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Questions and answers for 2025 Call for Power

Answers to questions on the 2025 Call for Power Request for Proposals (RFP), RFP process, and related documents issued during the call process are posted on this page. The deadline to submit questions was December 3, 2025.

Questions and answers provided are subject to the terms and conditions outlined in the 2025 Call for Power RFP and are for general information only. They do not constitute legal or other advice and do not amend or form part of the RFP, unless confirmed by Addendum or revised RFP documents. Should there be any differences between the responses on this page and the RFP or Specimen Electricity Purchase Agreement (EPA) issued by BC Hydro when the Call for Power is launched or subsequently updated, the RFP and the Specimen EPA shall prevail.

Answers to questions will be added regularly.
 

December 19, 2025

131. Why didn't BC Hydro consider alternatives to the Addendum 5 regarding NCTL projects, and how are Proponents expected to be able to secure financing?

We considered a number of options once we learned that new projects in the North Coast region would have to be contingent on the NCTL Project proceeding. Our intent is to balance protection for the IPP and BC Hydro ratepayers, while still keeping a door open for these projects in the 2025 Call.

Potential Proponents should note that BC Hydro would return the Performance Security of $60,000/MW if BC Hydro terminates the EPA before the NCTL Project Approval Decision or after the NCTL Project Approval Decision. After the NCTL Project Approval Decision, BC Hydro would only terminate if BC Hydro determines that it would not be possible, using commercially reasonable efforts, for the NCTL Project to be operational and come into service prior to the Seller's Guaranteed COD. BC Hydro only keeps the Performance Security if BC Hydro has made a decision to proceed with the NCTL Project and the Seller decides to terminate the EPA. Potential Proponents should review section 2.2 of the Specimen EPA for further detail.

BC Hydro also moved the Guaranteed COD for projects in the North Coast region to the latest date of Oct 1, 2033 to allow developers to see the progress of the NCTL Project and advance development of their project accordingly. For example, the later Guaranteed COD allows for some visibility on the progress on the NCTL Project as projects advance their permitting. Financing is typically completed when the project obtains their permits.

130. In cases where a project bidding in the BC Hydro 2025 Call for Power desires to share ownership of interconnection related equipment and/or POI's with existing projects or 2024 Call for Power awarded projects, how would BC Hydro treat a co-ownership of such shared interconnection facilities?

In such co-ownership situations would BC Hydro require a tri-party interconnection agreement with all three entities and would BC Hydro make any necessary amendments to the 2025 Call for Power form EPA for the bid project and the 2024 Call for Power for the existing projects to permit such co-ownership of certain assets of the respective Seller Plants? (as opposed to the contractual right to use / wheeling language in the 2025 Call for Power form EPA).

In the case where a Successful Proponent in the BC Hydro 2025 Call for Power co-owns the interconnections facilities up to the POI, then, at a minimum, changes will be required to:

  • BC Hydro 2024 Call for Power EPA with the existing project;
  • BC Hydro 2025 Call for Power EPA with the new project;
  • Standard Generator Interconnection Agreement (SGIA), all to reflect co-ownership of the subject facilities as well as amendments to ensure that BC Hydro is kept in the same position had it been if not for the co-ownership. Changes would be similar to those contemplated with an indirect interconnection: the SGIA would be amongst both project entities and BC Hydro.

129. If an RAS is deemed "filled", will new generation be allowed to interconnect as energy only or will new generation not be allowed to interconnect pending required transmission system reinforcements?

Generation restrictions implemented to avoid network upgrades are not Remedial Action Schemes, RAS, even if the generation restriction is automated since they are applicable under system normal without any elements out of service. Local protection and remedial action schemes may still be required to cover generation shedding or curtailment under system contingencies. New generation added to a region with generation restrictions and ERIS-connected resources in place will require a study to determine network upgrades required for its interconnection. A project can connect to the BC Hydro system only after all necessary network upgrades are complete and the project completes the necessary commissioning steps.

128. If a Project connects under ERIS as outlined in the EPA Interconnection Service Side Letter, will it have its NRIS access re-established after the network upgrades are completed? Will such a project have priority transmission access ahead of other potential ERIS projects behind it in the interconnection queue?

If BC Hydro completes the required network upgrades that remove transmission constraints for a project initially designated as ERIS, BC Hydro may re-establish the project as a NRIS resource. Generation curtailments for such a project would continue in accordance with the provisions of the EPA. If the required network upgrades are built, it is expected that generation restrictions would occur less frequently.

127. Will a NRIS resource receive priority dispatch, meaning BC Hydro will first curtail ERIS resources when curtailment is required to mitigate a transmission or system constraint?

Projects, whether interconnected under ERIS or NRIS, will be dispatched in accordance with the provisions of their EPAs. The EPAs allow for maximum generation restrictions to be applied for various reasons irrespective of the interconnection type. Where projects are interconnected under ERIS so to avoid network upgrades, it is expected that generation restrictions will occur more frequently with those projects.

126. When will the proponent receive interconnection security back?

Security collected for Network Upgrades will be returned to the customer according to the formula in the OATT, Attachment O (Recovery of New Facilities Costs).

125. For projects located within the NCTL Region, when is this interconnection security payment due? For projects located outside the NCTL Region, when is the interconnection security expected to be due?

The timing of security requirements will vary depending on factors such as how long the Interconnection Request implementation would take, and whether implementation activities must be accelerated to meet the in-service date. It does not depend on the region.

124. Is the required interconnection security staged? How is the interconnection staged security amount determined?

The interconnection security requirement for Network Upgrades may be staged. The staged security schedule is project-specific and based on forecasted cash flows and BC Hydro’s commitment amounts for a discrete portion of the Network Upgrades; there are no predetermined percentages. Interconnection Customers must provide sufficient security to cover the cash flow and commitment amounts, such as the full value of contracts or costs of ordered equipment.

123. How is the interconnection security amount determined? Is it 100% of estimated Network Upgrades cost, or a portion of it?

Under the Open Access Transmission Tariff (OATT), Attachment M-1, Appendix 5 (Standard Generator Interconnection Agreement), Section 11.5 (Provision of Security), the requirements for providing security are detailed. The Interconnection Customer must provide security equal to 100% of the estimated Network Upgrades cost quoted in the Standard Generator Interconnection Agreement (SGIA).

This security is required at least 30 days prior to initiating implementation of a discrete scope of work for the Network Upgrades.

If certain activities, such as detailed engineering or procurement of long-lead equipment, need to be accelerated to meet the Interconnection Customer’s requested in-service date, BC Hydro and the Interconnection Customer may execute an early Engineering and Procurement Agreement to collect security prior to the execution of a Standard Generator Interconnection Agreement; details of this are located in the OATT, Attachment M-1, Section 9.0 (Engineering and Procurement (E&P) Agreement).

122. Please confirm whether electing ERIS at BC Hydro's direction will impact our current interconnection queue position.

An election under the Open Access Transmission Tariff (OATT) M-1 to change from NRIS to ERIS does not affect a Proponent’s position in the interconnection queue. Please note that an election to be studied as ERIS under the OATT needs to be submitted before the Proponent confirms its decision to proceed with the Facilities Study.

121. If the NCTL adds transmission capacity to the North Coast region, will BC Hydro's load and generation modelling (for CEAP or otherwise) consider both scenarios: one where the NCTL is in service and one where it is not?

As outlined in Addendum 5, the development of Phase 1, and possibly Phase 2, of the NCTL Project will most likely be required to enable any Proponent Project located within the NCTL Project region to interconnect and deliver Energy to the BC Hydro System. As a result, BC Hydro has assumed, for the purposes of the Interconnection Feasibility Study under CEAP, that both Phases of the NCTL would be in service. For load forecasting, BC Hydro used the latest reference forecast.

120. The SGIA requires a Security for the Interconnecting Facilities 30 days prior to the starting of design, procurement, and construction. We have two questions:

  • (i) What is the basis for the amount of the Security? Is it the full Feasibility Study cost estimate, or the full Facility study estimated cost, a prorated value that increases over the various development stages of the project (regulatory costs, design costs, procurement costs and construction and commissioning costs) or some other basis? Is the security capped at the actual cost of the interconnection?
  • (ii) How is the post COD duration of the security determined? Is the full EPA revenue applied, or just a portion or some other method?

