Included below are PGE’s final documents for the 2023 All-Source RFP issued February 2, 2024.

2023 All-Source RFP Main Document

• Appendix D: Form BTA

• Appendix E: Renewable Resource Form PPA

• Appendix F: Form Storage Capacity Agreement

• Appendix G: Renewable Resource and Storage Capacity Form PPA

• Appendix H: Form APA

• Appendix I: Form EPC

• Appendix J: Form Parent Guarantee

• Appendix K: Credit Guidance

• Appendix L: NDA

• Appendix M: Solar Combined

• Appendix M: Storage Combined

• Appendix M: Wind Combined

• Appendix N: Approved Scoring and Modeling Methodology

• Appendix O: Bid Form

• Appendix P: Benchmark Details

• Appendix Q: Renewable PPA Form Term Sheet

• Appendix Q: Renewable PPA Form Term Sheet (MS Word)

• Appendix R: Storage Capacity Form Term Sheet

• Appendix R: Storage Capacity Form Term Sheet (MS Word)

• Appendix S: Renewable Power and Storage Capacity Purchase Agreement Form Term Sheet

• Appendix S: Renewable Power and Storage Capacity Purchase Agreement Form Term Sheet (MS Word)

• Appendix T: APA and EPC Form Term Sheet

• Appendix T: APA and EPC Form Term Sheet (MS Word)

• Appendix U: BTA Form Term Sheet

• Appendix U: BTA Form Term Sheet (MS Word)

• Bid Form

Included below are redlines of the final issued term sheets and form contracts:

• Appendix E: Renewable PPA Form Agreement - Redline

• Appendix F: Form Storage Capacity Agreement - Redline

• Appendix G: Renewable Power and Storage Capacity Purchase Agreement Form - Redline

• Appendix Q: Renewable PPA Form Term Sheet - Redline

• Appendix R: Storage Capacity Form Term Sheet - Redline

• Appendix S: Renewable Power and Storage Capacity Purchase Agreement Term Sheet - Redline

Included below are PGE’s draft documents for the 2023 All-Source RFP as filed May 19, 2023 with the OPUC.

2023 All-Source RFP Main Document

• Appendix D - 2023 RFP Build Transfer Agreement Form

• Appendix E - Renewable PPA Form Agreement

• Appendix F - Storage Capacity Form Agreement

• Appendix G - Renewable Power and Storage Capacity Purchase Agreement Form

• Appendix H - APA Form Agreement

• Appendix I - EPC Form Agreement

• Appendix J - Form Parent Guaranty

• Appendix K - Credit Guidance

• Appendix L - Non-Disclosure Agreement

• Appendix M - Technical Specifications

• Appendix N - Scoring and Modeling Methodology

• Appendix O - Bid Form

• Appendix P - Benchmark Details Update

• Bid Form Draft - This is the final bid form from the 2021 RFP. The 2023 bid form will likely be similar, but please do not use this file for 2023 RFP purposes.

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In partnership with OPUC Staff and Stakeholders, PGE has developed the following schedule.  The RFP schedule is designed to make timely progress toward PGE’s capacity needs and HB 2021 compliance requirements and is subject to change based on regulatory timing. PGE will update the schedule to reflect any timing changes.

• February 2, 2024 - PGE issues Final RFP.

• February 13, 2024 - Post-issuance bidder conference.

  • Content: PGE RFP Team will provide an overview of the bidding requirements, evaluation timeline and bid submission process.

  • When: 1 p.m. - 3 p.m. PST

  • Video recording

  • Slides

• February 16, 2024 – Notice of Intent to Bid due.

• February 23, 2024 – Benchmark bids due.

• March 26, 2024 — Third-Party Solar BTA/APA bids due.

• April 30, 2024 — All remaining bids due.

• June 7, 2024 - Initial shortlist identified.*

• June 21, 2024 – Best and final price update.*

• July 19, 2024 — PGE submits request for acknowledgment of FSL.

• Q3/Q4 2024 – Final contracts executed with winning Bidders as applicable.*

*These dates are subject to change depending on the quantity and complexity of bids received and should circumstances require.

Barring any major schedule changes in regulatory docket LC 80, PGE would not intend to submit this request prior to the CEP/IRP acknowledgement date, which is currently targeted for 1/25/24.

Dates subject to change.

Rev. 4/18/2024

RFP Post-Issuance Bidder Conference: Feb. 13, 2024

• Video recording

• Slides

We do not have a redline of Exhibit M (tech specs).

All technology tech specs were completely overhauled from both a substance and format perspective.

Here is a high level summary of key changes for each technical specification between the 2021 RFP to 2023 RFP.

Wind Facilities:

For 2023, the technical specifications for wind facilities were revised based on best practices developed from past RFP's, utility owned projects, and industry input. The specifications are based on a generic wind farm and cover balance-of-plant engineering, procurement, and construction scope activities for geotechnical services, civil works, wind turbine foundations, collection system, substation, gen-tie line, meteorological towers, operations and maintenance facilities, wind turbine erection, and general services. The document was streamlined from 2021 to aid in the review of the specifications while focusing on the key requirements for a wind facility.

