-www.auc.ab.ca.
All applicants must request a new proceeding and add applications electronically. Applications include application forms that the applicant completes using the eFiling System, together with attachments that the applicant uploads to the eFiling System. An application form must be created for each separate facility within a project before the proceeding can be registered.
Applicants can find the application forms hyperlinked in the respective information requirement sections of this rule. The forms are also listed on the Rule 007 Related information page on the AUC website.
After all the application forms and attachments have been uploaded to the eFiling System the proceeding can then be registered.
All documents filed in respect of a proceeding, including any application submissions and any documents received prior to the commencement of the proceeding, will be placed on the public record, unless the Commission directs otherwise.
Instructions on how to use the eFiling System, including: request a new proceeding, submit an application, and upload documents, can be found in the eFiling System User Guide. Questions and issues on the use of the eFiling System should be directed to the filing services support staff at 403‑592‑4500 or by email to info@auc.ab.ca.
The Commission reviews all applications to ensure regulatory compliance and completeness.
The Commission will not process an application that contains major deficiencies.
If the application contains major deficiencies, it will be closed and the applicant will receive an explanation via the eFiling System. An example of a major deficiency is the omission of key information, such as neglecting to include a renewable energy referral report from Alberta Environment and Protected Areas (AEPA) for a wind or solar power plant application, participant involvement information or a noise impact assessment when applying to build a power plant in proximity to residences.
If the application has minor deficiencies, or where clarification of information provided in the application is required, the Commission may request further information from the applicant. Failure to respond in the stated time frame may result in the Commission closing the application with written notification of the reason for the rejection.
The Commission will issue an application complete letter in a proceeding when it has deemed an application to be complete.
The AUC has established performance standards and timelines for processing facility applications. There are five categories of facility applications based on process requirements that are driven by the complexity of an application. Descriptions of the application categories and the corresponding processing timelines are set out in Table 3.1.
Table 3.1: Performance standards for facility applications
* This is the only performance standard based on business days; all other performance standards are based on calendar days.
The performance standards for record development are premised on the process steps necessary to ensure a complete application and a sufficient evidentiary record to allow the Commission to decide whether approval of an application is in the public interest. Those process steps are summarized in Table 3.2.
Table 3.2: Record development steps
The record development timelines are based on the receipt of applications that are complete or substantially complete. The timelines do not take into account process steps that are in addition to those outlined in Table 3.2 (such as technical meetings, negotiated settlements, supplemental information requests and motions for various matters), which could extend the overall timeline.
The Commission will assign new applications to one of the five category types listed above and will advise applicants of the application category in an application response letter that is issued in the proceeding. The Commission may revise the assigned category if more process steps are required to consider the application.
As described throughout this rule, the Commission allows checklist applications to be submitted in certain instances. The Commission will assess the eligibility for an application to be filed as a checklist application and will issue a decision within five business days of receiving a properly completed checklist application.
Power plant applications are made pursuant to Section 11 of the Hydro and Electric Energy Act. This section provides information on power plant exemptions and situations where an application may not be required. It sets out the checklist application process for new power plants that are equal to or greater than one MW and less than 10 MW and then sets out information requirements for power plants 10 MW or greater, by type of power plant, specifically:
If a power plant has an associated substation (for example a collector substation or step-up transformer), the applicant must choose whether the substation is considered:
If there is duplication between the requirements for a power plant application and an associated substation or connection order (for example, if one participant involvement program was completed for the project and each application requires a summary of the participant involvement program), the applicant must satisfy the requirements in full in one of the applications, and may refer to that application in the other application(s).
If a separate substation or connection order is also part of the project, a separate application form should be added for each component prior to registering the proceeding.
Applicants for new power plant applications (applications that are filed on or after May 2, 2024), including wind, solar, thermal, hydroelectric and other power plants and new energy storage facility applications, will be required to satisfy the existing information requirements in Rule 007, as well as the current interim information requirements.
The following section lists power plants that may not require an AUC application or approval. If no exemptions for power plants are applicable, the owner must file a power plant checklist application or a power plant application containing all the information required by this rule and Rule 012: Noise Control.
Even if an owner of a power plant is exempt from filing an application under this rule, the Commission retains the jurisdiction to investigate issues in relation to compliance with this rule and Rule 012, and to confirm that the requirements for exemption are satisfied and continue to be satisfied.
If a customer, within the meaning of Rule 024: Rules Respecting Micro‑Generation, is proposing a micro-generation generating unit, the customer must refer to Rule 024 to determine whether the proposed micro-generation generating unit (power plant) meets the requirements for an exemption or an application is required under this rule.
If the power plant is less than one MW, the owner may proceed without filing an application if the requirements of subsection 3(3) of the Hydro and Electric Energy Regulation are met.
If the power plant is an isolated generating unit with a total capability of less than 10MW, the owner may proceed without filing an application if the requirements of subsection 4(3) of the Hydro and Electric Energy Regulation are met.
An applicant must file a checklist application using the checklist form if the power plant:
The checklist form contains questions reflecting the location, capability and type of power plant and confirmation that all of the regulatory requirements for the project have been met. If the project is a wind or solar power plant, the applicant must submit a signed renewable energy referral report from Alberta Environment and Protected Areas (AEPA) Fish and Wildlife Stewardship. Applicants are not required to file any other related supporting documents (e.g., participant involvement program summaries, noise impact assessment); however, applicants are required to retain all related supporting documents. The Commission will continue to ensure compliance with its requirements via an audit review process.
The Commission will assess eligibility for an application to be filed as a checklist application and will issue a decision within five business days of receiving a properly completed checklist application. Applicants may be asked to file supplemental information for applications that are not eligible to be filed as checklist applications.
Please use the Power plant checklist application form to assemble the information requirements for a checklist application.
An application to construct and operate a power plant that is 10 MW or greater is not eligible for the checklist application process and must include the requirements corresponding to the power plant type (e.g., wind, solar, thermal).
If amendments are required to a power plant that was approved under the checklist application process, the applicant must follow the amendment process filing requirements corresponding to the power plant type (e.g., wind, solar, thermal), as set out below.
An application to construct and operate a wind power plant must include the information requirements listed in subsection 4.3.2.
Wind turbine technology continues to advance rapidly, often in less time than it takes for a project to progress through the development, permitting and pre‑construction cycle. To provide applicants with flexibility to accommodate technology selection after a project is approved, the requirements for a wind power plant include allowances that must be finalized in a project update.
An applicant submits one of the following types of applications to construct and operate a wind power plant:
If an applicant is filing for a project where no changes are anticipated after the approval of the application, and the applicant has identified specific equipment, including type and model, and proposed a specific layout for the project, the applicant must submit its application in accordance with the information requirements set out in subsection 4.3.2.
If an applicant is filing for a project where changes in equipment or layout are anticipated after the approval of the application, the applicant must submit its application in accordance with the information requirements set out in subsection 4.3.2. An applicant must submit a final project update to the Commission at least 90 days prior to the start of construction, in accordance with the requirements set out in subsection 4.3.3.
Please use the Wind power plant application form to assemble the information requirements for the project. Wind power plant is abbreviated as WP below. Project description
WP1) State the approvals that are being applied for from the AUC and describe the power plant and collector system, including the number of wind-powered generators (or turbines) and their make, model, the nominal capability of each wind-powered generator in MW and the total capability of the power plant in MW. If the vendors have not been selected or the equipment has not been finalized, provide:
WP2) Provide a list of existing approvals for facilities directly affected by this project, if any.
WP3) Provide details of the project ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
WP4) For a municipality or a subsidiary of a municipality to hold an interest in a generating unit, provide documentation confirming compliance with Section 95 of the Electric Utilities Act.
WP5) Describe the location of the project:
WP6) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
WP7) Provide the requested approval date from the Commission, the expected construction date, the expected in-service date for the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
Project connection
WP8) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
WP9) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO Project ID number related to your system access service request, if available.
WP10) If the power plant is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the power plant to the Alberta Interconnected Electric System.
If the power plant is to be connected to the distribution system, provide a statement from the distribution facility owner indicating that it is willing to connect the generating facilities.
Emergency response plan
WP11) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed power plant. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
WP12) Provide a summary of the following:
WP13) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
Shadow flicker assessment
WP14) Submit a shadow flicker assessment report that predicts the extent of shadow flicker at receptors within 1.5 kilometres from the centre point of each turbine where the potential for shadow flicker is possible. The assessment report must:
Environmental information
WP15) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
WP16) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007, Rule 012 and Rule 033: Post-approval Monitoring Requirements for Wind and Solar Power Plants and describe the steps taken, if any, to address specific requirements set out in these rules.
WP17) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
End-of-life management
WP18) Submit a copy of the initial renewable energy operations conservation and reclamation plan (REO C&R Plan) as set out in the Conservation and Reclamation Directive for Renewable Energy Operations.
WP19) Provide an overview of how the operator will ensure sufficient funds are available at the project end of life to cover the cost of decommissioning and reclamation.
Noise
WP20) Provide a noise impact assessment in accordance with Rule 012.
Approvals, reports and assessments from other agencies
WP21) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act, Highway Development and Protection Act and Wildlife Act)that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
WP22) Submit a signed renewable energy referral report from Alberta Environment and Protected Areas (AEPA) Fish and Wildlife Stewardship. If the applicant is unable to provide a renewable energy referral report at time of application, the applicant must clearly identify the reason and provide details of its status.
WP23) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment isrequired, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
WP24) If the government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
Participant involvement program
WP25) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided (see Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups.)
WP26) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups, owners of aerodromes or other interested persons that were consulted as part of the participant involvement program.
Table 4.1: Notification radius for wind power plants
WP27) Supply a list of contact information for all persons who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
WP28) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
WP29) Summarize consultation with Environment and Climate Change Canada regarding potential interference with nearby weather radars. If Environment and Climate Change Canada has identified the potential for significant interference with a weather radar, provide a copy of a mitigation agreement to be concluded with Environment and Climate Change Canada prior to the operation of the power plant.
WP30) Summarize consultation with Alberta First Responder Radio System, identify potential interference with other radar/radio frequency towers and provide mitigation measures agreed upon.
WP31) Identify all persons who expressed a concern(s) about the project. For each person include the following information:
Community generation
If the project is a proposed community generation project, the applicant must also submit the information specified in subsection 4.8.
This section outlines the process for projects that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can make one of the following three types of submissions to amend its wind power plant approval: final project update, letter of enquiry, or amendment application.
Descriptions of eligibility for each of the submission types are described in the following sections.
Final project update
If an applicant has applied for a project where changes in equipment or layout are anticipated after the application has been approved, a final project update must be submitted to the Commission at least 90 days prior to the start of construction. The allowances and requirements for a final project update are outlined below.
For wind power projects where the applicant is able to confirm that the project has stayed within the outlined allowances, an applicant is only required to submit a final project update on the record of the original proceeding. The AUC will review the update to confirm that the project has stayed within the allowances.
Please use the corresponding Wind power plant final project update requirements form to assemble the information required for the final project update.
If project amendments as described in the final project update are not within the outlined allowances, an applicant must submit either a letter of enquiry or an amendment application to the AUC.
Table 4.2: Final project update requirements for wind power plants
Provide table of predicted noise levels (to one decimal point) from finalized project receptors.
Confirm that the project continues to meet permissible sound levels at the most affected receptors (as determined under Rule 012).
Provide any new or additional noise mitigation measures implemented to ensure that permissible sound levels will be met.
Confirm that there are no unresolved objections to the project arising from the final project update.
Changes to the layout of access roads, collector lines and crane paths can be made within the approved project boundary as long as an experienced wildlife biologist has confirmed that these changes do not infringe on any wildlife habitat or any wildlife features, or alter any mitigation commitments.
Confirm that the location of each turbine and collector substation has not been relocated more than 100 metres from the approved location.
If changes are made to the layout of access roads, collector lines and crane paths, provide confirmation from an experienced wildlife biologist that these changes do not infringe on any wildlife habitat or any wildlife features, or alter any mitigation commitments. Confirm that the changes all occur within the approved project boundary.
Letter of enquiry
If an applicant is making minor alterations to an existing or approved but not yet constructed wind power plant that exceed the final project update allowances set out in Table 4.2, the applicant may submit a letter of enquiry. In the letter of enquiry, the applicant must provide information respecting the need, nature, extent, land affected and the timing of the alterations. The applicant must demonstrate that the proposed alterations do not have any adverse impacts on the environment or any person.
Amendment application
If an applicant is making changes to an existing or approved but not yet constructed wind power plant that exceed the final project update allowances outlined in Table 4.2. and do not meet the criteria for a letter of enquiry, the applicant must file an amendment application that provides all applicable information required within subsection 4.3.2.
An application to construct and operate a solar power plant, must include the information requirements listed in subsection 4.4.2.