We interpret this question as pertaining to the security requirements outlined in the Standard Generator Interconnection Agreement. Based on that interpretation, please see the clarification below:

  • (i) The customer is required to provide security for the Network Upgrades cost identified after the Interconnection Facilities Study and quoted in the Standard Generator Interconnection Agreement (SGIA), as per BC Hydro's Open Access Transmission Tariff (OATT), Attachment M-1, Appendix 5, Section 11.5 - Provision of Security. While a good-faith estimate of Network Upgrades is provided in the Interconnection Feasibility Study, this estimate is refined through subsequent Interconnection Studies, including the Interconnection System Impact Study and Interconnection Facilities Study.
  • (ii) The security requirement may be staged based on project cash flow and BC Hydro's commitment amounts, and is capped at the actual cost of the Network Upgrades. Please note that the Interconnection Customer may be required to provide security prior to SGIA execution if certain implementation activities such as engineering or procurement of long-lead equipment must be accelerated to meet the in-service date; this would be governed under an Engineering and Procurement Agreement, as per the OATT's Attachment M-1, Section 9 - Engineering and Procurement (E&P) Agreement.

The timing and release of interconnection security are governed by BC Hydro's OATT Attachment O.

119. In Schedule 3 Section 3.2, would a letter provided by external legal counsel attesting Project site control be sufficient documentation to evidence site access/control for private properties?

Schedule 3, Section 3.2 requires Proponents to demonstrate that they have obtained, or have a plan to obtain, access/control of all properties on the Project site (including transmission facilities) as required to build, maintain, and operate the Project over the Term of the EPA.

The intent of this requirement is to understand the extent to which Proponents have secured, or have a robust plan to secure, the necessary rights to the Project site to enable timely development and operation of the Project.

For further details, we encourage each Proponent to seek independent legal and technical advice in preparing its submission as may be necessary.

December 11, 2025

118. For projects intending to connect via Third Party System we are seeking clarification regarding the timing requirements for the execution of the Third Party Interconnection Agreement (TPIA) under the current Electricity Purchase Agreement (EPA). Section 5.2 of the EPA states that the Third Party Interconnection Agreement must be in place and effective by the start of commercial operations. However, Seller representations in Section 17.1 require a representation by the Seller that the agreement is already in place at the Effective Date.

Can BC Hydro clarify when it would expect the TPIA to be executed?

The EPA does not require the Seller to have such arrangements in place as of Effective Date but that to the extent that there are such arrangements in place, such arrangements must satisfy the requirements of s. 17(1)(j). All such arrangements must be in place by COD (s. 5.2(e)).

117. Please advise if BC Hydro would require Forest Fire Fighting Expense Liability for projects located on private agricultural lands?

Yes, BC Hydro would require Forest Fire Fighting Expense Liability for projects located on private agricultural lands.

116. We recognize that under Specimen EPA Section 15.4(a), BC Hydro retains the right to withhold consent to any pre-COD Assignment (Change of Control) of the Seller in its sole discretion.

  • (i) Would documented evidence proving the assignee's full capacity, experience (as defined by the requirements in RFP Schedule 3), and financial viability (as defined by the requirements in RFP Schedule 5, including providing evidence via Form 6) satisfy the necessary due diligence and background check requirements (Section 11.3)?
  • (ii) Assuming compliance with the ROFR process, in what circumstances would BC Hydro not provide consent to a pre-COD Assignment?

BC Hydro reserves the right to withhold consent at its own discretion for any pre-COD assignment. Decisions will be made on a project-specific basis at the time of assignment.

115. We make reference to subsections 7.10 (d) and 7.10 (e) of the Specimen EPA and the EPA Interconnection Service Side Letter dated November 20, 2025 (the "Side Letter"). BC Hydro has stated it will pay for deemed energy when generation is constrained solely due to the change to ERIS (where the Seller previous had Identified NU). The Side Letter states that "any Energy curtailed pursuant to a Curtailment Request issued for reasons solely attributable to not constructing the Identified Network Upgrade will be considered Turn-Down Energy under the terms of the EPA".

For clarity, does BC Hydro intends that any such curtailed energy would be compensated pursuant to subsection 7.10 (d)?

Confirmed. BC Hydro intends that any such curtailed energy would be compensated pursuant to subsection 7.10 (d).

114. Are there specific requirements regarding who must submit the bid security and the proposal? Must the project entity submitting the proposal be the same entity that posts the Letter of Credit for the bid security, or may another entity provide the bid security on the Proponent's behalf?

If the Proponent is submitting a Letter of Credit as bid security, the applicant on the Letter of Credit may be another entity submitting on behalf of the Proponent.

113. Reference is made to Schedule 9 (EPA Interconnection Service Side Letter), specifically Section 2 ('Treatment of Curtailed Energy'), which states that energy curtailed due to a directed switch to Energy Resource Interconnection Service (ERIS) will be considered 'Turn-Down Energy' under the EPA.

Please clarify:
Does this specific 'ERIS-driven' Turn-Down Energy count towards the standard Annual Turn-Down Energy Quantity (ATEQ) or any other compensable curtailment caps defined in the EPA?

If this curtailment causes the project to exceed its Annual Turn-Down Energy limit, will the excess curtailment continue to be compensated at the Energy Price, or does it revert to unpaid curtailment (or 'incidental' curtailment)?

Given that the Proponent has no control over the timeline of Network Upgrades, is there a specific 'floor' or guarantee that protects the Seller from unlimited unpaid curtailment if the required Network Upgrades are never completed?

There is no Annual Turn-Down Energy Quantity (ATEQ) or any other compensable curtailment caps defined in the BC Hydro's 2025 Call for Power Schedule 7 Specimen EPA.

December 1, 2025

112. Although a copy of the agreement (e.g. MOU or term sheet) is not required as part of Form 5, will this be critical evidence to support Schedule 4 submission and proponent receiving additional credit overall?

The Proponent is welcome to submit a copy of the agreement if the Proponent feels this is critical evidence to support Schedule 4 submission; however, this is not a mandatory requirement as part of Form 5.

111. What is the difference between 6.4 Principal Equipment Procurement Plan and 6.6 Major Equipment Procurement Plan? Is the only requirement of the Principal Equipment Procurement Plan to ensure that the capital cost estimate identified in 6.3 Project Budget aligns with the amount provided in Schedule 5?

Section 6.4 Principal Equipment Procurement Plan is no longer used. Please refer to Addendum 6 and the revised Schedule 3.

Per Section 6.3 Proponents should ensure that the expected Project cost is aligned with the amount provided in Schedule 5 – Financial Information Requirements.

110. In Schedule 3 Section 3.4, the Project site diagram should show key site features including "third party infrastructure, as applicable". Would oil and gas leases and right-of-ways need to be included in the Project site diagram?

Yes. Oil and gas leases and rights-of-way should be included in the Project site diagram under "third party infrastructure."

The purpose of this requirement is to ensure BC Hydro has full visibility of any external constraints or assets that could affect project development, construction, or interconnection. Proponents should include as much detail as possible.

109. In Schedule 5 Section 2, should CIB funding be classified as debt in the Capital Structure of the financing plan?

In Schedule 5, Section 2, CIB funding should be classified based on how Proponents receives funding from CIB:

  • If a Proponent receives funding from CIB as a loan, it should be included under debt in the capital structure and CIB noted as the debt provider.
  • If a Proponent receives funding from CIB to support their equity component, then it should be listed as an equity source and CIB noted as an equity provider.

The classification depends on the structure and terms of the CIB contribution as described by the Proponent.

108. Can BC Hydro please confirm that the equity letters can equal more than 100% of the expected project CapEx?

Confirmed, provided that the Financial Commitment Letter meets the requirement as per Schedule 5.

107. Could BC Hydro please confirm whether the Bid Security amount of $25,000/MW represents a minimum requirement? Additionally, would a Proponent be disqualified or otherwise penalized during evaluation if the Letter of Credit submitted exceeds $25,000/MW?

Please note that Addendum 8 has been issued to provide clarification. Specifically, refer to Subject C of Addendum 8: "Bid Security must be provided in the form of a Letter of Credit and in the amount of at least $25,000 per MW of Plant Capacity as specified in the Proponent's Commercial Proposal."

106. If BC Hydro:

1. decides not to go forward with the NCTL before selecting preferred proponents; or

2. determines that NCTL In-Service Date will not meet the required Guaranteed COD of October 31, 2033, after the Proposal Withdrawal Deadline has passed, but before selecting Preferred Proponents, will the proponents who would be affected by Addendum 5 be permitted to withdraw their proposal and receive the Bid Security back?

Addendum 5 notes that proposed Projects in the North Coast Transmission Line Region may be dependent on the North Coast Transmission Line (NCTL) Phase 1 and/or Phase 2 to interconnect into the BC Hydro Transmission System.

If a decision is made before EPA award not to proceed with the development of Phase 1 (and as applicable, Phase 2) of the NCTL Project, then any proposal with respect to an NCTL Phase 1 Plant or NCTL Phase 2 Plant will not be awarded an EPA, and in accordance with Section 7.3 of the RFP, Bid Security will be returned.

105. The EPA states that if BC Hydro:

1. decides not to go forward with the NCTL; or

2. determines that NCTL In-Service Date will not meet the required Guaranteed COD of October 31, 2033,

BC Hydro "may" terminate the EPA, and if so, must return the Performance Security.

