IGP RFP Questions & Answers

Section 4.3 and 4.4 of the RFP body and Section 2.7.1 of Appendix B will be revised to clarify the Company's expectations regarding the requirements of the "initial analysis".

1. The "initial analysis" will now be referred to as the "cultural assessment"
2. At Bid Submission a Proposal must, at a minimum, have:
   1. A qualified consultant on retainer
   2. Included a high-level plan to complete the cultural assessment within the timeline detailed in Section 4.4.2.1 of the RFP Body

No, based on the Company's re-evaluation of the ability of these lines to host generation, these lines will be removed from Table 1 in the next filing of the IGP RFP, and will not be offered as a pre-screened interconnection location preferred by the Company.

The soft copies of the Model PPAs will be available for download through the Electronic Procurement Platform (Wood Mackenzie Supply Chain Intelligence Platform) shortly after we receive an order from the PUC to issue the final RFP.

The HECO team will consist of members from the teams that have contributed to the Preliminary Interconnection Report ("PIR"), including planning engineer(s), and members of our Legal team. A sample PIR template was included as Attachment 1 to our letter filed on April 23, 2024, in Docket No. 2018-0165. Please also see Section 1.6 of the Draft IGP RFP for more information on the PIR.

Yes, Hawaiian Electric is open to other solutions. The Companies' intent is for the Seller's Facility to have a secondary source to provide power to BESS Aux Loads and Station Service loads that is permanent, continuous, and uninterrupted. Hawaiian Electric intends to delete this sentence in the Model ESPA. Hawaiian Electric also plans to add language to the Model ESPA and Model RDG PPA to clarify that any additional equipment for separately metering Station Service and BESS Aux Load shall be the Seller's responsibility. Hawaiian Electric also plans to revise Attachment W of the Model ESPA to clarify that the Charging Energy for the RTE Performance Metric will be measured at the POI.

The minimum required reactive compensation described in Section 3(a)(ii) (Reactive Amount) of Attachment B (Facility Owned By Seller) of the Model RDG PPA and ESPA is expected to be retained for all voltage levels within the continuous operation range of the applicable PPA, per Section 3(e) (Under Voltage Ride-through) and Section 3(f) (Over Voltage Ride-through) of Attachment B (Seller's Facility) of the Model RDG PPA (and analogous sections in the Model ESPA), including at the most extreme voltages of this range (0.80 pu and 1.10 pu). Recognizing the island grids' dependence on these resources for reactive voltage support and observing that the technologies expected to be proposed likely have capability beyond the minimum requirements of 0.3287X ICR; the Company desires Facilities that can meet or exceed a minimum requirement to 0.75* Contract Capacity (i.e., 0.6 X ICR), in both injection and absorption directions, when voltage is within the continuous operation range. For facilities with reactive power capability in excess of the minimum requirements, in both the injection and absorption of reactive power, when voltage is within the continuous operation range, the Facility reactive power capability should not be limited to anything less than the actual Facility capability, in either the injection or absorption directions. The Facility P-Q and Q-V capability curves will be obtained by testing the facility PSCAD model (or PSS/E model), with the expectations that the facility's reactive power capability is correctly modeled in the submitted facility PSCAD model and PSS/E model for representation of the expected actual Facility performance for reactive compensation at differing voltage levels within the continuous operating range.

Please refer to the definition of "Investment Grade Status" in the Schedule of Defined Terms of the applicable IGP Contract (i.e., Appendix J, L, or M), which references a credit rating for the "Company's" senior unsecured long-term debt obligations or an issuer credit rating for the "Company." As the "Company" is defined as the utility signing the contract, i.e., Hawaiian Electric Company, Inc., Maui Electric Company, Limited or Hawaiʻi Electric Light Company, Inc., it is the credit rating of this entity or the credit rating of this entity's senior unsecured long-term debt that applies. Please also be advised that Appendix B Attachment 1 was revised in our July 17, 2026 filing to remove references to HEI.

As stated in the IGP Contracts, the credit rating for the Company's senior unsecured long-term debt obligations or an issuer credit rating for the Company, in each case, without regard for third-party credit enhancements, will be considered "Investment Grade Status" if it meets the stated requirements from at least two out of the three of rating agencies (S&P, Moody's, and Fitch). S&P and Fitch display separate ratings for Hawaiian Electric, Hawaiʻi Electric Light, and Maui Electric while Moody's displays a consolidated rating for Hawaiian Electric which applies to Maui Electric and Hawaiʻi Electric Light as wholly owned subsidiaries. If a rating agency only displays a consolidated credit rating for Hawaiian Electric and/or for Hawaiian Electric's senior unsecured long-term debt obligations, that consolidated credit rating can be used to establish the associated credit rating of Hawaiʻi Electric Light or Maui Electric for the purpose of determining Investment Grade Status.