Solar technology continues to advance rapidly, often in less time than it takes for a project to progress through the development, permitting and pre-construction cycle. To provide applicants with flexibility to accommodate technology selection after a project is approved, the requirements for a solar power plant include allowances that must be finalized in a project update.
An applicant submits one of the following types of applications to construct and operate a solar power plant:
If an applicant is filing for a project where no changes are anticipated after the approval of the application, and the applicant has identified specific equipment, including type and model, and proposed a specific layout for the project, the applicant must submit its application in accordance with the information requirements set out in subsection 4.4.2.
If an applicant is filing for a project where changes in equipment or layout are anticipated after the approval of the application, the applicant must submit its application in accordance with the information requirements set out in subsection 4.4.2. If an applicant must submit a final project update to the Commission at least 90 days prior to the start of construction, in accordance with the requirements set out in subsection 4.4.3.
Please use the Solar power plant application form to assemble the information required for the project. Solar power plant is abbreviated as SP below.
Project description
SP1) State the approvals that are being applied for from the AUC and describe the power plant and collector system, including the number of solar photovoltaic panels and their make, model and the nominal capability of each solar photovoltaic panel in MW and the total capability of the power plant in MW. If the vendors have not been selected or the equipment has not been finalized, provide:
SP2) Provide a list of existing approvals for facilities directly affected by this project, if any.
SP3) Provide details of the project ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
SP4) For a municipality or a subsidiary of a municipality to hold an interest in a generating unit, provide documentation confirming compliance with Section 95 of the Electric Utilities Act.
SP5) Describe the location of the project:
SP6) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
SP7) Provide the requested approval date from the Commission, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
SP8) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
SP9) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO Project ID number related to your system access service request, if available.
SP10) If the power plant is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the power plant to the Alberta Interconnected Electric System.
SP11) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed power plant. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
SP12) Provide a summary of the following:
SP13) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
Solar glare assessment
SP14) Submit a solar glare assessment report that predicts the solar glare at receptors within 800 metres from the boundary of the project and registered aerodromes and known unregistered aerodromes within 4,000 metres from the boundary of the project where the potential for glare is possible. The assessment report must:
Include a table that provides the expected intensity of the solar glare (e.g., green, yellow or red) and the expected duration of solar glare at each identified receptor, critical points along highways, major roadways and railways and any registered and known unregistered aerodromes.
Environmental information
SP15) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
SP16) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007, Rule 012 and Rule 033 and describe the steps taken, if any, to address specific requirements set out in these rules.
SP17) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
SP18) Submit a copy of the initial renewable energy operations conservation and reclamation plan (REO C&R Plan) as set out in the Conservation and Reclamation Directive for Renewable Energy Operations.
SP19) Provide an overview of how the operator will ensure sufficient funds are available at the project end of life to cover the cost of decommissioning and reclamation.
SP20) Provide a noise impact assessment in accordance with Rule 012.
SP21) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
SP22) Submit a signed renewable energy referral report from Alberta Environment and Protected Areas (AEPA) Fish and Wildlife Stewardship. If the applicant is unable to provide a renewable energy referral report at time of application, the applicant must clearly identify the reason and provide details of its status.
SP23) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
SP24) If the government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
SP25) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups.)
SP26) Confirm that, if applicable, Alberta Transportation, the municipality in which the project is located, the applicable railway companies, and the owner of any registered and known unregistered aerodrome within 4,000 metres of the project boundary were consulted and provide a summary of any objections received, mitigations discussed, and any outstanding objections.
SP27) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups, owners of aerodromes or other interested persons that were consulted as part of the participant involvement program.
Table 4.3: Notification radius for solar power plants
SP28) Supply a list of contact information for all person(s) who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
SP29) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
SP30) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
This section outlines the process for projects that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can make one of the following three types of submissions to amend its solar power plant approval: final project update, letter of enquiry, or amendment application.
For solar power projects where the applicant is able to confirm that the project has stayed within the outlined allowances, an applicant is only required to submit a final project update on the record of the original proceeding. The AUC will only review the update to confirm that the project has stayed within the allowances.
Please use the Solar power plant final project update requirements form to assemble the information required for the final project update.
Table 4.4: Final project update requirements for solar power plants
Provide table of predicted noise levels (to one decimal point) from finalized project at receptors.
Confirm that the project continues to meet permissible sound levels at the most affected
receptors (as determined under Rule 012).
Confirm that the location of the solar array and collector substation(s) has not been relocated more than 100 metres from the approved location.
If changes are made to the layout of access roads and collector lines, provide confirmation from an experienced wildlife biologist that the changes do not infringe on any wildlife habitat or any wildlife features, or alter any mitigation commitments. Confirm that the changes all occur within the approved project boundary.
If an applicant is making minor alterations to an existing or approved but not yet constructed solar power plant that exceed the final project update allowances set out in Table 4.4, the applicant may submit a letter of enquiry. In the letter of enquiry, the applicant must provide information respecting the need, nature, extent, land affected and the timing of the alterations. The applicant must demonstrate that the proposed alterations do not have any adverse impacts on the environment or any person.
If an applicant is making changes to an existing or approved but not yet constructed solar power plant that exceed the final project update allowances outlined in Table 4.4 and do not meet the criteria for a letter of enquiry, the applicant must file a complete amendment application that provides all applicable information required within subsection 4.3.2.
An application to construct and operate a thermal power plant must include the information requirements listed in subsection 4.5.2.
To provide applicants with flexibility to accommodate technology selection after a project is approved, the requirements for a thermal power plant include allowances that must be finalized in a project update.
An applicant submits one of the following types of applications to construct and operate a thermal power plant:
If an applicant is filing for a project where no changes are anticipated after the approval of the application, and the applicant has identified specific equipment, including type and model, and proposed a specific layout for the project, the applicant must submit its application in accordance with the information requirements set out in subsection 4.5.2.
If an applicant is filing for a project where changes in equipment or layout are anticipated after the approval of the application, the applicant must submit its application in accordance with the information requirements set out in subsection 4.5.2. An applicant must submit a final project update to the Commission at least 90 days prior to the start of construction, in accordance with the requirements set out in subsection 4.5.3.
Please use the Thermal power plant application form to assemble the information requirements for the project. Thermal power plant is abbreviated as TP below.
TP1) State the approvals that are being applied for from the AUC and describe the power plant, including the number of generating units and their make, model and the nominal capability of each generating unit in MW. If the vendors have not been selected or the equipment has not been finalized, provide:
TP2) Provide a list of existing approvals for facilities directly affected by this project, if any.
TP3) Provide details of the project ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
TP4) For a municipality or a subsidiary of a municipality to hold an interest in a generating unit, documentation confirming compliance with Section 95 of the Electric Utilities Act is required.
TP5) Describe the location of the project:
TP6) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
TP7) Present the estimated power plant heat rates, efficiency of the power plant and details of the cooling system for the power plant.
TP8) For power plants with natural gas piping located within the power plant site boundary, provide the following information:
TP9) Provide the requested approval date from the Commission, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
TP10) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
TP11) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO Project ID number related to your system access service request, if available.
TP12) If the power plant is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the power plant to the Alberta Interconnected Electric System.
TP13) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed power plant. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
TP14) Provide a summary of the following:
TP15) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
TP16) Identify the current emissions standards or guidelines that are applicable to the proposed project. Submit a table that provides the plant’s emission rates (e.g., kg/MWh) for nitrogen oxides (NOx), sulphur dioxide (SO2), and primary particulate matter. The table must compare the emission rates to the current Alberta Air Emissions Standards for Electricity Generation and any other emission standards or guidelines that are applicable to the proposed project.
TP17) Indicate whether the proposed plant will be in compliance with the Alberta air quality standards or guidelines (e.g., Ambient Air Quality Objectives and Guidelines Summary) applicable to the proposed project for ground-level concentrations of pollutants. Identify all standards and guidelines that apply.
TP18) Provide a summary of any feedback received to date from AEPA addressing the environmental aspects of the project and any mitigation measures and monitoring activities recommended by AEPA.
TP19) Provide a copy of the emissions modelling report that was prepared for the Environmental Protection and Enhancement Act application to AEPA.
TP20) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
TP21) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007 and Rule 012 and describe the steps taken, if any, to address specific requirements set out in these rules.
TP22) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
TP23) Provide an overview of how the operator will ensure sufficient funds are available at the project end of life to cover the cost of decommissioning and reclamation.
TP24) Provide a noise impact assessment in accordance with Rule 012.
TP25) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
TP26) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
TP27) If the Government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the Government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the Government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
TP28) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
TP29) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups or other interested person(s) that were consulted as part of the participant involvement program.
Table 4.5: Notification radius for thermal power plants
TP30) Supply a list of contact information for all persons who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
TP31) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
TP32) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
This section outlines the process for projects that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can make one of the following three types of submissions to amend its thermal power plant approval: final project update, letter of enquiry, or amendment application.
If an applicant has applied for a project where changes in equipment are anticipated after the application has been approved, a final project update must be submitted to the Commission at least 90 days prior to the start of construction. The allowances and requirements for a final project update are outlined below.
For thermal power projects where the applicant is able to confirm that the project has stayed within the outlined allowances, an applicant is only required to submit a final project update on the record of the original proceeding. The AUC will review the update to confirm that the project has stayed within the allowances.
Please use the Thermal power plant final project update form to assemble the information required for the final project update.
Table 4.6: Final project update for thermal power plants
If an applicant is making minor alterations to an existing or approved but not yet constructed thermal power plant that exceed the final project update allowances set out in Table 4.6, the applicant may submit a letter of enquiry. In the letter of enquiry, the applicant must provide information respecting the need, nature, extent, land affected and the timing of the alterations. The applicant must demonstrate that the proposed alterations do not have any adverse impacts on the environment or any person.
If an applicant is making changes to an existing or approved but not yet constructed thermal power plant that exceed the final project update allowances outlined in Table 4.6 and do not meet the criteria for a letter of enquiry, the applicant must file a complete amendment application that provides all applicable information required within subsection 4.5.2.
An application to construct and operate a power plant must include the information requirements in subsection 4.6.2.
To provide applicants with flexibility to accommodate technology selection after a project is approved, the requirements for a power plant include allowances that must be finalized in a project update.
An applicant submits one of the following types of applications to construct and operate a power plant:
If an applicant is filing for a project where no changes are anticipated after the approval of the application, and the applicant has identified specific equipment, including type and model, and proposed a specific layout for the project, the applicant must submit its application in accordance with the information requirements set out in subsection 4.6.2, as appropriate for the specifications of the generation type.
If an applicant is filing for a project where changes in equipment or layout are anticipated after the approval of the application, the applicant must submit its application in accordance with the information requirements set out in subsection 4.6.2. An applicant must submit a final project update to the Commission at least 90 days prior to the start of construction, in accordance with the requirements set out in subsection 4.6.3.
Please use the Other power plant applications form to assemble the information requirements for the project.
Other power plant is abbreviated as OP below.
OP1) State the approvals that are being applied for from the AUC and describe the power plant, including the number of generating units and their make, model and the nominal capability of each generating unit in MW. If the vendors have not been selected or the equipment has not been finalized, provide:
OP2) Provide a list of existing approvals for facilities directly affected by this project, if any.
OP3) Provide details of the project ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
OP4) For a municipality or a subsidiary of a municipality to hold an interest in a generating unit, documentation confirming compliance with Section 95 of the Electric Utilities Act is required.
OP5) Describe the location of the project:
OP6) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
OP7) Present the estimated power plant heat rates, efficiency of the power plant and details of the cooling system for the power plant.
OP8) For power plants with natural gas piping located within the power plant site, provide the following information:
OP9) Provide the requested approval date from the Commission, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
OP10) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
OP11) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO project ID number related to your system access service request, if available.
OP12) If the power plant is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the power plant to the Alberta Interconnected Electric System.
OP13) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed power plant. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
OP14) Provide a summary of the following:
OP15) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
OP16) Identify any current emissions standards or guidelines that are applicable to the proposed project. Submit a table that provides the plant’s emission rates (e.g., kg/MWh) for nitrogen oxides (NOx), sulphur dioxide (SO2), and primary particulate matter. The table must compare the emission rates to the current Alberta Air Emissions Standards for Electricity Generation and any other emission standards or guidelines that are applicable to the proposed project.
OP17) Indicate, if applicable, whether the proposed plant will be in compliance with the Alberta air quality standards or guidelines (e.g., Ambient Air Quality Objectives and Guidelines) applicable to the proposed project for ground-level concentrations of pollutants. Identify all standards and guidelines that apply.
OP18) Provide a summary of feedback received to date from AEPA addressing the environmental aspects of the project and any mitigation measures and monitoring activities recommended by AEPA.
OP19) Provide a copy of the emissions modelling report that was prepared for the Environmental Protection and Enhancement Act application to AEPA, if applicable.
OP20) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
OP21) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The proponent must address how it has considered AUC Rule 007 and Rule 012 and describe the steps taken, if any, to address specific requirements set out in these rules.