Can you confirm whether BC Hydro will exercise this termination right if either of the above scenarios occur? If not, will the EPA be amended to allow the Proponent to terminate the EPA in this circumstance without incurring a termination payment?

BC Hydro cannot confirm whether it will exercise its termination rights under section 2.2, as this will depend on the circumstances at the time such scenarios arise. The EPA will not be amended. Under the terms of the EPA, the proponent is required to pay a termination payment only if the Seller elects to terminate the agreement after BC Hydro's board has made an NCTL Project Approval Decision.

104. If BC Hydro cancels the NCTL project or determines that its in-service date will not meet the Guaranteed COD of October 31, 2033, after the proponent has invested significant resources in developing or constructing its project, can the proponent recover any costs from BC Hydro?

The NCTL provisions are designed to provide proponents with flexibility by allowing a later Guaranteed COD, enabling greater certainty regarding the timing of the NCTL In-Service Date. Proponents should carefully assess the schedule risks associated with NCTL when planning their projects and making financial commitments. BC Hydro will not assume responsibility for any monetary damages or financial liability in the event that the NCTL project is cancelled, suspended, or delayed.

103. If, after selecting Preferred Proponents, BC Hydro determines that the BC Hydro System can support the increase in power obtained under the 2025 Call for Power without the Phase 1 and/or Phase 2 of the NCTL, will BC Hydro consider removing Addendum 5 from the EPA?

If after contract award, BC Hydro determines that a 2025 Call for Power project in the North Coast region can be interconnected and deliver Energy to the BC Hydro System without the NCTL Project, BC Hydro may consider amending the NCTL provisions under section 2.2 of the EPA.

102. If BC Hydro cancels the NCTL project or the in-service date is delayed beyond October 31, 2033 and the EPA ends, will the affected proponent get priority in future power calls?

BC Hydro cannot provide a proponent with priority or preference in future calls for power.

101. Will BC Hydro be considering changes to the termination provisions regarding North Coast projects given the recent funding announcement by the Federal government and Canada Infrastructure Bank?

BC Hydro is not considering changes to the provisions.

100. Schedule 2 states that the Bid Price should be in 2025 Canadian $/MWh. In the EPA Appendix C 3.(b) the Bid Price is adjusted by a factor of (CPI_Y/CPI_Jan 1, 2024). Could you confirm if the EPA price formula will be adjusted based on 2025?

Please note that the Energy Price under the EPA has been amended under Addendum 8 to escalate based on 2025 base year.

99. The Owners of the Seller are required to be parties to the EPA. The EPA implies, but that does expressly state, that only the persons that hold a direct legal or beneficial interest in the Seller are the 'Owners' for purposes of the EPA.

Can BC Hydro confirm that only persons that hold a direct legal or beneficial interest in the Seller (but not upstream owners of such persons) are expected to execute the EPA? For example, in a scenario where Seller is owned by Person 1, Person 1 is owned by Person 2 and Person 2 is owned by Person 3, only Person 1 would be an Owner for purposes of the EPA.

Confirmed.

98. Can BC Hydro please confirm if a Proponent is required to resubmit the Registration Form either 5 Business Days prior to the bid submission or along with the bid submission if the Proponent is changing to the Project entity, which was not established at the time of registration? For clarity, the primary contact will not be changing.

If a Proponent changes the Project Entity for the proposal submission but the Primary Contact remains the same as originally registered in Schedule 1, resubmission of Schedule 1 is not required.

Prior to the RFP Close, resubmission of Schedule 1 is required for any changes to your Registration information, in particular any changes to Primary Contact information as the Primary Contact is used for Sourcing Extranet credentials and communication updates.

On and after the RFP Closing Date, BC Hydro will communicate with Proponents using the Proposal Contact listed in Schedule 2. Please ensure Schedule 2 contains the most up-to-date information as part of your bid submission.

Refer to Q&A #29 from the October 23 Information Session notes for additional context.

97. If a Proponent is directed to switch to ERIS, please confirm that a Curtailment Request issued for reasons solely attributable to not constructing the identified Network Upgrades (NU) will not be considered a BC Hydro System Constraint, and as such the first 24 hours of curtailment will not be excluded from the total Turn-Down Energy.

Confirmed.

96. Please clarify that BC Hydro's direction to switch from NRIS to ERIS under the Interconnection Service Side Letter does not affect any other project parameters, including the Point of Interconnection and project capacity, as defined in the EPA.

BC Hydro's direction to switch from NRIS to ERIS under the Interconnection Service Side Letter does not impact the project parameters under the EPA including Point of Interconnection or Plant Capacity, as defined in the EPA.

95. Following the Canadian government's November 26, 2025 announcement of a new 25% global tariff on steel and related products, including wind towers, can BC Hydro confirm which tariffs proponents are required to account for in their bids?

The bids need to contemplate any Tariffs that are in effect at RFP Closing Date.

November 26, 2025

94. Can BC Hydro provide an example of how to complete the Tariff Adjustment Major Component Reporting Form in Appendix O and calculate the Tariff Energy Price Impact?

Please see the document: Sample Completed Tariff Adjustment Major Component Reporting Form and sample calculation of the Tariff Energy Price Impact. This can be found on the Call for Power Documents page, in the Reference Information section.

93. Based on Slide 27 of 2025 Call for Power Informational Meeting presentation: Proponents that permit their projects through BCER (or previously through the EAO) have the same delegation of procedural aspects of consultation. Why is BCH independently determining the adequacy of consultation? Does BCH have additional or different obligations (or metrics) as compared to other Crown agencies?

There are two different decisions by two different Crown decision-makers. BC Hydro is assessing the incremental impacts to Aboriginal rights and title, and treaty rights, of our decision to enter into an EPA with the proponent for the project. The British Columbia Energy Regulator is assessing the incremental impacts of their decision with respect to the Crown authorizations required for that project.

Each decision-maker must assess consultation based on the impacts of its own decision. BC Hydro's assessment does not replace or duplicate BCER's assessment, and vice-versa. The obligations are parallel, not additional.

92. Will there be any flexibility to change the proponent entity or project structure between proposal submission and EPA execution, if needed?

Please review the Section 8.6 of the RFP that outlines the Proponents' Obligation to Inform of Material Changes.

91. Per BC Hydro's 2025 Call for Power Engagement Summary Report, under RFP Key Terms, Forms and Schedules (pg 15), BC Hydro indicated that changes were made to the 2025 Call for Power to allow more time for EPA execution.

Please refer to Addendum 6.

90. I have questions about the Transmission System Information document and how it applies to my project. How can I get assistance?

Proponents that are interested in connecting to the BC Hydro Transmission system should review Transmission Generator Interconnections about ways to request an interconnection study. The 2025 CEAP process key deadlines have now passed.

89. Would BC Hydro consider releasing or reducing a proponent's bid security if a First Nation decides not to proceed with a proposed project, for example, following a community plebiscite?

As per Section 7.3 of the RFP, Bid Security is returned to Proponents if:

  • (i) the Project is not awarded an EPA;
  • (ii) BC Hydro cancels the RFP;
  • (iii) 180 days have passed since the Closing Date.

In addition, submitted Proposals withdrawn prior to the Closing Time or, after the Closing Time, withdrawn prior to the Proposal Withdrawal Deadline will have their Bid Security returned.

Bid Security will be fully forfeited if a Proponent withdraws its Proposal after the Proposal Withdrawal Deadline or fails to execute and return the EPA (and associated documents and performance security) in accordance with Section 12.1 of the RFP after being selected as a Preferred Proponent.

88. Will BC Hydro consider extending the submission deadline to January 16th to provide time after the holidays to finalize submissions?

We are unable to make any changes to the RFP closing date of 11:00 a.m. Pacific Time on January 5, 2026.

On December 8, 2025, BC Hydro extended the 2025 Call for Power RFP Closing Date. See Addendum 9 [PDF, 138 KB].

87. Will Addendum 5, or similar, be included in future Calls for Power?

Future Calls for Power will be structured to reflect BC Hydro's needs at the time.

86. Will BC Hydro be responsible for and retain all aspects of the consultation related to constructing the necessary upgrades to the BC Hydro transmission network to interconnect projects that have been awarded an EPA?

BC Hydro will be responsible for and retain the associated consultation requirements associated with the Transmission system upgrades required on the BC Hydro side of the Point of Interconnection (Network Upgrades).

November 20, 2025

85. Why is BC Hydro issuing a new EPA Interconnection Service Side Letter requiring that Preferred Proponents awarded an EPA agree to modify their Interconnection Request to be studied for Energy Resource Interconnection Service (“ERIS”) if directed?