For hybrid facilities, it is necessary to model generation and BESS separately to allow for all valid dispatches. It is especially important to explicitly model each unique power electronics device (e.g. aggregation of multiples of the same inverter is permitted but each different model/configuration of power electronics device should be modeled, even if on the DC side). It is insufficient to perform the analyses with one representative combination of PV+BESS dispatch. You may also reference Table C-3 for dispatch scenarios. If your PV system is capable of VAR output while online but outputting 0MW, it can remain connected in the ‘BESS output only' cases otherwise it will be modelled as offline.

When referring to the diagram on page 70 of Appendix H (Interconnection Facilities Cost and Schedule Information), in most cases, the new fiber running to the new substation would satisfy the primary and backup communications requirement. However, if you would like more specific guidance, please submit an inquiry to the applicable RFP Email Address and include the physical location of the new proposed substation.

The new Electronic Procurement Platform will be launched no later than 60 days prior to the bid proposal date, if not sooner. Once the replacement is ready, a revised Appendix D with instructions will be filed in Docket No. 2024-0258 (the "IGP RFP docket") and posted to the IGP RFP website at IGP RFP | Hawaiian Electric. Please check the IGP RFP website for updates.

The PIR intake requires an executed NDA (Appendix E) as a submission requirement but separately treats PIR Requests and PIR Fees on a per-island basis. A single executed NDA will cover PIR Requests submitted on both islands.

Question 1 – Multiple Proposal Submissions
The three-PIR request limit applies to the consolidated corporate-family level.
Question 2 – Co-Located Projects and Contract Structure
Please refer to section 3.11 of the IGP RFP. The Company states that any co-located project will be governed by a combination of the IGP Contracts and as a single contract. The generation component of a proposed Co-located Project must meet the requirements of either the RDG PPA or the Firm PPA; and the energy storage component of a proposed Co-located Project must meet the requirements of the ESPA.
Question 3 – MCBH Interconnection Status
Please note that two circuits are required for subtransmission interconnection. Referring to Table 1 in the IGP RFP, a project at MCBH would qualify for the pre-screened PIR price if the point of interconnection is with Koolau-Aikahi and Koolau-Kailua 46kV lines. An MCBH project interconnecting with Koolau substation and Koolau-Pukele 1 & 2 would also qualify for the pre-screened PIR fee.

The PIR Fee and the Proposal Fee does not need to be remitted by the named Proposer and may be made by an affiliate or other entity on the Proposer’s behalf. Per [GS1.1][AL1.2][GS1.3]RFP Section 3.7.3, please note that the PIR Fee and the Proposal Fee must be in the form of a cashier’s check from a U.S.-chartered bank. The cashier’s check should include a reference to the Proposal(s) for which the PIR Fee or Proposal Fee is being provided. We will not accept other types of checks, such as personal or business checks.

The entity named as prospective Proposer on the PIR Request and the executed Mutual Non-Disclosure Agreement (“MNDA”) does not need to be the same entity that subsequently submits the Proposal. However, confidential information can only be shared in accordance with the terms of the MNDA. If the entities on the PIR Request, MNDA, and other proposal documents do not match, Hawaiian Electric reserves the right to request additional information and to respond appropriately based on the specific circumstances. In general, a change of entity within the same corporate group should be acceptable.

For PIR Fee purposes, we would consider this one non-prescreened location, requiring a PIR Fee of $4,000.

A project that is considering two alternative points of interconnection (POI) should be submitted as two separate Proposals / PIR Requests. Each POI will need to be reviewed for capacity and other considerations. Please note that per IGP RFP Section 3.7.2.1, only variations of GCOD, Facility size, or configuration with/without storage (solar energy must include storage) can be offered as variations within a Proposal.

For mail tracking purposes, please feel free to use the contact information of the RAD Manager for Energy Procurement, Max Markrich. His phone number is 808-594-8081.

For the PIR Request, you may use your project's maximum export capacity at the POI in place of the Project Contract Capacity. If a Proposal's Contract Capacity differs from the maximum export capacity stated in the PIR Request, this deviation must comply with the requirements of RFP Section 1.6.9. For example, such deviation must have been identified in the PIR Meeting, memorialized in the Company's written meeting summary of the PIR Meeting and be deemed by the Company to be a reasonable alternative interconnection for the Project.

The requirements of IGP RFP Section 2.1.9 apply to all Project infrastructure. Footnote 35 clarifies that Project infrastructure subject to this requirement includes both the Project itself as well as any SOIF and COIF located at the Project Site but does not limit the scope of this requirement to only these components.

A PIR Fee (cashier's check) received by Hawaiian Electric after the PIR Request Due Date will be accepted as timely if sufficient evidence is also submitted to the applicable RFP Email Address by the PIR Request Due Date to substantiate that the PIR Fee was mailed on or before the PIR Request Due Date. Please be advised that this guidance applies to the PIR Fee only and does not change any Proposal Fee requirements.