OP22) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
OP23) Provide an overview of how the operator will ensure sufficient funds are available at the project end of life to cover the cost of decommissioning and reclamation.
OP24) Provide a noise impact assessment in accordance with Rule 012.
OP25) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
OP26) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
OP27) If the Government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the Government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the Government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
OP28) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
OP29) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups or other interested person(s) that were consulted as part of the participant involvement program.
Table 4.7: Notification radius for other power plants
OP30) Supply a list of contact information for all persons who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
OP31) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
OP32) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
This section outlines the process for projects that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can make one of the following three types of submissions to amend its power plant approval: final project update, letter of enquiry, or amendment application.
If an applicant has applied for a project where changes in equipment are anticipated after the approval of the application, a final project update must be submitted to the Commission at least 90 days prior to the start of construction. The allowances and requirements for a final project update are outlined below.
For power projects where the applicant is able to confirm that the project has stayed within the outlined allowances, an applicant is only required to submit a final project update on the record of the original proceeding. The Commission will review the update to confirm that the project has stayed within the allowances.
Please use the Other power plant final project update requirements form to assemble the information required for the final project update.
Table 4.8: Final project update requirements for other power plants
If an applicant is making minor alterations to an existing or approved but not yet constructed power plant that exceed the final project update allowances set out in Table 4.8, the applicant may submit a letter of enquiry. In the letter of enquiry, the applicant must provide information respecting the need, nature, extent, land affected and the timing of the alterations. The applicant must demonstrate that the proposed alterations do not have any adverse impacts on the environment or any person.
If an applicant is making changes to an existing or approved but not yet constructed power plant that exceed the final project update allowances outlined in Table 4.8 and do not meet the criteria for a letter of enquiry, the applicant must file a complete amendment application that provides all applicable information required within subsection 4.6.2.
An application to construct or alter a hydroelectric power plant and an associated hydro development must contain all of the following information requirements.
Hydro development applications are made pursuant to sections 9 and 10 of the Hydro and Electric Energy Act.
Power plant applications are made pursuant to Section 11 of the Hydro and Electric Energy Act.
Please use the Hydroelectric power plant and hydro development application form to assemble the information requirements for the project. Hydroelectric power plant is abbreviated as HE below.
HE1) State the approvals that are being applied for from the AUC. Describe the power plant including the number of generating units and their make, model and the nominal capability of each generating unit in MW, and the hydro development, including technical and engineering details.
HE2) Provide a list of existing approvals for facilities directly affected by this project, if any.
HE3) Provide details of the ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
HE4) For a municipality or a subsidiary of a municipality to hold an interest in a generating unit, provide documentation confirming compliance with Section 95 of the Electric Utilities Act.
HE5) Describe the location of the project:
HE6) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
HE7) Provide the requested approval date from the Commission, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
HE8) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
HE9) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO Project ID number related to your system access service request, if available.
HE10) If the proposed hydro development is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the proposed hydro development to the Alberta Interconnected Electric System.
If the proposed hydro development is to be connected to the distribution system, provide a statement from the distribution facility owner indicating that it is willing to connect the generating facilities.
HE11) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed hydro development. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
HE12) Provide a summary of the following:
HE13) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
HE14) Provide a summary of feedback received to date from Alberta Environment and Parks (AEPA) addressing the environmental aspects of the project and any mitigation measures and monitoring activities recommended by AEPA.
HE15) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
HE16) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
HE17) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007 and Rule 012 and describe the steps taken, if any, to address specific requirements set out in these rules.
HE18) Provide an overview of how the operator will ensure sufficient funds are available at the project end of life to cover the cost of decommissioning and reclamation.
HE19) Provide a noise impact assessment in accordance with Rule 012.
HE20) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may affect the project, identify approvals the project may require, and provide the status of each of these approvals.
HE21) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
HE22) If the Government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the Government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the Government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
HE23) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups.)
HE24) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups, non-governmental organizations or other interested persons that were consulted as part of the participant involvement program.
Table 4.9: Notification radius for hydroelectric power plants
HE25) Supply a list of contact information for all person(s) who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
HE26) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
HE27) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
If the project is a proposed community generation project, the applicant must also submit the information specified in subsection 4.8.
If an applicant is applying to have a small-scale generating unit qualified as a community generating unit, or to report changes to an existing community generating unit, the application must include the information outlined below.
Community generation applications are made pursuant to the Small Scale Generation Regulation. To be eligible to be qualified as a community generating unit, a generating unit must first be qualified as a small-scale generating unit by the distribution facility owner for the service area in which the generating unit is located.
These information requirements do not apply to changes to a small-scale generating unit unless the changes may make the community generating unit cease to be a community generating unit, as outlined in Section 10 of the Small Scale Generation Regulation.
Please use the Community generating unit application form to assemble the information requirements for the project. Community generating unit is abbreviated as CG below.
CG1) Describe the generating unit(s) including quantity, make, model and the Total capability in MW.
CG2) Describe the location of the generating unit(s).
CG3) Confirm if the generating unit requires an AUC power plant approval.
CG4) Confirm if the generating unit is currently in service and if so, provide the in-service date. If the generating unit is not in service, provide the estimated in-service date. If the generating unit has not been constructed, provide the estimated construction start date.
Eligibility
CG5) Confirm that the generating unit qualifies as a small-scale generating unit under the Small Scale Generation Regulation; include documentation from the distribution facility owner confirming that qualification.
CG6) Describe how the community group associated with the generating unit satisfies the definition of community group in subsection 1(e) of the Small Scale Generation Regulation.
CG7) Provide the community benefits agreement or community benefits statement associated with the generating units, as defined in subsections 1(b) and 1(c) of the Small Scale Generation Regulation. Clearly describe the benefits received by the community group under the community benefits agreement or community benefits statement. Indicate the category or categories each benefit falls within (i.e., social, environmental or economic).
CG8) Provide details of the ownership structure of the generating unit, including the names of all entities having an ownership interest in the generating unit and their ownership share. Confirm if the generating unit is wholly owned by the community group identified in the community benefits statement or community benefits agreement.
CG9) Provide a detailed breakdown of costs for the meter equipment associated with the generating unit, excluding any related installation or commissioning costs. If the meter equipment has not been procured, provide an estimate of costs that will be incurred for the meter equipment, excluding any related installation or commissioning costs.
Notice of any changes that may cause a qualified community generating unit to cease being a community generating unit, including changes described in subsection 10(1) of the Small Scale Generation Regulation, should be filed as a letter of enquiry application through the eFiling System.
This section outlines the requirements for applications for a time extension to complete the construction or alteration of a power plant or hydro development. Time extensions may be granted at the discretion of the Commission.
An application for a time extension for a power plant or hydro development must include the information outlined below.
Applications for a time extension to complete the construction or alteration of a power plant or hydro development are made pursuant to Section 19 of the Hydro and Electric Energy Act.
Please use the Time extension application for power plants form to assemble the information requirements for the project. Time extension application for power plants is abbreviated as TEP below.
TEP1) Provide a list of the existing approvals for facilities affected.
TEP2) Explain whether construction of the approved power plant and other associated facilities has commenced. If it has not yet commenced, explain whether it will commence prior to the expiry date of the existing approval. Explain why the construction or alteration completion date will not be met, why the time extension is required and provide an updated project schedule, including the expected construction start date, the expected in-service date for the project and the requested construction completion date to be used in the project approval.
TEP3) Provide a new noise impact assessment, as required under subsection 1.5 of Rule 012 if one or more of the following conditions is satisfied:
TEP4) Confirm that the participant involvement program meets the requirements contained in Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups. Describe any concerns specific to the time extension request, raised by directly and adversely affected persons and how the concerns were dealt with or will be dealt with.
TEP5) Supply a list of contact information for all persons who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Section 9 of Appendix A1 – Participant involvement program guidelines.
TEP6) For a time extension to construct or alter a solar or wind power plant, provide:
TEP7) For a time extension to construct or alter a power plant that is not solar or wind power, the application shall include confirmation that the project does not require a wildlife survey or that the project wildlife surveys remain current and do not require updating.
TEP8) If the project has received a connection order, confirm that the Alberta Electric System Operator (if the project is to be connected to the transmission system) or the distribution facility owner (if the project is to be connected to the distribution system) has no concerns with the new construction or alteration completion date.
TEP9) Provide any available updates on outstanding directions associated with the existing approvals.
Discontinuing the operation of a power plant is referred to as decommissioning in this section. Dismantling or removing any works or installations forming part of a power plant is referred to as salvaging.
Notifications to decommission and salvage power plants are made pursuant to Section 22 of the Hydro and Electric Energy Act. This notice should be filed as a letter of enquiry application through the eFiling System.
Applications to decommission and salvage a power plant that contains an isolated generating unit are made pursuant to Section 21 of the Hydro and Electric Energy Act.
Cancellation of an approval for an unconstructed power plant does not require an application. Instead, the power plant approval holder should indicate that the project is being cancelled in a response to the Commission’s direction to provide confirmation of completion of the power plant.
This section outlines the requirements for applications for needs identification documents, and the requirements for applications to construct and alter transmission facilities, including transmission lines, substations, telecommunications facilities and fibre optic facilities.
The independent system operator (ISO) is responsible for identifying the need for the construction of new transmission projects or alterations to existing transmission facility as set out in Section 34 of the Electric Utilities Act and the Transmission Regulation. When the ISO identifies such a need, it seeks approval from the Commission of a needs identification document which is sometimes referred to as a “NID” or a “NID application.”
The ISO may submit an abbreviated needs identification document (ANID) application for a project responding to a generation or load system access service request at an estimated cost of less than $5 million for system-related cost.
A NID or an ANID can be submitted either as a stand-alone application or concurrently with a related facility application. When applications are filed concurrently, the NID and facility applications will be reviewed in a single Commission proceeding; however, the ISO will remain responsible for any concerns raised with respect to the need and the proposed technical solution of system enhancement, upgrade or interconnection. An approval, if granted, will be issued to the ISO for the needs identification document or abbreviated needs identification document prior to or at the same time as a permit and licence, if granted, to the facility applicant.
Unless otherwise directed, a NID application must contain the information set out in the requirements listed in the Transmission Regulation, and information requirements set out in subsection 7.1.1 of this rule. An ANID application must include the information outlined in subsection 7.1.2. If the information required is not provided, the application must contain an explanation of the reason for omitting the information.
For routine ANIDs driven by system access service requests from generators and non-distribution facility owner loads, the ISO may file a checklist application confirming that the regulatory requirements for the proposed work have been completed. An ANID will only qualify as routine, and be eligible to be filed as a checklist application, if:
For checklist applications, the ISO will not be required to file any other related supporting documents (e.g., technical studies, participant involvement program summaries), however, it will be required to retain the related supporting documents. The Commission will continue to ensure compliance with its requirements via audit procedures. The Commission will assess eligibility for an application to be filed as a checklist application and will issue a decision within five business days of receiving a properly completed checklist application. The ISO will be asked to file supplemental information for applications that are not eligible to be filed as checklist applications.
Please use the Needs identification document checklist application form to assemble the information required for a routine ANID checklist application.
Pursuant to the Transmission Regulation, a NID application is not required for:
If the exemption above does not apply, or if the TFO or market participant does not have prior approval from the ISO under the abbreviated needs approval process, it must receive AUC approval of the NID or ANID before an application for a new transmission facility or a time extension or alteration to an existing facility may be considered. Alternatively, the NID application may be submitted concurrently with the facility application under Section 15.4 of the Hydro and Electric Energy Act.
Please use the Needs identification document application form to assemble the information requirements for the project. Needs identification document is abbreviated as NID below.
NID1) Provide the information required under subsection 11(3) of the Transmission Regulation.
NID2) Provide information to support the ISO assessment of the need and selection of a preferred option. This information should include but is not limited to:
NID3) Provide the rationale, determination and assumptions for the following:
NID4) Provide an Association for the Advancement of Cost Engineering (AACE) Class 4 cost estimate for the applied-for option in accordance with the requirements in ISO Rules Section 504.5 and the Alberta Electric System Operator (AESO) Information Document #2015-002R, Service Proposals and Cost Estimating. The format of the cost estimate provided must take the form of the estimate summary that is obtained by completing the AESO’s cost estimate template (available on the AESO web page).
NID5) Indicate the date by which the transmission development described in the proposed needs identification document approval must be direct assigned to a transmission facility owner or market participant.
NID6) Describe the participant involvement program conducted by the ISO, including the rationale used to develop the participant involvement program (see Appendix A2 – ISO participant involvement program guidelines). A summary of how the ISO addressed the issues raised by participants must be included in the NID application.
Please use the Abbreviated needs identification document application form to assemble the information requirements for the project. Abbreviated needs identification document is also abbreviated as NID below.