There are two types of Interconnection Service: Energy Resource Interconnection Service (ERIS) in OATT Section 1.12.1, and Network Resource Interconnection Service (NRIS) in OATT Section 1.26.1.

BC Hydro is requiring Preferred Proponents awarded an EPA to agree to modify their Interconnection Request to ERIS if requested by BC Hydro because in some cases, the use of ERIS can reduce the interconnection costs to BC Hydro, and by extension, the Seller and BC Hydro’s ratepayers.

84. Who is Schedule 9 applicable to and when is it required?

All 2025 Call for Power Preferred Proponents will be subject to signing Schedule 9, however, whether BC Hydro directs a Preferred Proponent to interconnect under ERIS will be a project-specific decision that will be made post EPA Award, as projects proceed under the Standard Generator Interconnection Procedures.

A signed agreement letter is required from Preferred Proponents at the time of EPA execution. Please see Addendum 7 and Schedule 9.

83. How does the EPA Interconnection Service Side Letter impact my project?

BC Hydro will pay for deemed energy when generation is constrained solely due to the change. Furthermore, under the Open Access Transmission Tariff, the Successful Participant is responsible for all interconnection studies costs associated with their project. While switching from Network Resource Interconnection Service (NRIS) to Energy Resource Interconnection Service (ERIS) or studying them concurrently may increase the System Impact Study costs, it will, in turn, reduce the overall Facilities Study costs. Additionally, as certain Network Upgrades could be avoided, the security requirements for the Seller under the Standard Generator Interconnection Agreement could decrease. As a result, the overall cost of interconnection studies is not expected to increase when moving from NRIS and ERIS, and there is a strong potential for overall interconnection cost savings for both BC Hydro and the Successful Participant.

November 14, 2025

82. Under Schedule 3 – Project Information Requirements, Section 6.10 states that "the Proponent has notified the public in the local community where the Project will be located of its intention to develop the Project". Can BC Hydro confirm if an advertisement in the local newspaper would be sufficient to meet the public notification requirement? If not, can BC Hydro elaborate on what would be an acceptable public notification?

BC Hydro is seeking to understand what efforts, and the status of such efforts, the Proponent has taken to consult with the local community where the Project will be located.

Please refer to the second paragraph of Schedule 3 Section 6.10 that details the information that is requested as evidence of community consultation.

Proponents are responsible for assessing the extent and requirements of community consultation requirements and we encourage you to consult your own technical, financial, and legal experts to inform your bid assumptions.

81. In Schedule 3, Section 6.10 (Community Consultation), it states "the Proponent has notified the public in the local community where the Project will be located of its intention to develop the Project and has a viable plan to provide adequate information on the Project to the public in that community, and a reasonable opportunity for members of the community to provide a response to that information."

Could BC Hydro clarify whether community members must be provided an actual opportunity to respond prior to bid submission, or if it is sufficient that this opportunity is outlined as part of the consultation plan?

BC Hydro is seeking to understand what efforts, and the status of such efforts, the Proponent has taken to consult with the local community where the Project will be located. The second paragraph of Schedule 3 Section 6.10 details the information that is requested as evidence of community consultation.

80. Can you confirm that a submission will include a $25k security payment. However if accepted this then gets turned into a $60K performance payment. In reality this means paying an additional $35k payment required for successful projects?

A submission must include a Bid Security of $25,000 per MW of Plant Capacity. If the Proposal is accepted and the Proponent is selected as a Preferred Proponent, this Bid Security may be amended to become the Performance Security, which is $60,000 per MW.

In effect, this means an additional $35,000 per MW is required as Performance Security for successful projects.

79. If awarded a Canadian Content Price Adder, will this amount be applied to every MWh generated over the entire 30 year EPA contract?

Yes.

78. Could BC Hydro clarify what qualifies as an outage event as referenced in the Schedule 3 RFP document in the following sections:

Section 2.1: "Provide annual and monthly energy estimates that represent the net energy delivered to the POI excluding all outages in GWh"

Section 2.3: "Description of loss assumption and annual planned outage factor (%)"

Outages referred to in Schedule 3 Section 2.1 and 2.3 refer to Planned Outages as per the definitions in Schedule 7 of the Specimen EPA.

77. Can BC Hydro clarify the specific level of detail and format required for the Community Engagement Plan in Schedule 3 Section 6.10?

BC Hydro is seeking to understand what efforts, and the status of such efforts, the Proponent has taken to consult with the local community where the Project will be located.

Please refer to the General Instructions of Schedule 3 and the second paragraph of Schedule 3 Section 6.10 that details the information that is requested as evidence of community consultation.

76. Can BC Hydro please confirm if the following items in Appendix A. Seller's Plant Description of Schedule 3, are required to be submitted with the bid proposal or at contract execution?

Per Section 1.1 (g) of Schedule 3, Proponents should complete and submit Appendix A, along with the associated documents by the RFP Closing date.

Site Layout and Electricity Distribution and Generation System may be updated based on the final design.

November 7, 2025

75. If the Proponent submits a completed Form 5 from a Project First Nation and receives the $1/MWh credit for the First Nations Community Economic Benefits and that Project First Nation wishes to become an equity partner post EPA award and prior to COD; will the Proponent receive the $1/MWh EPA penalty for this evaluation credit?

As per Schedule 7 – Specimen Electricity Purchase Agreement (EPA), Appendix C and Appendix I, if the project receives a credit of $1.00/MWh for First Nations Community Economic Benefits and the Project First Nation becomes an equity partner prior to COD and holds Equity Ownership in the Seller's Plant within the meaning of the EPA at COD, then the Energy Price will be reduced by $1.00/MWh credit that was previously received.

November 4, 2025

74. Will there be a deadline to make the Proposal Fee payment for the 2025 Call for Power?

A unique invoice from BC Hydro will be sent to the Proposal Contact provided on Schedule 2, after the RFP Closing Date. The Proposal Fee must be received by the payment due date that is specified in the invoice, in order to meet the eligibility requirement in Table 1 of the RFP.

73. Can BC Hydro please confirm if the project specific line loss values will be provided with the CEAP results on November 24, 2025?

BC Hydro will not be sharing project specific line losses as part of the 2025 Call for Power.

72. What is the target date for NCTL Project Approval by BC Hydro Board of Directors?

This information is not available for disclosure at this time.

71. For the 2025 Call for Power, can the Proposal Fee be paid by Electronic Fund Transfer (EFT)? Is it the same bank account used for the CEAP deposits?

Yes, for the 2025 Call for Power, the Proposal Fee can be paid by EFT, and the bank account details will be the same as those used for the CEAP Interconnection Request deposits. However, please wait until you receive an invoice from BC Hydro before making any payment.

Each Proposal will have its own invoice, and the invoice number must be included with your payment to ensure it is correctly tracked.

Invoices and payment instructions will be sent to the Proposal Contact listed in Schedule 2 after the RFP Closing Date. The payment due date will be specified in the invoice.

October 20, 2025

70. I have questions specific to the Canada Infrastructure Bank (CIB) agreement and its covenants. How can I get clarity on them?

Proponents interested in learning more about the CIB agreement and its covenants can contact bchydro2025@cib-bic.ca.

69. Under Schedule 3 – Project Information Requirements, Section 2.2 requires a registered engineer's letter to confirm the accuracy and reasonableness of the energy generation estimates. Is it required for this engineer to be registered as a Professional Engineer (P.Eng) with Engineers and Geoscientists BC (EGBC), or will a Professional Engineer registered in another Canadian province be acceptable?

Yes, engineers registered outside of British Columbia are allowed, as long as they meet the requirements stated in Schedule 3.

68. Can the legal entity listed on the CEAP application and RFP Registration form change prior to bid submission?

Yes, changes to the legal entity, including: name, address, and corporate structure are possible prior to bid submission.

Please note that for the 2025 CEAP, participants are not required to revise the CEAP IR Form if the legal entity name changes. Instead, please notify BC Hydro by contacting CEAP2025@bchydro.com.

For changes to the RFP Registration Form please refer to instructions provided in Q&A#50.

October 14, 2025

67. Please confirm if projects proposing to connect into the Northwest Transmission line (including at Alyansh, Meziadin, Bob Quinn, and Tattoga substations) are subject to the recent North Coast Transmission Line (NCTL) Phase 1 Plant or Phase 2 Plant amendments to the specimen EPA.

Projects that will require NCTL Phase 1 and/or Phase 2 are subject to RFP Addendum 5.

NCTL Phase 2 Plants include POIs that are at a point on the portion of the BC Hydro System that extends west of Glenannan (GLN). The Alyansh, Meziadin, Bob Quinn, and Tattoga substations are all located west of Glenannan and as noted in Addendum 5 will require NCTL Phase 1 and possibly NCTL Phase 2.

