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. Proponents can use the 2025 Call For Power question submission form to submit questions online.
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.
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?
To submit a question, use the webform at www.bchydro.com/callforpowerquestions Questions and answers as 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.