NID7) Provide the information required under subsections 11(3)(a), (b), (f), (g) and (h) of the Transmission Regulation.
NID8) Provide information to support the ISO’s assessment of the need and selection of a preferred option. Depending on the nature of the need and the proposed solution, this information may include but is not limited to:
NID9) Provide the rationale, determination and assumptions for the following:
NID10) For projects where connection options are causing or exacerbating existing local area congestion, provide a connection assessment and the details of any operating procedures or remedial action schemes, generation must-run or constraint management protocols that may be implemented to meet reliability requirements prior to the transmission system enhancement or expansion being implemented.
NID11) Provide an AACE Class 4 cost estimate for the applied-for option and other viable options in accordance with the requirements in ISO Rules Section 504.5and the AESO Information Document #2015-002R, Service Proposals and Cost Estimating. The format of the cost estimate provided must take the form of the estimate summary that is obtained by completing the AESO’s cost estimate template (available on the AESO web page).
NID12) Provide a description of the participant involvement program conducted by the ISO, including the rationale used to develop the participant involvement program (see Appendix A2 – ISO participant involvement program guidelines). A summary of how the ISO addressed the issues raised by participants must be included in the application.
This section outlines the requirements for applications to construct or alter transmission facilities, including transmission lines, substations, telecommunication facilities, and fibre optic facilities.
Applications to construct and operate transmission facilities are made pursuant to sections 14 and 15 of the Hydro and Electric Energy Act.
Applications by a market participant to construct and temporarily operate a substation or transmission line are made pursuant to Section 24.31 of the Transmission Regulation.
Any application to construct and operate a substation or transmission line must include the information outlined in subsection 7.2.1.
If the proposed development includes both a substation application and a transmission line application, and there is duplication between the requirements (for example, if one participant involvement program was completed for the project and each application requires a summary of the participant involvement program), the applicant must satisfy those requirements in full in one of the applications, and may refer to that application in the other application.
A separate application form should be submitted for each transmission facilities and interconnection application as part of a single proceeding.
If a new connection to the Alberta Interconnected Electric System is also necessary, a connection order application must also be made, pursuant to Section 18 of the Hydro and Electric Energy Act, and include the information indicated in Section 11.
Applications to discontinue, dismantle or remove an approved transmission facility are made pursuant to Section 21 of the Hydro and Electric Energy Act. The information requirements for these applications can be found in Section 9.
Please use the Transmission/substation facility application form to assemble the information requirements for the project. Transmission/substation facility is abbreviated as TS below.
TS1) Provide a description of the proposed project.
TS2) Confirm if the application is for a customer project or an application related to a proposal for a market participant under Section 24.31 of the Transmission Regulation.
TS3) Provide details of the ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the operator of the facilities that is seeking to acquire the permit or licence. Confirm that the applicant is a qualified owner.
TS4) Provide a list of existing approvals for facilities directly affected by this project, if any.
TS5) Provide a copy of the ISO direct assignment letter pursuant to the Electric Utilities Act. Alternatively, if a needs identification document was not required, provide a copy of the ISO approval letter pursuant to the abbreviated needs approval process, or provide a statement in the application that the project was exempt pursuant to the Transmission Regulation (as described in subsection 7.1 of this rule).
TS6) Provide the most up-to-date functional specification issued by the ISO.
TS7) Describe the design and ratings of the transmission line and major elements of the substation.
TS8) If the ISO requires the facility applicant to determine the choice of conductors, describe the conductor size and arrangement selected and the basis for the conductor selection.
TS9) If the application is not direct assigned by the ISO, provide the rationale for the rating/size of any proposed conductor or piece of major substation equipment.
TS10) Describe the proposed transmission line structure type, including height and spacing; if more than one type of structure is proposed, state where each type will be used.
TS11) State the right-of-way width and the basis for determining the width.
TS12) Describe all major substation equipment being applied for, including the height of any telecommunications structure, and provide a list of the final major equipment that would be in the substation.
TS13) Describe the switching and protection features of the proposed transmission facilities.
TS14) Describe the electrical interaction of proposed transmission facilities with other facilities, such as pipelines, railways, telephone, radio and television transmission facilities, and other surface structures.
TS15) Describe the changes to existing facilities required to accommodate the proposed facilities.
TS16) Describe any transmission line routing alternatives to the proposal, and compare the relative effects (environmental, social and economic, including any associated distribution costs) of these alternatives with the proposal. If the alternatives are segmented, include a comparison of the effects of each segment to the effects of its corresponding alternative segments.
TS17) Provide an electric single-line diagram or switching map showing new facilities in place in the system. In the case of a substation, provide an electric single-line diagram and a substation layout diagram, including major items of equipment and the fenced boundary of the substation, with units of measure/scale.
TS18) Discuss the construction schedule, equipment and method of construction, and method of eventual right-of-way maintenance.
TS19) Provide the requested approval date from the AUC, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be stipulated in the project permit(s) and licence(s).
TS20) If available, provide the location of any required temporary or permanent workspace areas and access roads, and state whether these locations are requested to be listed in a permit and licence.
TS21) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
TS22) Provide a Keyhole Markup Language (.kml/.kmz) file that contains the geographic data of the transmission line centre lines for all applied for transmission route options and substation locations. This file should reflect the information shown on the drawings and maps submitted to address information requirement TS21.
TS23) If applicable, describe the measures proposed to minimize potential visual effects of the proposed development, including the identification of project components and locations that require screening and the screening measures (e.g., fences, earth berms, painting, landscaping) to be used.
TS24) Submit an environmental evaluation of the project. The environmental evaluation must:
TS25) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007 and Rule 012 and describe the steps taken, if any, to address specific requirements set out in these rules.
TS26) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
TS27) Describe any decommissioning of existing transmission facilities and describe the reclamation plan that will be carried out, including for any temporary workspace areas and temporary access roads following commissioning.
TS28) Provide a noise impact assessment in accordance with Rule 012 for new substations and transformer additions within an existing substation, clearly indicating the impact of the new substation and/or transformer addition.
Approvals from other agencies
TS29) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
TS30) For the preferred route and possible alternatives, applicants must provide a summary of feedback received to date from AEPA (including the local wildlife biologist of AEPA) addressing the environmental aspects of the project, and confirmation that AEPA is satisfied with any proposed mitigation measures and monitoring activities, or identify any unresolved project aspects where agreement with AEPA was not achieved.
TS31) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical, archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
TS32) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
TS33) List all occupants, residents and landowners within the appropriate notification radius as determined using Appendix A1 – Participant involvement program guidelines, as well as Indigenous groups and other interested persons that were notified or consulted as part of the participant involvement program.
TS34) Supply a list of contact information for all persons who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
TS35) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
TS36) Identify all person(s) who expressed a concern(s) about the project. For each person, include the following information:
Economic assessment
TS37) Provide an AACE Class 3 cost estimate for the preferred route and all alternatives on a common basis, in accordance with the requirements in ISO Rules Section 504.5 and the AESO Information Document #2015-002R, Service Proposals and Cost Estimating. The format of the cost estimate provided must take the form of the estimate summary that is obtained by completing the AESO’s cost estimate template (available on the AESO web page). Where identifiable, include costs to be borne by persons other than the applicant and the applicant’s customer(s) in the comparison. This information requirement may not be applicable to market participant and merchant line applications.
Market participant choice
TS38) In addition to the above, if the applicant is a market participant applying under Section 24.31 of the Transmission Regulation, the applicant must also:
Energy storage facility
TS39) If an energy storage facility is to be constructed and operated as part of a transmission line, the applicant must also submit the information specified in Section 10.
TS40) An applicant seeking to construct and operate an energy storage facility as part of a transmission line must provide the approval number for the associated needs identification document application.
This section outlines the process for transmission facilities that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can proceed to amend its transmission facilities approvals without filing an application, by submitting a checklist application or an amendment application. If the amendment is related to an energy storage facility that is to be constructed and operated as part of a transmission line, applications must include the information outlined in subsection 10.4 as applicable.
No application
No application is required if there are no changes to the existing permit and licence and the project meets all of the following conditions:
If a decision is required by the AUC, a letter of enquiry application or an amendment application should be submitted.
If no application is required, proponents shall retain a project record for information purposes that includes a project description, the need, nature, extent and the timing of the project, and the criteria used to determine that the project was a minor alteration with no adverse effects on a person or the environment. The project record could be requested by the Commission in the event that there is a complaint related to the project. Further, the project record may be subject to a subsequent compliance review by the AUC.
Examples of projects that would likely be considered minor alterations have no adverse effects on a person or the environment, and would therefore not require an application, include:
Checklist application
If the project is a minor alteration and there are no adverse effects on a person or the environment, but the project requires the amendment of an existing permit and licence, or requires a decision by the AUC, the application should be filed as a checklist application.
The applicant must file a checklist application, confirming that all the regulatory requirements for the proposed amendment have been met and a draft of the amended permit and licence, including an updated transmission line route map. All applications for minor transmission facilities alterations must be filed as a checklist application using the checklist form. The checklist form contains questions respecting the need, nature, extent and the timing of the alterations and confirmations that the proposed alterations do not have any adverse impacts on the environment and people.
Applicants are not required to file any other related supporting documents (e.g., environmental evaluations, participant involvement program summaries), however, applicants are required to retain all related supporting documents. The Commission will continue to ensure compliance with its requirements via an audit review process.
Please use the Electric transmission checklist application form and accompanying instructions to assemble the information requirements for a transmission facility alteration.
If an applicant is making changes that are not a minor alteration, or there are potentially adverse effects on a person or the environment, the applicant must file an amendment application with the AUC that provides all applicable information required within subsection 7.2.1.
An application for a time extension for a transmission facility must be filed as a checklist application confirming that the regulatory requirements for the proposed time extension have been met and, in some cases, a draft of the amended permit and licence must be included.
Applications for a time extension to complete the construction or alteration of a substation or transmission line are made pursuant to Section 19 of the Hydro and Electric Energy Act.
Applicants will not be required to file any other related supporting documents (e.g., environmental evaluations, participant involvement program summaries), however, applicants will be required to retain the related supporting documents. The Commission will continue to ensure compliance with its requirements via audit procedures.
The Commission will assess eligibility for an application to be filed as a checklist application and will issue a decision within five business days of receiving a properly completed checklist application. Applicants will be asked to file supplemental information for checklist applications that do not meet the requirements.
Please use the Electric transmission time extension checklist application form and accompanying instructions to assemble the information requirements for a time extension for a transmission facility.
If a time extension is related to an energy storage facility that is to be constructed and operated as part of a transmission line, applications must include the information outlined in subsection 10.7 as applicable.
Applications to discontinue the operation of, or dismantle or remove any work or installation forming part of a permit and/or licence with respect to a substation, a transmission line and other transmission facility are made pursuant to Section 21 of the Hydro and Electric Energy Act.
An application to decommission or salvage a transmission facility must include the information outlined in subsection 9.1. If the decommission and salvage is related to an energy storage facility that is to be constructed and operated as part of a transmission line, applications must include the information outlined in subsection 10.5 as applicable.
An application to cancel a transmission facility permit and licence must include the information outlined in subsection 9.2. If the cancellation is related to an energy storage facility that is to be constructed and operated as part of a transmission line, applications must include the information outlined in subsection 10.6 as applicable.
Please use the Decommission and salvage application form to assemble the information requirements for the project. Decommission and salvage is abbreviated as DST below.
DST1) Provide the permit and licence of the facility to be decommissioned or salvaged.
DST2) Provide a letter from the ISO endorsing the project.
DST3) Provide information on: the salvage, remediation and reclamation work to be performed; an assessment of contamination; the legislative requirements or other published guidelines that will be adhered to or considered.
DST4) Confirm that decommissioning will take place in alignment with any clean up and reclamation plan in place.
DST5) Provide a cost estimate and the schedule for the salvage.
DST6) Confirm that personal notification was provided to occupants, residents, landowners, Indigenous groups and other utilities on, or directly adjacent to, the project right-of-way or location
DST7) Identify all person(s) who expressed a concern(s) about the project. For each person, include the following information:
Please use the Cancellation application form to assemble the information required for the cancellation of a project. Cancellation is abbreviated as CT below.
Needs identification document approval cancellation
CT1) Provide the approval number to be cancelled and the rationale for the cancellation.
Transmission line, substation and other transmission facility cancellation
CT2) Provide the permit and licence number to be cancelled.
CT3) Provide the connection order number to be cancelled, if applicable.
CT4) Provide a letter from the ISO endorsing the cancellation.
CT5) Describe whether any work on the construction of the transmission line or substation has been started, and if so, describe the extent of the work.
CT6) If any work on the construction of the transmission line or substation has been started, describe how the site will be reclaimed.
CT7) Confirm that personal notification was provided to occupants, residents, landowners, Indigenous groups, and other utilities on, or directly adjacent to, the project right-of-way or location.