October 10, 2025

66. Why are you making the changes described in Addendum 5?

Through BC Hydro system planning we identified that any project in the North Coast region that is awarded an EPA through the 2025 Call for Power will likely be contingent on the North Coast Transmission Line Project (NCTL) to interconnect to the BC Hydro system.

BC Hydro is committed to the building of the NCTL Project with its First Nations Project partners and the Province.

However, as with any large project of this size, there are risks and uncertainties that we need to manage on behalf of all ratepayers. While we are confident in NCTL proceeding, there could be unknown circumstances in the months ahead which may result in the project being delayed or not proceeding as currently planned. Therefore, the terms we have now added to the EPA are included to provide protection to both BC Hydro and proponents in the event of changes.

Adding termination rights to the EPA is done to protect the IPP and the ratepayer, it does not reflect BC Hydro's commitment or confidence in the completion of the NCTL project. NCTL remains a strategic priority for BC Hydro and the Province, and when in service, will enable significant economic development in the North West region of BC while also furthering First Nations reconciliation and economic benefits.

65. Why wasn't the change related to projects in the North Coast Transmission Line region communicated earlier?

BC Hydro system planning is dynamic and constantly changing in terms of the assumptions we use. The North Coast is one of the most dynamic areas due to a number of planning activities underway.

Based on the interconnection requests received in the North Coast, and also given the uncertainties and the dynamic nature of the North Coast system, we identified a need to amend EPA terms to balance the protection of IPP and BC Hydro rate payers along with providing opportunities for viable projects in the North Coast region to proceed.

64. I already submitted a CEAP interconnection request for my project that is an NCTL Phase 1 or Phase 2 plant, do I have to revise the proposed Commercial Operation Date (COD) in my interconnection request(s) given Addendum 5 specifies the Guaranteed Commercial Operation Date for both an NCTL Phase 1 and Phase 2 Plants will be October 1, 2033?

No, there is no requirement for a CEAP participant to revise the Interconnection Requests. BC Hydro will complete a 2025 CEAP Interconnection Feasibility Study based on the information submitted by the Proponent. The Proponent may adjust the COD for its bid submission based on the result of Feasibility Study.

63. I would like to withdraw my 2025 CEAP interconnection request, but already made a payment. Can I receive a full refund if I want to withdraw?

Yes, you are eligible to receive a refund as long as the CEAP IR Submission deadline has not passed.

If you choose to withdraw from the 2025 CEAP before the CEAP IR Submission deadline and have already submitted your payment, BC Hydro will issue a full refund for the $30,000, which represents the $15,000 CEAP Interconnection Request (IR) deposit and the $15,000 CEAP Feasibility Study deposit.

To initiate a withdrawal, please email CEAP2025@bchydro.com with your request no later than CEAP IR Submission deadline stated in Section 4.4 Table 2 which is October 14, 2025, at 5 p.m. Pacific time.

62. How do I know whether my project requires Phase 1 or Phase 2 of the North Coast Transmission Line Project?

Proposed projects in the North Coast Transmission Line Region may be dependent on the North Coast Transmission Line (NCTL) Phase 1 and/or Phase 2 to interconnect into the BC Hydro Transmission System primarily depending on the location of where the project would interconnect to the BC Hydro system.

Please review the Revised Schedule 7 Specimen EPA to determine how this may affect your proposed project and if your project is defined as a NCTL Phase 1 Plant or a NCTL Phase 2 Plant.

NCTL Phase 1 Plants include projects that plan to connect directly or indirectly to a Point of Interconnection on the BC Hydro Transmission System extending west from the Williston substation near Prince George up to and including the Glenannan substation. Projects that connect directly at Williston Substation are not dependent on the North Coast Transmission Line Project.

NCTL Phase 2 Plants include projects that plan to connect directly or indirectly to a Point of Interconnection on the BC Hydro Transmission System extending west from the Glenannan Substation. For clarity, projects that connect at Glenannan Substation are NCTL Phase 1 Plants, not NCTL Phase 2 Plants.

October 3, 2025

61. When will the details of the Canada Infrastructure Bank project level loan and IEI loan be available for proponents?

Proponents interested in accessing draft credit documents or learning more about these financing options should register their interest by contacting bchydro2025@cib-bic.ca.

60. Please confirm if BC Hydro would allow successful proponents to utilize or expand existing BC Hydro transmission right-of-way for new transmission infrastructure.

BC Hydro allows compatible use or development near existing transmission rights-of-way. Proponents must follow BC Hydro's guidelines and approval process. For further details, please refer to the Prepare & submit a ROW proposal page.

59. Please confirm if a non-binding MOU is sufficient for demonstrating site control on private lands for transmission facilities.

Confirmed.

58. What does a "valid" Interconnection Request mean? Does it mean my project can be connected to the system?

A valid Interconnection Request means that the data submitted by the CEAP participant as part of their Interconnection Request has been reviewed for completeness and consistency, and all deficiencies identified by BC Hydro have been cured.

A valid Interconnection Request does not confirm the feasibility of a requested point of interconnection (POI), nor does it confirm the feasibility of a requested interconnection for a proposed generating facility. The feasibility of the Interconnection Request will be evaluated during each Interconnection Feasibility Study, as per the executed Interconnection Feasibility Study Agreement.

There may be situations where the Interconnection Feasibility Study finds the requested POI is not feasible for various reasons. For example, it may not be feasible to expand an existing substation to accommodate an additional line position due to geographic, property, and other reasons.

57. If First Nations do not want to participate will a proposal be eligible?

A proposal will be eligible only if it meets the mandatory eligibility requirement of minimum 25% First Nations Equity Ownership in the project. This means that at least one Project First Nation must agree to hold equity ownership in the project at Commercial Operation Date (COD).

If no Project First Nation agrees to participate in equity ownership, the proposal will not meet the eligibility criteria and will be disqualified.

September 26, 2025

56. To support effective review of Schedule 4, can BC Hydro please clarify the preferred method for organizing and packaging Exhibits? Specifically, when submitting supporting documentation for First Nations consultation, should materials be grouped by individual Nation or organized chronologically by date or milestone? Additionally, should the consultation chronology be embedded within the First Nations Consultation and Economic Participation document, or submitted as a separate Exhibit?

As per Schedule 4 – General Instructions and Section 1, supporting documents should be grouped by First Nation to reflect the consultation chronology specific to each Nation.

The consultation chronology (e.g., communication log) should be submitted as a separate, clearly referenced Exhibit.

55. Will BC Hydro incorporate the July 2025 Ministry of Water, Land and Resource Stewardship (WLRS) Best Management Practices for Bats in BC into the EPA if it remains non-regulatory by the bid submission date, given its potential impact on wind energy generation forecasts?

While BC Hydro is aware of the Best Management Practices for Bats in B.C. being developed by the Ministry of Water, Land and Resource Stewardship (WLRS), we are not intending to modify the Specimen EPA. Please refer to section 4.2 of the Schedule 7 Specimen EPA that requires the Seller to obtain, comply with and maintain all permitting requirements over the life of the project.

Proponents are responsible for assessing risks and uncertainties, including potential impacts on budgets and schedules. We encourage you to consult your own technical, financial, and legal experts to inform your bid assumptions.

54. Will BC Hydro reflect the upcoming BCER policy framework in the EPA if it remains non-regulatory by the bid submission date, and will it provide standardized assumptions to help proponents manage risks and prepare levelized bids?

We are not intending to modify the Specimen EPA. Please refer section 4.2 of Schedule 7 Specimen EPA that requires the Seller to obtain, comply with and maintain all permitting requirements over the life of the project. Proponents are responsible for assessing risks and uncertainties, including potential impacts on budgets and schedules. We encourage you to consult your own technical, financial, and legal experts to inform your bid assumptions.

53. Are updated cost ranges or estimates available for the Feasibility, System Impact, and Facilities Studies?

The cost of interconnection studies depends on the complexity of the study and the scope of network upgrades required to support the interconnection request. As the interconnection studies for the 2024 Call projects are still underway or pending reconciliation, actual costs are currently available only for feasibility studies.

To support planning and budgeting, BC Hydro is providing the following typical cost ranges for the three types of Open Access Transmission Tariff (OATT) interconnection studies, based on recent generator and load interconnection projects with comparable scope and complexity:

Feasibility Study: $25,000 – $70,000

System Impact Study: $150,000 – $250,000

Facilities Study: $1 million – $7 million

The costs of Feasibility Studies, System Impact Studies, and Facilities Studies must be paid by the interconnection customer in cash (OATT Attachment M-1 Appendix 2: Interconnection Feasibility Study Agreement, Section 6 and OATT Attachment M-1 Appendix 3: Combined Study Agreement, Sections 6 and 10).

For Facilities Studies, BC Hydro can accommodate staged payments aligned with forecasted cash flow and contractual commitments.

Please note: The Facilities Study cost range does not include expenses related to equipment procurement or property acquisition. It does include costs associated with permitting preparation and all activities required to de-risk the project and achieve a Class 3 cost estimate of +15% / -10% (OATT M-1, Section 8.4 – Interconnection Facilities Study Procedures). Completion of these activities ensures the estimated cost and schedule for implementing Network Upgrades are accurate and helps minimize the risk of significant Network Upgrades cost increases and/or delays to the in-service date.

September 12, 2025

52. If an MOU is signed between a Proponent and the Economic Development entity of a Project First Nation (as the delegated authority for managing business and commercial matters on behalf of the Project First Nation), will this MOU count towards the Evaluation Price Credit under Form 5?

The MOU can be between a Proponent and the Economic Development entity of a Project First Nation as long as the attestor signing Form 5 meets the requirements detailed in Form 5, Section 4, 1.

51. Form 5 – Are Proponents required to submit a copy of the MOU alongside Form 5 or is the attestation all that is required?

BC Hydro only requires a Form 5 to be submitted with the Proposal. We do not require a copy of the MOU.

50. Can a Proponent change the entity name on its Registration Form after September 12th, 2025?

Yes, it is possible to amend a Registration after September 12th, 2025. However, please note that Section 8.2 of the RFP states that BC Hydro requires five (5) business days following receipt of the Registration Form to provide access credentials to the Sourcing Extranet, which is necessary for submitting a Proposal.

Therefore, Proponents should ensure that any amendments to their Registration Form are submitted with sufficient time to allow for credential issuance and proposal submission before the Closing Time.

49. Will the list of Proponents and First Nations be published?

BC Hydro may make certain Proposal information publicly available. Please refer to Section 14.14 of the RFP document.

48. If a project involves an expansion to an existing or planned generation facility, does the operational footprint represent only the areas around each individual wind turbine generator? Does the footprint include site roads or interconnection infrastructure, such as the collector substation?

Refer to Table 1 of Section 2.2 of the RFP (Project Eligibility Requirements), the operational footprint for an expansion must be clearly delineated from and not overlap with the operational footprint of an existing generating facility or a yet to be constructed generating facility with an existing electricity purchase agreement. The operational footprint is not limited to the areas around individual wind turbine generators.

However, non-generating assets, such as access roads, collector substation and common collector system trenches, etc., may be utilized by more than one Project.

47. Will BC Hydro provide a Levelized Real Conversion Factor for the 2025 RFP (as referenced in section 11.2 of the RFP document)? If not, should we assume the same factor as in the 2024 RFP, or are proponents expected to calculate it themselves?

Please see Q&A #36.

46. EPA Appendix C, 5(a)(ii) & 5(c) – does "total actual project capital" expenditures include or exclude financing costs, advisory costs, interest during construction, LC fees?

Yes, "total actual project capital" expenditures includes financing costs, advisory costs, interest during construction, LC fees.

45. When does a First Nation need to legally become an equity partner to meet the minimum 25% First Nation Equity Ownership Eligibility Requirement for the 2025 Call for Power? What evidence is required at the bid submission stage versus the EPA stage?

To meet the minimum 25% First Nations Equity Ownership Eligibility Requirement, one or more Project First Nation(s) must hold at least 25% Equity Ownership in the Proponent/Seller at Commercial Operation Date (COD).

At the time of bid submission, Proponents are required to confirm this eligibility by completing the attestation provided in Schedule 4, Form 4. If the Proponent is awarded an Electricity Purchase Agreement (EPA), the Seller must, as a condition of achieving COD and again on each of the first, second, and third anniversaries of COD, submit a statutory declaration confirming the level of Equity Ownership held by each Proposal First Nation and, if applicable, any additional Project First Nation.

In addition, the Seller must provide a letter from each Proposal First Nation (and any additional Project First Nation, if applicable) confirming their ownership level in the Seller. Failure to deliver the required statutory declaration will be considered a "material default" under the Specimen EPA.

For further details please refer to: Table 1 – First Nations Equity Ownership; Section 3 – First Nation Economic Participation; Schedule 4 – First Nations Consultation and Economic Participation.

44. I have comments on the RFP process and/or Specimen EPA (e.g., ROFR). Will you consider my comments and make changes?

No, the 2025 Call for Power RFP and Specimen EPA are final, aside from addenda that are issued. The 2025 Call for Power Engagement period has closed and we do not plan to make changes based on feedback at this point.

43. I have questions about my project's viability and/or how to interpret the Specimen EPA (e.g., how ROFR might apply), can BC Hydro help me?

No, BC Hydro will not provide advice, confirm a Proponent's calculations, or eligibility related to the RFP. BC Hydro recommends that each Proponent seek independent legal and technical advice in preparing its submission as may be necessary.

August 29, 2025

42. Can one project (i.e. one bid submission) have two Points of Interconnection? For example, Project A has a nameplate capacity of 200MW, consisting of 100MW connecting to two adjacent Points of Interconnection with separate Interconnection Requests. This may allow projects to achieve economies of scale while avoiding congestion on a single Point of Interconnection.

As outlined in Table 1 of Section 2.2 of the RFP (Project Eligibility Requirements) a project must have single Point of Interconnection.

41. Is BC Hydro able to advise if my project is better suited for the Call for Power RFP or the Request for Expression of Interest RFEOI for Capacity?

BC Hydro is unable to advise whether a whether a project is best suited for the RFP or RFEOI. Interested parties are responsible for ensuring that their projects meet the requirements of the RFP and its associated Schedules and/or the RFEOI. Please seek professional guidance as necessary to help with that assessment.

40. If a CEAP Interconnection Request was submitted to include a wind resource with a battery energy storage system (BESS), can the BESS be dropped later at RFP submission?

In Table 1 of Section 2.2 of the RFP (Project Eligibility Requirement), it states that "the technical parameters of a Project as described in a Proposal must be consistent in all material respects with the technical parameters forming the basis of the corresponding CEAP IR. A material inconsistency would include any inconsistency that, in BC Hydro's opinion, could reasonably be expected to have an impact on the proposed interconnection including Network Upgrade schedule or any costs to be borne by BC Hydro in relation thereto. Without limiting the generality of the foregoing the Plant Capacity specified in a Proposal must be less than or equal to the installed capacity reflected in the corresponding CEAP IR."

Given the foregoing, if dropping the BESS results in a material inconsistency between the technical parameters of a Project described in a Proposal and the corresponding technical parameters in the CEAP IR, a Project, could be ineligible in the RFP.

39. Does this RFP exclude biomass generation?

As noted in Table 1 of Section 2.2 of the RFP (Project Eligibility Requirement), the entire energy output from the Project (excluding Auxiliary Fuel) must be from a single resource type and must qualify as a Clean or Renewable Resource as defined under the Clean Energy Act.

38. Are Proponents permitted to change the parameters of their bids (e.g., Project Size, Commercial Operations Date (COD), equipment specifications, etc.) between what is submitted in the CEAP IR and the Proposal Schedules? And can I change my CEAP IR after it has been approved?

As specified in Table 1 of Section 2.2 of the RFP (Project Eligibility Requirement), the details contained in the CEAP IR must be consistent in all material respects with the information that is provided pursuant to the Schedules of the RFP. A material inconsistency would include any inconsistency that, in BC Hydro's opinion, could reasonably be expected to have an impact on the proposed interconnection including Network Upgrade schedule, or any costs to be borne by BC Hydro in relation thereto. This is important because the cost of Network Upgrades are considered in the evaluation.

Accordingly, Proponents should not change the details in their Proposal, otherwise the project may not meet the eligibility requirement. Notwithstanding the above, the COD reflected in the CEAP IR may be different from the Proposal if the Interconnection Feasibility Study (as defined in the Open Access Transmission Tariff [OATT]) conducted by BC Hydro determines that the COD proposed in the CEAP IR cannot be met due to the time required to complete Network Upgrades.

In this circumstance, the COD in the Proposal Schedule may differ from the COD in the CEAP IR provided that the COD in the Proposal Schedule falls between the date by which BC Hydro determines that Network Upgrades may be completed and October 1, 2033.

We provide the following illustrative examples for clarity: A change to COD may or may not be material depending on whether or not the change has implications to the Network Upgrade cost estimate and schedule which could be impacted by how many months the COD moves between what was proposed in the CEAP IR and the Proposal Schedules.

A COD cannot move to an earlier date in the Proposal Schedules than what was proposed in the CEAP IR because it may not be possible to accelerate the schedule of the Network Upgrades on the BC Hydro System. A change in the make, model, number of turbines is not expected to be material as long as the maximum injected capacity is consistent or less than the corresponding Interconnection Feasibility Study.

Please note there is no opportunity for the Proponent to revise the Interconnection Request (IR) during the CEAP once the IR becomes valid.