If an applicant is applying to construct and operate a new energy storage facility or to alter an approved energy storage facility, the application must include the information requirements listed in subsection 10.3.
If a connection order is also part of the project, a separate interconnection application should be added prior to registering the proceeding.
If an energy storage facility is to be constructed and operated as part of an electric distribution system, in addition to information requirements ES1 to ES32 in subsection 10.3, the applicant must provide information demonstrating that:
If the energy storage facility is less than one MW, the owner may proceed without filing an application if the requirements of subsection 3(3) of the Hydro and Electric Energy Regulation are met.
Please use the Energy storage facility application form to assemble the information requirements for the project. Energy storage facility is abbreviated as ES below.
ES1) State the approvals that are being applied for from the AUC.
ES2) Provide the total capability in MW and storage capacity in megawatt-hour (MWh) of the project.
ES3) Describe where the proposed energy storage facility is charged from and discharged to.
ES4) Summarize the discussions held with the ISO, transmission facility owner, and/or distribution facility owner regarding the interconnection of the proposed energy storage facility, including any concerns indicated and solutions proposed.
ES5) Provide a single-line diagram for the project including the metering points for the proposed project.
ES6) Describe the recycling plan, based on current regulations, for the energy storage facility at project end of life and confirm that the final recycling plan will be in accordance with the regulation in place at the time of decommissioning.
ES7) Provide a list of existing approvals for facilities directly affected by this project, if any.
ES8) Provide details of the project ownership structure, including the names of all companies having an ownership interest in the project and their ownership share, and if applicable, the name of the project operator. Confirm that the applicant is a qualified owner.
ES9) Provide documentation confirming compliance with Section 95 of the Electric Utilities Act, if applicable.
ES10) Describe the location of the project:
ES11) Provide the following drawings and maps with units of measure/scale and the direction of north specified:
ES12) Provide the requested approval date from the Commission, the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval. Provide the rationale for these dates.
ES13) If a connection order is not concurrently being applied for, provide the expected date when the connection order application will be submitted.
ES14) Provide the asset identification code assigned by the independent system operator (ISO) and the ISO Project ID number related to your system access service request, if available.
ES15) If the energy storage facility is to be connected to the transmission system, provide a map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the energy storage facility to the Alberta Interconnected Electric System.
If the energy storage facility is to be connected to the distribution system, provide a statement from the distribution facility owner indicating that it is willing to connect the energy storage facilities.
ES16) Confirm the applicant has or will have a corporate or site-specific emergency response plan for the construction and operation of the proposed energy storage facility. If the applicant will have a corporate emergency response plan, please explain why it decided not to develop a site-specific emergency response plan.
ES17) Provide a summary of the following:
ES18) Confirm that local responders and authorities have been contacted or notified regarding the project emergency response plan. Describe any requirements or feedback received and describe how the applicant intends to address the requirements and feedback received.
ES19) Provide a summary of feedback received to date from AEPA addressing the environmental aspects of the project and any mitigation measures and monitoring activities recommended by AEPA.
ES20) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
ES21) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The proponent must address how it has considered AUC Rule 007, Rule 012 and Rule 033 and describe the steps taken, if any, to address specific requirements set out in these rules.
ES22) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
ES23) Provide an overview of how the operator will ensure sufficient funds are available at the end of life of the project to cover the cost of decommissioning and reclamation.
ES24) Provide a noise impact assessment in accordance with Rule 012.
ES25) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
ES26) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
ES27) If the Government of Alberta, through the Aboriginal Consultation Office (ACO) or otherwise, directed consultation with an Indigenous group for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.) the applicant must provide a copy of the pre-consultation assessment, the adequacy assessment and the specific issues and response table (if prepared). If the Government of Alberta, through the ACO or otherwise, indicated that a pre-consultation assessment is not required, the applicant must provide a copy of that direction. If advice from the Government of Alberta has not been obtained, the applicant must provide justification for its decision to not seek advice.
ES28) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
ES29) List all occupants, residents and landowners on lands within the appropriate notification radius as shown below and described in Appendix A1– Participant involvement program guidelines, as well as Indigenous groups or other interested persons that were consulted as part of the participant involvement program.
Table 10.1: Notification radius for energy storage facilities
ES30) Supply a list of contact information for all person(s) who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
ES31) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
ES32) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
This section outlines the process for projects that have received AUC approval and require an amendment. Depending on the scope of the proposed changes in relation to the original application, an applicant can make one of the following three types of submissions to amend its energy storage facility approval: final project update, letter of enquiry, or amendment application.
For energy storage projects where the applicant is able to confirm that the project has stayed within the outlined allowances, an applicant is only required to submit a final project update on the record of the original proceeding. The AUC will review the update to confirm that the project has stayed within the allowances.
Please use the Energy storage facility final project update requirements form to assemble the information required for the final project update.
Table 10.2: Final project update requirements for energy storage facilities
If an applicant is making minor alterations to an existing or approved but not yet constructed energy storage facility that exceed the final project update allowances set out in Table 10.2, the applicant may submit a letter of enquiry. In the letter of enquiry, the applicant must provide information respecting the need, nature, extent, land affected and the timing of the alterations. The applicant must demonstrate that the proposed alterations do not have any adverse impacts on the environment or any person.
If an applicant is making changes to an existing or approved but not yet constructed energy storage facility that exceed the final project update allowances outlined in Table 10.2 and do not meet the criteria for a letter of enquiry, the applicant must file a complete amendment application that provides all applicable information required within subsection 10.3.
Please use the Energy storage facility decommission and salvage application form to assemble the information requirements if applications to decommission and salvage an energy storage facility are made pursuant to sections 21 or 30(1) of the Hydro and Electric Energy Act. Decommission and salvage of energy storage facility is abbreviated as DSES below.
DSES1) Provide the approval of the facility to be decommissioned or salvaged.
DSES2) Provide a letter from the ISO or distribution facility owner endorsing the project.
DSES3) Provide information on the salvage, remediation and reclamation work to be performed; an assessment of contamination; and the legislative requirements or other published guidelines that will be adhered to or considered.
DSES4) Confirm that decommissioning will take place in alignment with any cleanup and reclamation plan in place.
DSES5) Provide a cost estimate and the schedule for the salvage.
DSES6) Confirm that personal notification was provided to occupants, residents, landowners, Indigenous groups and other utilities directly adjacent to the project boundary.
DSES7) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
If notifications to decommission and salvage energy storage facilities are made pursuant to Section 22 of the Hydro and Electric Energy Act, the notices should be filed as a letter of enquiry application through the eFiling System.
Please use the Energy storage facility cancellation form to assemble the information requirements if the energy storage facility contains an isolating generating unit, is part of a transmission line or electric distribution system. Cancellation of energy storage facility is abbreviated as CES below.
CES1) Provide the approval number to be cancelled.
CES2) Provide the connection order number to be cancelled, if applicable.
CES3) Provide a letter from the ISO or distribution facility owner endorsing the cancellation.
CES4) Describe whether any work on the construction of the energy storage facility has been started, and if so, describe the extent of the work.
CES5) If any work on the construction of the energy storage facility has been started, describe how the site will be reclaimed.
CES6) Confirm that personal notification was provided to occupants, residents, landowners, Indigenous groups, and other utilities directly adjacent to the project boundary.
Cancellation of an approval for an unconstructed energy storage facility that does not contain an isolated generating unit, is not part of a transmission line or electric distribution system does not require an application. Instead, the energy storage facility approval holder should indicate that the project is being cancelled in a response to the Commission’s direction to provide confirmation of completion of the energy storage facility and provided the reason why the project is being cancelled.
Please use the Energy storage facility time extension application form to assemble the information requirements for the project. Time extension application for energy storage facility is abbreviated as TEES below.
TEES1) Provide a list of the existing approvals for facilities affected.
TEES2) Explain whether construction of the approved energy storage facility has commenced. If it has not yet commenced, explain whether it will commence prior to the expiry date of the existing approval. Explain why the construction or alteration completion date will not be met, why the time extension is required and provide an updated project schedule, including the expected construction start date, the expected in-service date of the project and the requested construction completion date to be used in the project approval.
TEES3) Provide a new noise impact assessment, as required under subsection 1.5 of Rule 012 if one or more of the following conditions is satisfied:
TEES4) Confirm that the participant involvement program meets the requirements contained in Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups. Describe any concerns specific to the time extension request, raised by directly and adversely affected persons and how the concerns were dealt with or will be dealt with.
TEES5) Supply a list of contact information for all persons who were contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Section 9 of Appendix A1 – Participant involvement program guidelines.
TEES6) Provide confirmation that the project does not require a wildlife survey or that the project wildlife surveys remain current and do not require updating.
TEES7) Confirm that the Alberta Electric System Operator or the distribution facility owner has no concerns with the new construction or alteration completion date.
TEES8) Provide any available updates on outstanding directions associated with the existing approvals.
An application to interconnect a power plant or an energy storage facility to the Alberta Interconnected Electric System, or to interconnect two or more transmission facilities owned by different parties must include the information outlined in subsection 11.1.
An application is required pursuant to Section 18 of the Hydro and Electric Energy Act, for the interconnection of a power plant to the Alberta Interconnected Electric System or for interconnection of two or more transmission elements owned by different parties.
Please use the Interconnection application form to assemble the information requirements for the project.
Interconnection is abbreviated as IC below.
IC1) Provide a statement that the local distribution facility owner has agreed to the interconnection, the legal subdivision (LSD) of the interconnection point, and an electric single‑line diagram showing the interconnection point with the distribution facility owner.
IC2) Provide a statement from the ISO, at such time determined by the ISO, that endorses the interconnection and confirms that the interconnection will not result in adverse effects to the interconnected electric system.
An application to designate facilities as an industrial system must include the information outlined in subsection 12.1.
Applications requesting that an electric system be designated as an industrial system are made pursuant to Section 4 of the Hydro and Electric Energy Act.
If there is duplication between the requirements for an industrial system designation and an associated facility application (for example, if one participant involvement program was completed for the project and each application requires a summary of the participant involvement program), the applicant must satisfy those requirements in full in one of the applications, and may refer to the response in the corresponding application.
Please use the Industrial system designation application form to assemble the information requirements for the project. Industrial system designation is abbreviated as ISD below.
ISD1) State the approvals that are being applied for from the AUC and include a complete list of all electric facilities and equipment of 25 kilovolts or more to be included in the industrial system designation.
ISD2) Provide a list of existing approvals for facilities directly affected by this project, if any.
ISD3) Provide the legal description of the location of the electric facilities to be included in the proposed industrial system (legal subdivision [LSD], section, township, range, meridian and/or plan, block, lot, municipal address for urban parcels) and connection point, if applicable.
ISD4) Provide the following drawings and maps with units of measure/scale and direction of north specified:
ISD5) Provide an electrical single-line diagram of the entire industrial complex. This diagram must clearly show existing facilities, future facilities and their ownership.
ISD6) Provide block diagrams showing electrical, natural gas, steam, water and feedstock flows between the different blocks representing processes, including the flow of electricity to and from the Alberta Interconnected Electric System. Relevant units of measurement must be included to indicate flows (e.g., megawatts for electric flows, and cubic metres per second for gas and water flows). Also include in these diagrams the volumes consumed or produced by each process block.
ISD7) Provide a detailed description of the overall industrial process and include a list of the companies that own or operate different aspects of the industrial process, and describe how the different aspects of the industrial process will be managed.
ISD8) Provide an annual estimate of the gross amounts for generation, on-site load, import from and export to the Alberta Interconnected Electric System.
ISD9) Demonstrate, by way of an economic comparison, that the internal supply through on‑site generation is the most economic source of power for the industrial complex. For example, if the industrial complex uses cogeneration to produce electric and thermal energy, the applicant must provide a comparison of the costs of the internal supply of electricity and process heat with the alternative of contracting electrical supply from the Alberta Interconnected Electric System and installing heat exchangers or boilers in place to satisfy the thermal requirements of the industrial process. The economic comparison must be provided in a format similar to what is provided in Appendix B1 – Economic comparison formats – requirement ISD9.
All assumptions must be clearly stated, along with the basis for each assumption. In the discussion of the assumptions, address significant factors that could affect the economic comparison, such as fuel prices, power pool prices and delivery tariffs.
Provide a discussion of the sensitivities of the economic analysis in relation to the major factors that could have an impact on the economic comparison.
ISD10) Demonstrate that there is significant investment in:
ISD11) Provide an assessment of losses and congestion on transmission lines due to the electric power that the industrial complex would supply to the Alberta Interconnected Electric System. The assessment must also take into account other existing generation and generation under construction.
ISD12) If the industrial operation extends beyond the contiguous property of the industrial complex, provide information to satisfy the Commission that the overall cost of providing the owner’s own distribution or transmission facility to interconnect the integral parts of the industrial operation is equal to or less than the tariffs applicable for distribution or transmission in the service area where the industrial operation is located.