37. Can details on the Registration Form be amended after it has been submitted? For example, changing the name of the Entity or the Parent Company?

Yes, the Registration Form may be amended after its submission. Please refer to Section 6 for more details.

36. What are the evaluation bid price adjustments and formula to be used in the 2025 Call for Power?

Please refer to Section 11.2 in the RFP for an explanation of how the bid price adjustors are to be applied at Evaluation. BC Hydro will generally use the same formulas as the 2024 Call Illustrative Evaluation Price Adjustor Formulas [PDF, 214 KB] example with updates to reflect the 2025 Call evaluation, subject to BC Hydro's discretion to modify if/as needed.

35. Would BC Hydro consider flexible-term EPAs to support financing of a hybrid pumped storage hydro project that could be built in tandem with wind and solar resources ahead of the COD?

As outlined in Table 1 of Section 2.2 of the RFP (Project Eligibility Requirement) the entire energy output from the Project (excluding Auxiliary Fuel) must be from a single resource type and must qualify as a Clean or Renewable Resource. In addition, the Specimen EPA is not subject to negotiation or modification other than as described in Section 12.1 in the RFP.

34. The BC Hydro transmission system nearest my potential project is at capacity with no point of interconnection available. Will my community solar projects be eligible under the BC Hydro Call for Power?

Please review Section 2 on the eligibility requirements for the 2025 Request for Proposals, including the Interconnection Feasibility Study Agreement eligibility requirement in Table 1 where, a Proponent must submit a new interconnection request to participate in the 2025 CEAP. This CEAP process will review the feasibility of interconnecting your proposed project. Please refer to the 2025 CEAP website for key dates and submission instructions. If your community project is below the minimum project size that is eligible for the 2025 Call for Power RFP please refer to BC Hydro's other programs, including Self-generation.

33. When considering an expansion to a project that was successful in the 2024 Call for Power, please confirm that the collector substation is part of the interconnection facilities that can be shared. Specifically, can the additional wind turbine generators be connected to the low side of the main power transformer of the project substation, provided the correct switching and metering are in place on the MV bus to conform with operational requirements?

As per Section 2 .2 Table 1 as described the sharing of the transmission related facilities is permissible.

32. If a project has the potential to be built in phases, with additional generation added in each phase, should all phases be in one submission, or should each additional phase be a separate submission?

Addendum 2 has been issued to clarify that phased projects are not eligible for the 2025 Call for Power RFP. As outlined in Section 2.2 Table 1 of the RFP, and Schedule 7 Specimen EPA a Project must have a single COD. As outlined in Section 2 of the RFP, for clarity, Proponents may not submit multiple, or alternative, Proposals for a Project(s) on the same site. However, a Proponent may submit separate Proposals for Projects on different sites. Subject to satisfaction of the eligibility requirements outlined in Section 2.2 Table 1 of the RFP, an expansion to a project that was awarded an EPA in the 2024 Call for Power could be eligible. However, we will not consider two different Proposals submitted in the 2025 Call for Power, where one Proposal is dependent upon another Proposal. For example, where Proposal A is a generating facility and Proposal B is an expansion to the generating facility in Proposal A.

August 28, 2025

31. In completing Section 1.1(b) of Schedule 3 – Project Information Requirements, which line item from the CEAP Interconnection Request Generator Interconnection Data Form should Proponents reference to report the aggregated plant generating capacity? Specifically, should this correspond to Line 3.02 (Maximum Power into BC Hydro Transmission System at POI), Line 3.03 (Total Contracted Capacity), or Line 3.04 (Total Installed Capacity of All Generators)?

The item 3.04 "Total of the MW installed capacities of all generators, should include existing and new" of the Interconnection Request   Generator Interconnection Data Form (GIDF) notes the total generating capacity of the proposed generating facility and should be referenced in Section 1.1 of Schedule 3 (Project Information Requirements).

For clarity, 3.02, 3.03, and 3.04 in GIDF are intended to capture only the new proposed generating facility's values. If a 2025 CEAP Interconnection Request is connecting a project to an existing Point-of-Interconnection (POI) with an existing or planned generating facility, do not include the existing or planned facilities values in these cells.

For clarity, 3.02 (maximum power that the plant plans to inject into the BC Hydro Transmission system at POI) must be lower than the 3.04 value due to the losses on the IPP's system between the POI and the generating facility.

30. Can an advisor advise on, or work with, more than one Proponent (including First Nation members of the Proponent Team) on different Proposals in this RFP? If so, what kind of disclosure must be made to BC Hydro, if any, and what steps does the advisor need to take?

An advisor to one Proponent Team may be an advisor to another Proponent Team subject to compliance with Section 14.11 (No Collusion) and Section 13 of the RFP (Conflict of Interest, Relationship Discloser and Restricted Parties). Note that Section 13 of the RFP includes a potential requirement for BC Hydro's written approval to enable an advisor to advise two separate Proponent Teams.

29. Is there any risk of a Project being rejected if it is too large for the proposed Point of Interconnection (POI), or will BC Hydro just increase the cost of the Interconnection to account for all the System Upgrades required to accommodate the Large Project?

The technical feasibility of interconnection can be confirmed only through an Interconnection Feasibility Study. It is possible that an interconnection of a very large project may not be technically feasible depending on the POI selected. If the interconnection is technically feasible and BC Hydro can identify Network Upgrades, BC Hydro will issue an Interconnection Feasibility Study including a good faith cost estimate of Network Upgrades. BC Hydro's evaluation process is detailed in Section 11 in the RFP.

Specifically, BC Hydro will consider Projects that meet the Eligibility Requirements presented in Table 1 of the RFP, which includes the Interconnection Feasibility Study Agreement requirement. Furthermore, the input of Network Upgrade cost in the Evaluation Price is described in Table 4 of the RFP.

28. Can a Proponent request an extension to a deadline under the Request for Proposals Schedule?

No, the deadlines are as specified in the RFP Schedule and apply to all Proponents.

August 20, 2025

27. How has the First Nations economic participation model changed since the 2024 Call for Power?

Following engagement with both Independent Power Producers (IPPs) and First Nations, the First Nations non-equity benefits credit has been adjusted, specifically:

  • The name of the credit has been changed to the First Nations Community Economic Benefits Credit.

  • Proponents and First Nations will be required to provide attestations indicating that preliminary agreements are in place at the time of proposal submission, rather than a full agreement that was required in the 2024 Call.

  • A Form 5 must be submitted for each First Nation that is attesting to the existence of a signed Term Sheet or Memorandum of Understanding (MOU). Each accepted Form will receive an evaluation credit of $1 MWh (for one First Nation), to a maximum of $2/MWh (for two or more First Nations). Refer to Section 11.2 of the RFP for more information.

  • Upon successful award of an EPA, proponents will be required to submit a letter signed by a representative of the First Nation by the project's COD that confirms a First Nations Community Economic Benefits agreement is in place; if the proponent fails to provide the letter by COD, penalties in the form of a reduction to energy price will apply. See Specimen EPA for details.

  • BC Hydro has included a non-exhaustive list of examples of economic benefits that count for the First Nations Community Economic Benefits Credit in Schedule 4, Section 3.

26. What are the consultation standards against which BC Hydro will review proponent consultation information?

BC Hydro has set out a list of expectations in Schedule 4 of the RFP. Although not specified in the RFP, it is generally accepted practice to allow First Nations at least 30 days to review and respond to any information provided.

As described in Section 11.1 (e) of the RFP, BC Hydro will not enter into an EPA with a proponent unless BC Hydro in its sole discretion considers BC Hydro has met BC Hydro's consultation obligations to enter the EPA.

25. What are some publicly available sources of information on consulting with First Nations?

BC Hydro encourages proponents to review the resources on consulting with First Nations available on the website of the Ministry of Indigenous Relations and Reconciliation, particularly:

(i) Building Relationships with First Nations: Respecting Rights and Doing Good Business [PDF];
(ii) Guide to Involving Proponents When Consulting First Nations [PDF]; and
(iii) Updated Procedures for Meeting Legal Obligations When Consulting First Nations [PDF].

BC Hydro also encourages proponents to review Clean Energy Production in B.C.: An Interagency Guide Book for Proponents [PDF], which brings together statutory, regulatory, and procedural information from resource-based ministries and agencies involved with the review of clean energy projects.

24. Where is a good first point of contact at the Provincial government for proponents to discuss First Nations consultation matters?

Proponents should contact the Clean Energy and Major Projects Office (CEMPO@gov.bc.ca). The Clean Energy Major Projects Office can address high level questions and concerns about clean energy projects and also direct proponents to other sources of information with the Provincial Government.

23. How do I register to submit a Proposal?

Email the completed Registration Form (Schedule 1 [MS Word, 43 KB]) to 2025call@bchydro.com. Once registered, BC Hydro will provide credentials to access the Sourcing Extranet for Proposal submission.

22. Will there be additional informational meetings and how do I register to participate?

As part of BC Hydro's 2025 Call for Power, we will be hosting two virtual Request for Proposals (RFP) Informational Meetings on September 25 and October 2, in accordance with Addendum 1 of the RFP.

As outlined in Section 5.6 of the RFP, we are holding these Informational Meetings for registered Proponents and their affiliates, which should be identified by the registered Proponent's primary contact through the Informational Meeting registration process.

First Nations representatives are also invited to attend.

Attendance at an Informational Meeting is at the discretion of the registered Proponents and First Nations, but registered Proponents who do not attend will be deemed to have received all of the information made available to attendees.

Since the same information will be provided at both meetings, please attend only one of the virtual sessions.

21. How do I submit a question?

The deadline to submit questions was December 3, 2025. Questions and answers are subject to the terms stated in Section 5.2 – Enquiries and Responses of the RFP.

20. Where can I access the documents / presentations from the engagement sessions?

Documents/presentations from the engagement sessions are available at the following link: https://www.bchydro.com/callforpower/engagement

19. Can BC Hydro please confirm that for the purposes of Bid Security, more than one letter of credit may be provided so long as the aggregate amount of the letters of credit is the same as the amount of Bid Security required in respect of the Project? For example, if the total bid security is $5M, BC Hydro would accept a $2M letter of credit from one party and a $3M letter of credit from another?

Confirmed.

18. Could you please confirm that the address provided by BC Hydro below should not include "BC Hydro" as the organization name?

RFP Administrator – RFP 22357 BC Hydro 2025 Call for Power
333 Dunsmuir Street, Main Floor Lobby
Vancouver, BC V6B 5R3

BC Hydro may be added as the organization name.

17. For the 2025 Call for Power, will BC Hydro allow a renewable energy project to connect to the 500 kV network?

Please refer to the BC Hydro Transmission System Information for the 2025 Call for Power [PDF, 342 KB], where it states "BC Hydro does not allow new generator customers to directly connect at the 500kV level to maintain system integrity and reliability for all customers."

16. Can I participate to both the RFEOI for Capacity and the 2025 Call for Power RFP?

Yes, you can participate in both the RFEOI for Capacity and the 2025 Call for Power RFP. These are separate and independent processes, and participation in one does not preclude or qualify you for the other.

15. Is the Applicant as stated on the Form 1 – Form of Letter of Credit, meant to be the Proponent or can the Applicant be an owner and equity provider of the Proponent?

The Applicant on the Letter of Credit is typically the Proponent, but it can also be the owner or the equity provider of the Proponent.

14. Do we need to submit met tower data for wind resource assessments?

Schedule 3, Section 2.3 outlines the requirements for data submission. No raw data is required to be submitted.

13. How can developers establish which domestic Canadian financial institutions will be acceptable to BC Hydro, for a Letter of Credit? For example, are BNP and HSBC Bank Canada acceptable institutions?

Form 1 – Form of Letter of Credit, page 2, Letter of Credit Requirements, provides the criteria regarding acceptable financial institutions. Developers are responsible for ensuring the letter of credit issuer meets the stated criteria. BC Hydro will not confirm acceptability of the letter of credit issuer beforehand.

12. Are Reciprocating piston Gensets powered by either Natural gas or Biogas permitted to participate?

The entire energy output from the Project (excluding Auxiliary Fuel) must be from a single resource type and must qualify as a Clean or Renewable Resource as defined under the Clean Energy Act.

11. Are the 2024 Call for Power CEAP Interconnection Feasibility Studies valid for the 2025 Call for Power for projects that either didn't win an EPA or were not bid into the Call for Power? In other words, do we have to re-submit the CEAP IR for the exact same project size and POI as was done for the 2024 Call for Power? Or, can we use the 2024 CEAP IR Study?

Due to ongoing system changes, Feasibility Studies are only valid for the same Competitive Electricity Acquisition Process (CEAP) they were completed in. Therefore, in order to meet the Interconnection Feasibility Study Agreement eligibility requirement as detailed in Table 1 of the 2025 Call for Power RFP, a Proponent must submit a new interconnection request to participate in the 2025 CEAP. Please refer to the 2025 CEAP website for key dates and submission instructions.

10. Can U.S. companies participate in the RFP?

Section 2.1 in the RFP provides information regarding the eligibility of U.S. Suppliers, pursuant to the Tariff Response Procurement Directive (No. 1) issued by the Lieutenant Governor in Council under the Economic Stabilization (Tariff Response) Act (British Columbia), U.S. suppliers are not eligible to participate in this RFP.

9. What are the site control requirements under the RFP? Specifically for Crown land, is submitting an investigative licence application sufficient, or must it be approved before the proposal deadline? Should the expected approval date be included in the proposal schedules?

Schedule 3 Section 3.2 outlines the evidence of Site Access/Control information requested as part of the RFP. For Crown land, please refer to Section 3.2(d) which states to include Investigative Use License and/or Accepted Investigative Use License Application and/or submitted Investigative Use License Application form for Provincial Crown lands as an Exhibit, where applicable.

August 5, 2025

8. Are the Early Commercial Operation Date (COD) incentive bonuses additive?

Yes. Please refer to Section 8.4 in Schedule 7 – Specimen EPA [PDF, 1.2 MB] for more information.

7. Are there geographic regions or substations where BC Hydro is prioritizing new energy supply due to transmission constraints or projected demand growth?

In the province, more than 70% of the province's electricity is consumed in the major load centers of the Lower Mainland and southern portion of Vancouver Island. Please see the BC Hydro Transmission System Information [PDF, 343 KB] for the 2025 Call for Power.

6. Will BC Hydro allow bundled proposals where generation and storage are combined under a single contract?

Yes, the specimen EPA includes provisions for battery storage. Please note that additional amendments may be required to the Specimen of EPA.

5. Within an energy-only procurement framework, how will BC Hydro evaluate the contribution of storage—such as its role in shaping, dispatchability, or enhancing system reliability? Will hybrid configurations receive additional value or scoring consideration, particularly for their system integration and delivery profile? Additionally, will proposals offering shaped energy in constrained areas be considered higher value during the evaluation process?

A proposal with a Designated Capacity Commitment may receive a credit in calculating the evaluation price if the project can meet the capacity commitment requirements that are specified in the Specimen Electricity Purchase Agreement. Proponents are encouraged to review both Section 11.2 of the RFP and Schedule 7 – Specimen EPA for full details on the capacity commitment criteria and associated evaluation credit.

4. Are there performance expectations, metering configurations, or delivery requirements specific to hybrid projects?

Please refer to Q&A #5. Furthermore, batteries must be charged by generation from the Energy Source and cannot be charged using BC Hydro's integrated system. There may be additional project specific technical requirements identified for a hybrid project in the Interconnection process.

3. Will battery-paired wind or solar projects be eligible under the 2025 Call for Power?

Yes. Please refer to Q&A #1 for more information.

2. Are batteries a generation resource?

No. Batteries are energy storage and not considered a generation resource. Eligibility requirements for the 2025 Call for Power are detailed in Section 2.2 of the RFP. An eligibility requirement, Clean or Renewable Resource, details that "the entire energy output from the Project must be from a single resource type and must qualify as a Clean or Renewable Resource." A Clean or Renewable Resource, as defined in the RFP, which also references the Clean Energy Act, means "biomass, biogas, geothermal heat, hydro, solar, ocean, wind or any other prescribed resource."

1. Is a project that combines run-of-river hydro and a Battery Energy Storage System (BESS) to meet the 40 MW minimum eligible for the 2025 Call for Power (CFP)?

Eligibility requirements for the 2025 Call for Power are detailed in Section 2.2 of the RFP. An eligibility requirement, Clean or Renewable Resource, details that "the entire energy output from the Project must be from a single resource type and must qualify as a Clean or Renewable Resource." A Clean or Renewable Resource, as defined in the RFP, which also references the Clean Energy Act, means "biomass, biogas, geothermal heat, hydro, solar, ocean, wind or any other prescribed resource."

Batteries are energy storage and are not considered a generation resource. As such, a project must consist of a minimum of 40 MW of generation from any Clean or Renewable Resource.

Note that if a project has an Energy Source that is not hydro, wind, solar or biomass; or storage, additional amendments may be required to the Specimen of EPA and batteries must be charged by generation from the Energy Source and cannot be charged using BC Hydro's integrated system.

Additionally, BC Hydro also has a 2025 Request for Expressions of Interest (RFEOI) for Capacity underway. Participation in the 2025 Call for Power does not preclude proponents from taking part in RFEOI. Interested parties are advised that the 2025 Call for Power process and the 2025 RFEOI for Capacity are independent of the other and participation in one process will not be participation in the other process.