ISD13) If the industrial system will result in a significant and sustained increase in efficiency in the process of the industrial operation or in the production and consumption of electric energy by the industrial operation as a result of the integration of the electric system with the industrial operations the electric system forms part of and serves, provide a thermal energy balance to demonstrate this increase in efficiency.
ISD14) Explain how the proposal meets the principles of an industrial system outlined in subsection 4(2) of the Hydro and Electric Energy Act.
ISD15) Explain how the proposal meets the criteria of an industrial system outlined in subsection 4(3) of the Hydro and Electric Energy Act.
ISD16) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
ISD17) Supply a list of contact information for all persons contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
ISD18) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
Gas utility pipeline applications are made pursuant to the Pipeline Act and Gas Utilities Act.
This section provides information on gas utility pipeline exemptions and situations where an application may not be required. It then sets out the requirements for need applications, and the requirements for applications to construct, operate, or modify gas utility pipeline(s) or pipeline installation(s). Lastly, it sets out ongoing operational and reporting requirements for gas utility pipelines, including obligations related to flaring, incinerating, venting and storage.
The following section lists gas utility pipelines, installations and activities that may not require an AUC application or licence. If no exemptions are applicable, the gas utility must file a gas utility pipeline application containing all the information required by this rule and Rule 012: Noise Control.
Even if a gas utility is exempt from filing an application, the gas utility must provide a project-specific information package to any landowners, occupants, and residents that may be directly and adversely affected. The gas utility must file an application if there are unresolved objections.
No licence is required for the following pipeline installations:
No licence is required for the following pipelines and activities:
This section sets out the requirements for establishing the need for a gas utility pipeline capital project as part of a facility application.
The need for a gas utility pipeline capital project must be established before a licence will be issued regardless of what form of rate regulation applies to the gas utility. The Commission will assess the need for a project in the first instance the gas utility identifies the project to the Commission, either as part of a rate filing (i.e., general rate application or as part of an application for companies that are operating under performance-based regulation) or a facility application.
If a gas utility files an application for a licence for a project where the need was not previously assessed and approved in the rate decision, or before the rate decision is issued, the need will considered in conjunction with the facility application instead of the rate filing.
Need for a project should be addressed only one time, although need may be reconsidered if there is a material change in circumstances.
Please use the Gas utility pipeline need assessment application form to assemble the information required for the project. gas utility pipeline is abbreviated as GU below.
GU1) Identify any current or anticipated rate or facility applications associated with the project.
GU2) Provide an explanation of why the project is required, including but not limited to:
GU3) Describe whether the project is part of a larger initiative including a description of the project’s various components, functions and forecast in-service dates.
GU4) Provide a summary of the studies and analysis performed in identifying the timing and nature of the need.
GU5) Describe alternatives considered to address the identified need, including doing nothing.
GU6) Provide technical and economic comparison of all viable alternatives considered, including:
GU7) Describe the applicant’s choice of preferred alternative, including:
An abbreviated need assessment processes is available for the gas utility pipeline projects identified in Table 13.1 where there are no unresolved objections or significant environmental impacts. Thresholds in Table 13.1 indicate the maximum project cost or scope and are reflective of the differing rate base amounts between gas utility pipelines and the resultant rate sensitivity to capital additions. Where a project falls into two or more categories, the lower threshold applies.
Table 13.1: Abbreviated need thresholds
Please use the Gas utility pipeline abbreviated need application assessment form to assemble the information required for the project. gas utility pipeline is abbreviated as GU below.
GU8) Describe which threshold in Table 13.1 applies to the project.
GU9) Confirm that there are no unresolved interested party objections or significant environmental impacts.
GU10) Provide an estimated capital cost for the project.
GU11) Provide an explanation of why the project is required, including but not limited to:
This section outlines the requirements for applications to construct and operate gas utility pipelines and pipeline installations, and to replace existing pipelines or pipeline segments greater than 100 metres in length.
The types of pipelines requiring a licence under this rule are listed in the consultation and notification table in Appendix A1 – Participant involvement program guidelines under Section 5 specific to gas utility pipelines, along with their respective consultation and notification requirements. The applicant must identify the correct category type for the proposed pipeline and perform all associated consultations and notifications.
If a gas utility is not able to confirm that an information requirement is satisfied, the gas utility must provide a detailed explanation of which regulatory standards or requirements are not met and, wherever possible, support the explanation with a technical assessment that demonstrates how the project’s design, construction and operational considerations nevertheless address public safety and environmental concerns.
Please use the Gas utility pipeline licence application form to assemble the information required for the project. gas utility pipeline is abbreviated as GU below.
GU12) State the licence(s) being applied for from the AUC.
GU13) Provide a description of the proposed project.
GU14) Provide a list of existing approvals for facilities directly affected by this project, if any.
GU15) Describe whether the need for the project has already been established or is currently under consideration in another proceeding. If so, provide the proceeding number. If not, confirm that need will be considered in conjunction with the facility application.
GU16) If a capital cost forecast for the project has previously been provided to the Commission, confirm that current costs estimates do not vary by more than +/-30 per cent. If the previous and current cost estimates vary by more than +/- 30 per cent, provide updated capital cost forecasts.
GU17) For pipeline applications that involve new construction or an amendment to change or correct the pipeline route/right-of-way, submit a right-of-way plan and confirm that no permanent dwellings exist within the pipeline right-of-way boundaries.
GU18) Provide the H2S content in the gas phase in mol/kmol.
GU19) Confirm that the partial pressure of H2S in the gas phase is less than 0.30 kilopascals. If not, please provide the partial pressure of H2S in the gas phase.
GU20) Confirm that the project meets all applicable Canadian Standards Association (CSA) Z662 design requirements.
GU21) Confirm that all steel pipe, fittings, flanges and valves meet the applicable requirements of a standard or specification given in Table 5.3 of CSA Z662.
GU22) Confirm that procedures for corrosion mitigation, monitoring, evaluation and record keeping will be implemented prior to operation.
GU23) For pipeline installation applications, confirm that piping within the line heater is designed to meet American Society of Mechanical Engineers (ASME) B31.3.
GU24) For pipeline installation applications, submit a process flow diagram that accurately represents the operations of the installation and contains:
GU25) For pipeline installation applications, submit a plot plan that clearly indicates the on-lease location of all the equipment (with the exception of valves) as indicated on the process flow diagram.
GU26) Confirm the applicant has or will have a corporate-level emergency response plan that addresses the fundamentals for handling an emergency situation arising from the construction or operation of a gas utility pipeline or pipeline installation.
GU27) If preparation of either a federal impact assessment or a provincial environmental impact assessment report was required, provide a copy as an appendix to the application and a separate environmental evaluation is not required. If a federal impact assessment or a provincial impact assessment report was not required, submit an environmental evaluation of the project. The environmental evaluation must:
GU28) For projects wholly or partially located on federal lands (First Nation reserves, national parks or military bases), provide a copy of the environmental impact analysis completed for the corresponding federal government department. Indicate whether the project has the potential to cause effects that may cross into another jurisdiction. Environmental effects that originate on federal lands, but cross into another jurisdiction, must be addressed as part of the environmental review process. Projects on federal lands may be subject to provincial laws, standards and permits. The applicant must address how it has considered AUC Rule 007 and Rule 012 and describe the steps taken, if any, to address specific requirements set out in these rules.
GU29) Submit a stand-alone, project-specific environmental protection plan (or environmental management plan) that itemizes and summarizes all of the mitigation measures and monitoring activities that the applicant is committed to implementing during construction and operation to minimize any adverse effects of the project on the environment.
Nitrogen oxides emissions
GU30) When nitrogen oxides (NOx) emissions are present at pipeline installations that require registration or approval with the Alberta Energy Regulator (AER):
GU31) Provide a noise impact assessment in accordance with Rule 012.
GU32) Identify any other acts (e.g., Environmental Protection and Enhancement Act, Water Act, Public Lands Act, Highway Development and Protection Act and Wildlife Act) that may apply to the project, identify approvals the project may require, and provide the status of each of these approvals.
GU33) If the proposed gas utility pipeline or an activity related to a gas utility pipeline will result in a surface disturbance in the transportation/utility corridors, provide a ministerial consent or letter of non-objection from Alberta Infrastructure.
GU34) Confirm that a Historical Resources Act approval has been obtained or has been applied for. If a historic resource impact assessment is required, briefly describe any known historical or archaeological sites, palaeontological sites, or traditional use sites of a historic resource nature. If a Historical Resources Act approval has been obtained, provide a copy of it.
GU35) Identify the consultation and notification radius applicable to the project as set out in the consultation and notification table in Appendix A1 – Participant involvement program guidelines under Section 5.
GU36) Provide the distance to the nearest residence in kilometres.
GU37) For pipeline installations, provide the distance to the nearest surface development in kilometres.
GU38) Summarize the participant involvement information, including a description of the activities undertaken and include any engagement materials provided. (See Appendix A1 – Participant involvement program guidelines and Appendix A1-B – Participant involvement program guidelines for Indigenous groups).
GU39) Supply a list of contact information for all person(s) who had been contacted as part of the participant involvement program in a spreadsheet in accordance with the template included in Appendix A1 – Participant involvement program guidelines.
GU40) Summarize consultation with local jurisdictions (e.g., municipal districts, counties).
GU41) Confirm that all other Crown disposition holders, oil and gas reserve owners, and pipeline licensees that may be directly and adversely affected have been notified of the project.
GU42) Identify all persons who expressed a concern(s) about the project. For each person, include the following information:
This section outlines the process for projects that have received a pipeline licence and require a licence amendment due to a physical alteration or a change in operating parameters.
A licence amendment is also required to correct erroneous or invalid information on a current licence, and to notify the Commission when a previously approved pipeline or installation is not constructed.
Depending on the scope of the proposed changes in relation to the original application, a gas utility can make one of the following two types of submissions to amend its pipeline licence: a checklist amendment application or an amendment application.
Unless otherwise specified, an amendment application must be filed and the gas utility must obtain a licence amendment prior to undertaking any activity described in this section. Within 90 days of receiving an amended licence, the gas utility must file a related OneStop application with the AER, and file confirmation of the OneStop update with the Commission.
Table 13.2 outlines the eligibility requirements and application process for checklist amendment applications and amendment applications.
Table 13.2 Amendment process eligibility and application requirements
If a gas utility establishes that the proposed alterations are low-risk activities, the gas utility may file a checklist application confirming that the regulatory requirements for the proposed amendment have been met.
The Commission will assess eligibility for an application to be filed as a checklist amendment application and will issue a decision within five business days of receiving a properly completed checklist application. Applicants will be asked to file supplemental information for checklist applications that do not meet the requirements.
Please use the Gas utility pipeline checklist amendment application form to assemble the information requirements for eligible gas utility pipeline amendment applications.
A checklist amendment application is ordinarily eligible for the following types of amendments:
Some checklist amendment applications have specific regulatory requirements, these are described in further detail below.
Pipeline discontinuation
A licence amendment is not required prior to a pipeline discontinuation; however, the gas utility must notify the Commission by submitting a checklist amendment application within 90 days of completion of the pipeline discontinuation.
When discontinuing a pipeline, the gas utility must ensure that proper discontinuation procedures are in place, cathodic protection is maintained, and setback distances are retained (right-of-way boundaries). A gas utility should be prepared to explain, with reference to supporting documentation, how it ensured that the pipeline was discontinued in accordance with the requirements of the Pipeline Rules.
Pipeline abandonment
A licence amendment is not required prior to a pipeline abandonment; however, the gas utility must notify the Commission by submitting a checklist amendment application within 90 days of completion of the pipeline abandonment.
When abandoning a pipeline, the gas utility must ensure that proper abandonment procedures are in place and take the measures required to ensure that the pipeline is left in a permanently safe and secure condition. A gas utility should be prepared to explain, with reference to supporting documentation, how it ensured that the pipeline was abandoned in accordance with the requirements of the Pipeline Rules.
Maximum operating pressure decrease
The gas utility must determine if either of the following is affected by a decrease in maximum operating pressure (MOP) and take the necessary mitigation measures to ensure continued compliance:
If a gas utility is making changes that do not meet the criteria for a checklist amendment application, the gas utility must file an amendment application that responds to all information requirements contained in subsection 13.3.2 as well as any additional information requirements specific to the amendment. The gas utility must also comply with the applicable notification and consultation requirements for pipeline activities requiring licence amendments, which are listed in the consultation and notification table in Appendix A1 – Participant involvement program guidelines under Section 5.
An amendment application is ordinarily required for the following types of amendments:
Please use the Gas utility pipeline licence application form to assemble the information requirements for the project. gas utility pipeline is abbreviated as GU below.
Pipeline resumption
GU43) Explain whether the pipeline has been discontinued or abandoned, and provide the date on which it was last in active flowing service.
GU44) Confirm that the pipeline was discontinued or abandoned in accordance with the requirements of the pipeline rules.
GU45) Confirm that the pipeline will operate under the same parameters approved by the Commission when it was last in active flowing service.
GU46) Confirm that cathodic protection was maintained in accordance with CSA Z662.
GU47) Describe the integrity of the external coating, with reference to an engineering assessment or other supporting documentation if available. If the pipeline has previously been abandoned, provide a comprehensive engineering assessment supporting the resumption.
Maximum operating pressure increase
GU48) Describe what testing was undertaken to confirm capability for the increased maximum operating pressure (MOP).
GU49) Confirm that the pipe, valves, flanges and fittings are suitable for the increased MOP.
GU50) Confirm that an increase in MOP will not affect the existing overpressure protection on upstream and downstream pipelines.
GU51) Describe whether any pipeline setbacks are affected by the increased MOP.
GU52) Describe whether the increased MOP will necessitate either of the following:
If a gas utility is applying for a time extension for a gas utility pipeline prior to the licence expiring, a checklist amendment application must be filed confirming that the regulatory requirements for the proposed time extension have been met.
Prior to initiating new construction when a licence is nearing expiry, the gas utility must conduct a new resident and landowner search and determine if any new issues have arisen since the licence was granted.
If a gas utility intends to proceed with a proposed gas utility pipeline for which a licence has expired, the gas utility must fulfil all applicable requirements, including participant involvement requirements in Appendix A1 – Participant involvement program guidelines, before filing a new application. The applicant should contact the Commission for further direction on how to proceed. Please use the Gas utility pipeline time extension checklist application form to assemble the information requirements for the time extension application.
This section sets out operational requirements applicable to gas utilities.
GU53) A gas utility pipeline licensee must comply with sections 6 and 7 of AER Directive 060: Upstream Petroleum Industry Flaring, Incinerating, and Venting.
GU54) Temporary, short-term venting is allowed at gas utility pipelines and pipeline installations on the following conditions:
GU55) Temporary venting is permitted within 500 metres of a residence if the volume vented does not exceed 500 m3. Venting volumes in excess of 500 m3 requires the approval of the local AER field centre and the consent of the resident whose residence is within 500 m of the venting.
GU56) In the event of an upstream process upset, gas containing more than 10 mol/kmol H2S must not be vented to the atmosphere. Venting must not result in H2S odours outside the boundary of the site of the pipeline installation.
GU57) Venting must not result in off-site exceedances of the Alberta Ambient Air Quality Objectives.
GU58) A licensee must keep all equipment and controls design information and submit it to the Commission upon request, if the Commission determines that there is a concern with the equipment or controls.
GU59) A licensee must keep copies of operating limits and procedures and submit them to the Commission upon request.
GU60) A licensee must keep design information on flare and incinerator system liquid separation equipment and submit it to the Commission upon request.
GU61) A licensee must keep information on backflash controls and submit it to the Commission upon request if the Commission determines that there is a concern with the equipment or controls.
GU62) A licensee must maintain a log of flaring, incinerating, and venting occurrences and respond to public complaints and to comply with release reporting requirements set out in the Pipeline Rules. Logs must:
GU63) Flaring, incinerating, and venting records must be made available to the Commission upon request for each pipeline or pipeline installation, where flaring, incinerating, and venting occur.
GU64) A licensee may retain logs for remote or semi-attended facilities at a central location where public complaints related to the pipeline installation in question would normally be received.
GU65) A gas utility pipeline licensee must comply with all applicable requirements of AER Directive 055: Storage Requirements for the Upstream Petroleum Industry.
An application to transfer an approval with respect to a power plant, interconnection, transmission facility, energy storage facility or industrial system designation, or gas utility pipeline must include the information outlined below.
Each approval that is being requested to be transferred must be submitted as a separate application, however, all of the transfers may be requested in a single proceeding.
Please use the Electric facility approval transfer application form or Gas utility pipeline approval transfer application form to assemble the information requirements for the project. Approval transfer is abbreviated as AT below.
AT1) State the approvals or licences to be transferred, including connection orders, if applicable.
AT2) Provide a list of existing approvals for facilities directly affected by the application.
AT3) Provide a list of companies that may be affected by the transfer and confirm that these companies have no concerns regarding the application. This must include the transmission facility owner (TFO) or distribution facility owner that the facilities are connected to.
AT4) Provide the effective date of the transfer.
AT5) Provide details of the current and proposed ownership structure, including the names of all companies having an ownership interest and their ownership share, and if applicable, the name of the operator of the facilities that is seeking to acquire the approval, permit or licence. Confirm that the proposed approval holder is a qualified owner.
AT6) If the proposed approval holder is a municipality or a subsidiary of a municipality, provide documentation confirming compliance with Section 95 of the Electric Utilities Act.
AT7) For a transfer of an operating licence from a market participant to a TFO the application must include:
AT8) State the licence(s) to be transferred.
AT9) Provide a list of companies that may be affected by the transfer and confirm that these companies have no concerns regarding the application.
AT10) Provide the effective date of the transfer.
AT11) Describe the need that is being met by the pipeline transfer and the alternatives considered.
AT12) Describe the pipeline integrity review that has been undertaken to ensure the safety and reliability of the pipeline.
Some of the terms used in this rule are defined for this particular context; these definitions are not necessarily the same as the generally accepted broader definitions of the terms.
Table 16.1:Glossary
(i) The ability to positively identify target species by sight and/or sound.
(ii) Familiarity with the species biology, including habitat requirements of the species and experience in identifying the species habitat features.
(iii) Familiarity with survey methods as described in the Sensitive Species Inventory Guidelines.
(iv) Attained a Bachelor of Sciences degree in Biology, Environmental Sciences, Renewable Resources, or holds a Technical Diploma in Natural Resources or Environmental Management from a certified college.
(v) Multiple years of wildlife and surveying experience.
The dwelling must not be mobile and should have some sort of foundation or features of permanence (e.g., electrical power, domestic water supply, septic system) associated with it. Summer cottages or manufactured homes are examples of seasonally occupied dwellings, while a holiday trailer simply pulled onto a site is not.
(for the purposes of this document, decommissioning is included as part of the process of reclamation)
All practical and reasonable methods of designing and conducting an activity to ensure:
1.1 Purpose of the participant involvement program guidelines
These guidelines list the factors that an applicant should consider when creating its participant involvement program (PIP). The Commission expects that an applicant will adhere to these guidelines when developing its PIP. However, the Commission recognizes that there may be circumstances where it may be appropriate for an applicant to deviate from these guidelines. In those circumstances, the Commission expects the applicant to explain the circumstances and rationale for the deviation.
The precise extent and scope of an applicant’s PIP cannot be predetermined because each application is unique and may present circumstances that must be addressed on an individual basis.
A PIP must be conducted before an electric facility or gas utility pipeline application can be submitted to the Commission. An applicant should consider these guidelines in relation to new electric facility or gas utility pipeline projects, and also when it is modifying, seeking a time extension, salvaging, or decommissioning an existing electric facility or modifying, seeking a time extension, removing or resuming service on a gas utility pipeline or installation.
The Commission requires the applicant to assume responsibility for informing stakeholders and Indigenous groups and involving them in the applicant’s project.
If there is a potential for the applicant’s project to impact Aboriginal or treaty right as provided in Section 35 of the Constitution Act, 1982 (Section 35 rights), applicants must specifically address this as part of the participant involvement program and identify the Indigenous groups consulted. Section 35 rights may be practiced on unoccupied Crown land and other lands to which the members have a right of access for such purposes.
1.2 Purpose of the participant involvement program
It is paramount that effective communications take place between the applicant and all potentially affected persons including Indigenous groups, the public, local authorities, agencies, industry and government so that concerns may be raised, properly addressed, and if possible, resolved. All persons whose rights may be directly and adversely affected by a proposed development must be informed of the application, have an opportunity to voice their concerns and have an opportunity to be heard.
Stakeholders and Indigenous groups are strongly encouraged to participate in ongoing issue identification, problem solving and planning with respect to local electric facility and gas utility pipeline projects. Early involvement in informal discussions with an applicant may lead to greater opportunity to influence project planning and mitigation of potential impacts. Recognition of landowner groups with common concerns and issues at an early stage of the PIP, especially in highly developed areas, may be an efficient way for applicants and potentially affected persons to interact and discuss the project and any related concerns.
In its PIP, the applicant is expected to consider how to effectively communicate and interact with persons whose rights may be directly and adversely affected by the proposed project. This includes the public, local authorities, agencies, industry, Indigenous groups and government and may also include other groups that have a stake in electric facility and gas utility pipeline projects, should such groups make themselves known to the applicant.
As mentioned above, the development and implementation of the PIP must occur prior to the filing of an application with the Commission. The elements of the PIP must include:
Local authorities and various provincial departments have a role in ensuring orderly land use and development. Applicants should consider whether it is appropriate to involve these groups at an early stage in the planning of the electric facility or gas utility pipeline project and its PIP.
The Commission encourages an applicant to be sensitive to the capacity challenges and timing constraints of Indigenous groups (e.g., seasonal land use and cultural activities) and other stakeholders (e.g., planting, harvesting, calving seasons and statutory holidays) when developing and implementing its PIP.
Comprehensive project-specific information must be developed and made available to all persons included in the PIP. Distribution of project-specific information may include, but is not limited to, website content, email, and addressed or unaddressed postal mail.
The applicant must use appropriate language and terminology in all written, electronic and website materials so that stakeholders and Indigenous groups can clearly understand the details of the proposed project and the impact(s) it may have upon them. At a minimum, all persons must be given the following project-specific information and be provided with options for accessing more detailed information in the format of their choice (e.g., postal mail, website or electronic communication):
If the proposed project is part of a larger project, the applicant is expected to discuss the entire project and explain how it complements other development in the area.
In addition to the aforementioned, an applicant must include the following project-specific information about the project if applying for a gas utility pipeline licence. In the event that one or more points are not applicable an explanation must be provided:
Who to include – electric facility and gas utility applications
Depending on the scenario, this rule contemplates two types of notification requirements, personal notification and public notification, as well as personal consultation. The Commission recommends that notification and consultation should, at a minimum, be conducted to the distances outlined in the following table.
If there is Crown land within the distances identified in the following table, the applicants should consider if there is a potential for the project to impact Section 35 rights and if so, include Indigenous groups in the PIP. Applicants are encouraged to be aware of the Government of Alberta’s consultation policies and guidelines, and to use the Government of Alberta’s Landscape Analysis Indigenous Relations Tool (LAIRT) to inform their decisions about consultation. If no steps were undertaken by the applicant to identify and consult with Indigenous groups, the applicant must provide an explanation for that decision.
Table A1-1: Electric facility application notification and consultation requirements
For wind and solar power plants, provide personal notification to the owners of any registered aerodrome within 4,000 metres from the proposed turbine locations, or the edge of the proposed power plant site boundary for solar plants, and provide public notification to owners of unregistered aerodromes within 4,000 metres measured from proposed turbine locations, or from the edge of the proposed solar power plant site boundary, respectively.
If the applicant considers that certain landowners that should be notified of the proposed project may be missed because they do not reside at the property, additional efforts to notify them should be considered.
For wind and solar power plants, provide personal notification to the owners of any registered aerodrome within 4,000 metres from the proposed turbine locations, or the edge of the proposed solar power plant site boundary, and provide public notification to owners of unregistered aerodromes within 4,000 metres measured from proposed turbine locations, or from the edge of the proposed solar power plant site boundary, respectively.
Provide personal notification to the owners of any registered aerodrome within 4,000 metres from the proposed turbine locations and provide public notification to owners of unregistered aerodromes within 4,000 metres measured from the proposed turbine locations.
For major power plant applications, if there are populated areas just outside the 1,500-metre distance, applicants should consider including those areas in the public notification.
For solar power plants, provide personal notification to the owners of any registered aerodrome within 4,000 metres from the edge of the proposed power plant site boundary and provide public notification to owners of unregistered aerodromes within 4,000 metres measured from the edge of the proposed power plant site boundary.
For major power plant applications, if there are populated areas just outside the 800-metre distance, applicants should consider including those areas in the personal notification.
For wind power plants, provide personal notification to the owners of any registered aerodrome within 4,000 metres from the proposed turbine locations and provide public notification to owners of unregistered aerodromes within 4,000 metres measured from the proposed turbine locations.
For major power plant applications, if there are populated areas just outside the 2,000-metre distance, applicants should consider including those areas in the personal notification.
Notice of project-specific information to postal code addresses is generally sufficient to satisfy this communication requirement. If the applicant considers that certain landowners that should be notified of the proposed project may be missed because they do not reside at the property, additional efforts to notify them should be considered.
Alternatively, notice of project-specific information to postal code addresses is sufficient to satisfy this communication requirement. If the applicant considers that certain landowners that should be notified of the proposed project may be missed because they do not reside at the property, additional efforts to notify them should be considered.
For clarity:
Table A1-2: Gas utility pipeline and pipeline installation consultation and notification requirements
In a rural or industrial setting, provide personal notification to occupants, residents, landowners, First Nation reserves, and Metis Settlements within 0.1 km of the pipeline.
In urban communities, provide personal notification to occupants, residents, landowners, First Nation reserves, and Metis Settlements within the first row of development on each side of the pipeline.
Confirmation of non-objection is required from occupants, residents, landowners, First Nation reserves, and Metis Settlements within the pipeline right-of-way
Provide personal notification to occupants, residents, landowners, First Nation reserves, and Metis Settlements within 0.2 km of the pipeline.
Confirmation of non-objection is required from occupants, residents, landowners, First Nation reserves, and Metis Settlements adjacent to the compressor station site.
Application is filed within 90 days of completing the discontinuation operation to advise the Commission of the discontinuation
It is an applicant’s responsibility to assess the area potentially impacted by the project and determine whether the distance of notification recommended in these guidelines should be altered to include a greater area. It may be necessary to change the distance to include stakeholders or Indigenous groups who have expressed an interest in development in the area. An applicant should explain the basis of its decision to change the distance of notification recommended in these guidelines in its application.
During the planning of its PIP, the applicant should assess its need for public notification to reach the broader public and determine whether an information session or public open house meeting is required. When holding such information sessions, the applicant must disclose the same project-specific information it would disclose to those individuals involved in personal consultation and notification.
The applicant must allow notified stakeholders and Indigenous groups a minimum of 14 calendar days to receive, consider and respond to the PIP for the proposed project prior to filing a facility application. The timeline for responses should be clearly stated in the PIP information as per Section 4.
In the case of a gas utility pipeline application, if an applicant has conducted personal consultation with every person in the applicable notification radius and obtained written confirmation of non-objection, the applicant may file an application once consultation is complete.
The applicant must make reasonable attempts to contact stakeholders and Indigenous groups, provide information about the project, discuss the project, and address any questions and concerns. If the applicant is unable to contact a stakeholder or Indigenous groups, it should be able to demonstrate reasonable attempts to establish contact.
The applicant is accountable for the outcomes of personal notification and consultation, including consultation and notification completed on its behalf by all personnel (including contracted personnel). Consequently, the applicant must ensure that individuals conducting personal notification and consultation:
The applicant must provide its project-specific information to those stakeholders and Indigenous groups described in the Who to include section, above. The required information may be made available electronically or forwarded by courier, mail, fax, email or other means as agreed upon by the applicant and stakeholders and Indigenous groups consulted.
Notification to Indigenous groups should be provided to the official consultation contact(s) on the Aboriginal Consultation Office website.
If the stakeholder or Indigenous group does not wish to receive the project-specific information or declines to consult with the applicant, the applicant must document the refusal for compliance audit purposes.
The applicant must keep a log containing information on the dates personal consultation occurred or was attempted, whether project information was provided, and to whom the project information was given.
6.1 Specific considerations for consultation
The applicant is expected to conduct one-on-one consultation with occupants, residents, landowners, and Indigenous groups as outlined in the Who to include section, above.
Where there is more than one landowner or occupant at an address, a consultation with one adult at that address will normally be sufficient, unless a request is made to meet with more than one landowner or occupant.
The applicant should use the method of consultation preferred by the occupant, resident, landowner, or Indigenous groups which could include face-to-face meetings, phone, email, or other electronic media.
Questions raised during discussions about the proposed project should alert the applicant to potential objections. The applicant should attempt to address concerns raised about the proposed project during consultation.
6.2 Consultation for projects on a First Nation reserve
For an application that crosses or is wholly located on a First Nation reserve the applicant is required to obtain the necessary consent and approvals from the First Nation and, if applicable, the federal government. The applicant must notify the Chief and Council, and the lands office (if applicable) about the project, seek direction on the consultation and notification requirements, and obtain any federal land tenure that may be required for the project (i.e. Indian Act, First Nation Land Management Act, or other applicable legislation).
The applicant is expected to make reasonable attempts to update stakeholders on material changes to the project, even if the application is withdrawn. Stakeholders and Indigenous groups included in the PIP should continue to be included in correspondence and information updates, except in cases where:
When a change in circumstances does not allow previous commitments to stakeholders or Indigenous groups to be met, the Commission expects the applicant to provide notification to all stakeholders or Indigenous groups impacted by the change in circumstances.
In some instances occupants, residents and landowners may be away for extended periods, such as on vacation, or they may reside out of the province. An applicant is expected to attempt to contact these stakeholders and Indigenous groups regardless of these extended absences.
When the applicant is expected to consult with stakeholders and Indigenous groups but is unable to do so, it is expected to send letters and project information to the address indicated on the most up-to-date land title documents.
If the applicant is unable to fulfill all PIP requirements, it must explain the efforts made to contact all necessary stakeholders and Indigenous groups.
The applicant should document its PIP, including the elements specified in Section 3 and it should include all information provided and received through the notification and consultation process. The applicant is required to retain communications logs, including any registered mail and courier tracking information, to record feedback and objections received prior to filing an application and the applicant’s responses and follow up to resolve objections. The applicant is also required to document commitments made during its PIP and have a process in place to monitor and follow up on those commitments.
When submitting an application, the applicant must include a written summary of any unresolved objections, its responses and its follow-up to these objections. Documentation may be requested in the event of a compliance audit.
Information requirements throughout this rule require a list of contact information for all persons who were contacted as part of the PIP in a Microsoft Excel spreadsheet with columns for name, company or organization name, address 1, address 2, city, province, postal code, country and optional email address, as shown below. An email address is to be provided if a person indicates that they would prefer to be communicated with via email rather than mail.
Table A1-3: Requirements for contact information
The AUC has the authority to consider and address potential adverse impacts to Aboriginal and treaty rights as set out in Section 35 of the Constitution Act, 1982, when deciding whether approval of an electric facility or gas utility project is in the public interest. The Commission is committed to ensuring that Indigenous groups whose constitutionally protected rights may be directly and adversely affected by development have the opportunity to have their concerns heard, considered, understood and accommodated (if required).
These guidelines list the factors that an applicant should consider when creating its participant involvement program (PIP) for Indigenous groups. It is designed to augment the guidelines for the PIP in Appendix A1 by providing additional guidance to applicants on consultation with Indigenous groups.
Project applicants are responsible for discussing the project with Indigenous groups, understanding their concerns, and exploring accommodation measures where those are needed or recommended to avoid, minimize or mitigate adverse impacts on Section 35 rights. It is helpful for the Indigenous groups to be notified early in project planning to provide sufficient time for relationship building, issue identification and mitigation exploration.
If resolution of concerns is not possible applicants are responsible for providing the AUC with the record of the consultation that was undertaken, including a summary of any objections received, mitigations discussed, and any outstanding objections.
The Commission requires an applicant to inform the Indigenous groups of, and involve them in discussions about, the applicant’s project if there is a potential for that project to impact Section 35 rights. The applicant must specifically address this as part of the PIP and identify the Indigenous groups it consulted. Section 35 rights may be practiced on unoccupied Crown land and other lands to which the members of an Indigenous group have a right of access for such purposes.
2.1 When should Indigenous groups be included in the PIP?
The following planning tool was developed to assist applicants in determining whether they should include Indigenous groups in the participant involvement program.
The Commission has identified three Indigenous consultation categories to improve regulatory consistency, predictable decision-making, and public transparency. The three categories are based on knowledge of the potential physical impacts of a project on land or resources that could affect Section 35 rights. However, they are not a definitive categorization of all potential adverse impacts on Section 35 rights and other credibly asserted or apparent impacts must also be considered. In the event that an application has characteristics that fall into two or more categories, the more stringent notification requirements should be followed.
Category A projects: Crown has determined there is a duty to consult or there are reserve or settlement lands within the consultation radii
AUC applications for which the government of Alberta requires consultation on related approvals:
Additionally, the consultation radii for an application, as identified in Rule 007 [Table A1-1], may include lands set aside for or owned by an Indigenous group (i.e., First Nation reserve or Metis Settlement). In that case, the First Nation or Metis Settlement must be included in the PIP and given AUC notice, regardless of whether the government of Alberta has required consultation in respect of a different approval.
Category B projects: Small projects, projects on private land with little or no off-site impacts, or administrative changes
Applications that do not ordinarily require the Indigenous groups to be included in the participant involvement program:
If an Indigenous group contacts the applicant and requests consultation the applicant should include the Indigenous group in the PIP or provide an explanation why it declined to do so.
Category C projects: Projects requiring further analysis
Projects that are not in Category A or Category B will be reviewed by the Commission on a case-by-case basis using the following questions as a guide. Applicants may request pre-application feedback from AUC staff on the participant involvement for Indigenous groups, including determining the most suitable project category.
Please use the Request for AUC staff feedback on participant involvement program for Indigenous group form to request pre-application feedback from AUC staff on the participant involvement for Indigenous groups.
In reviewing Category C applications to determine if Indigenous groups should be included in the participant involvement program, the AUC considers the nature, scope, magnitude and duration of the potential adverse impacts on Section 35 rights. Some questions that the Commission considers during the assessment of Category C projects include, but are not limited to, the following:
The following table (Table A1-4) is a quick reference for the consultation categories.
Table A1-4: Quick reference – Indigenous consultation framework
and/or
A First Nation reserve or Metis Settlement is within the consultation areas (Notification radius right).
First Nations or Metis Settlements with reserves or Settlements within the consultation area must be included in the PIP.
2.2 Which Indigenous groups should be included in the participant involvement program?
If a First Nation reserve or Metis Settlement is located within the consultation radii for an application, as identified in Appendix A1 of Rule 007, then the First Nation or Metis Settlement must be included in the PIP.
If the government of Alberta, through the Alberta Consultation Office (ACO) or otherwise, directed consultation with any Indigenous groups for related approvals (i.e., Public Lands Act, Water Act, Environmental Protection and Enhancement Act, Historical Resources Act, Government Organization Act, etc.), the applicant must include those Indigenous groups in the PIP for the AUC application.
If advice from the government of Alberta on consultation was not sought by the applicant, the applicant must summarize the steps it took to identify and consult with Indigenous groups. Applicants are encouraged to use the government of Alberta’s Landscape Analysis Indigenous Relations Tool (LAIRT) to inform their decisions about consultation. If no steps were undertaken to identify and consult with Indigenous groups, the applicant must provide an explanation.
The applicant must indicate if Indigenous groups were included the PIP. If so, the applicant must include a summary of the consultation undertaken including a description of the unresolved objections that it is aware of, and its responses and follow-up to these objections.
Notification to Indigenous groups should be provided to the official consultation contact(s) and by the method identified on the Aboriginal Consultation Office website.
It is helpful for the Indigenous groups to be notified early in project planning to provide sufficient time for relationship building, issue identification and mitigation exploration.
The applicant must retain documentation of potential mitigation measures for objections that were identified or considered through the notification and consultation process prior to filing an application.
The applicant is expected to document all commitments made during its PIP and have a process in place to monitor and follow up on those commitments.
The applicant is accountable for the outcomes of consultation, including consultation completed on its behalf by all personnel (including contracted personnel). Consequently, the applicant must ensure that individuals conducting consultation:
Applicants are encouraged to consider options to avoid, minimize, or mitigate impacts on Section 35 rights identified during consultation with Indigenous groups. Exploration of these concerns should be documented thoroughly in the consultation record.
Efforts to accommodate concerns may include:
The applicant must keep a log containing information on the dates notification occurred or was attempted, whether project information was provided, and to whom the project information was given, as well as any follow-up discussions.
1 Purpose of the ISO stakeholder notification
Prior to submitting a needs identification document application or an abbreviated needs identification document application to the Commission, the ISO must notify stakeholders and Indigenous groups in the area where the ISO has reasonably determined that facilities could be installed to implement the ISO’s preferred option to meet the need.
2 Content of the ISO stakeholder notification
For each application, the ISO will develop a notification approach that best aligns with the project size and location and will notify stakeholders and Indigenous groups in accordance with this approach. The ISO will explain the basis for its approach when filing a needs identification document application or an abbreviated needs identification document application with the Commission.
The ISO is not required to initiate consultation with stakeholders and Indigenous groups.
3 Responding to questions and concerns
The ISO must be prepared to respond to questions and concerns from stakeholders and Indigenous groups regarding a needs identification document application or an abbreviated needs identification document application.
4 Changes to the ISO notification
If the ISO revises the information provided in a notification following the ISO’s issuance of a notification, the ISO must notify stakeholders and Indigenous groups of those changes.
In the event that the ISO decides not to proceed with a needs identification document application or an abbreviated needs identification document application for which a notification has been distributed, the ISO must notify stakeholders and Indigenous groups of this decision.
Table B1: Economic comparison requirement for ISD9
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