In 2021, the technical specifications for a wind facility were broken up by the following classifications: M1-01 General, M1-02 Civil, M1-03 Mechanical, M1-04 Electrical, M1-05 Substation and Transmission, and M2 Wind. For 2023, any of the wind specific general, civil, mechanical, electrical, substation and transmission, and wind requirements were consolidated into one wind plant specification. During the consolidation, requirements were reviewed for their continued applicability, current utility requirements, and industry best practice. In addition, certain categories of requirements that spanned across all projects regardless of technology were kept as stand-alone specifications. These are the Engineering Documents, Drawings & Other Deliverables; Security and Compliance; PGE CAD and Numbering Standards; General Transformer Specification; and Communication, SCADA and Metering Facilities specifications. These five documents together with the Wind Plant Specifications make up the entirety of the technical specifications that apply to utility owned wind facilities.

Solar PV Facilities:

For 2023, the technical specifications for solar facilities were revised based on best practices developed from past RFP's, utility owned projects, and industry input. The specifications are based on a generic ground-mounted solar PV project and cover balance-of-system engineering, procurement, and construction scope activities for geotechnical services, civil works, foundations, collection system, substation, gen-tie line, weather stations, operations and maintenance facilities, permits, and site commissioning/turnover. The document was streamlined from 2021 to aid in the review of the specifications and focusing on the key requirements for a solar PV facility. In 2021, the technical specifications for a solar facility were broken up by the following classifications: M1-01 General, M1-02 Civil, M1-03 Mechanical, M1-04 Electrical, M1-05 Substation and Transmission, and M3 Solar. For 2023, any of the solar PV specific general, civil, mechanical, electrical, substation and transmission, and solar PV requirements were consolidated into one specification. During the consolidation, requirements were reviewed for their continued applicability, current utility requirements, and industry best practice. In addition, certain categories of requirements that spanned across all projects regardless of technology were kept as stand-alone specifications. These are the Engineering Documents, Drawings & Other Deliverables; Security and Compliance; PGE CAD and Numbering Standards; General Transformer Specification; and Communication, SCADA and Metering Facilities specifications. These five documents together with the Solar PV Plant Specifications make up the entirety of the technical specifications that apply to utility owned solar facilities.

Battery Energy Storage (BES) Facilities:

In 2021, the technical specifications for a BES facility were broken up by the following classifications: M1-01 General, M1-02 Civil, M1-03 Mechanical, M1-04 Electrical, M1-05 Substation and Transmission, and M4 Energy Storage.

For 2023, the technical specifications for battery energy storage facilities were revised based on best practices developed from past RFP's, utility owned projects, and industry input. Redundancies, commonalities, and aspects that did not apply between the Energy Storage specification in M4 and the other specifications from 2021 were identified and removed wherever possible to streamline the overall structure of the document. During the consolidation, requirements were reviewed for their continued applicability, current utility requirements, and industry best practice. In addition, certain categories of requirements that spanned across all projects regardless of technology and not already part of the Energy Storage specification were kept as stand-alone documents. These are the Engineering Documents, Drawings & Other Deliverables; Project Management and Controls; Security and Compliance; PGE CAD and Numbering Standards; General Civil Requirements; General Electrical Study Requirements; General Transformer Specification; Substation Design and Construction Specification; and Communication, SCADA and Metering Facilities Specifications. These nine documents together with the BES Specification make up the entirety of the technical specifications that apply to utility owned BES facilities.

All solar ownership bids will be evaluated as traditional ownership (i.e., rate base) without normalization effects within the 2023 RFP.

In appendix N, Exhibit A it states that state permits (e.g., site certificate) are required by “final shortlist”. However, the RFP Schedule on page 6 of the 2023 All Source RFP-Draft does not specifically say the words “final shortlist” so no date is included there related to that milestone.

The intent is that permitting documentation noted as required by “final shortlist” will be due by the acknowledged final shortlist. We do not have a specific date for when that would be yet, but it would likely be in Q1 2024.

Yes, if a project proposes a co-located resource with battery storage, and there are no barriers from a technical/engineering or a commercial perspective to grid-charging the battery, the RFP team will evaluate the storage as grid-charging capable. There will be incremental transmission costs related to such charging.

PGE will be updating the 2023 RFP solicitation schedule as a result of the regulatory schedule changes. PGE fully expects that both the Benchmark and third-party bid due dates will change, and hopes to share this revised schedule in the next few weeks.

This announcement makes a public commitment to complete some important transmission upgrades that allow conditional firm service to bridge into long term firm service. Please clarify if this announcement impacts PGEs proposed RFP transmission requirements and will no longer disqualify any projects relying on those upgrades.

The announcement by BPA that they will examine acceleration of key regional transmission projects - while a welcome step to enable decarbonization in the region - does not impact PGE's proposed RFP transmission requirements. As BPA notes in their press release, the projects are subject to environmental review and additional process, and PGE notes that the timing of key projects such as the Ross-Rivergate Rebuild, Big Eddy to Chemawa Rebuild, and Chehalis-Cowlitz Tap rebuild are likely outside of the action plan window (with late 2027 as a best-case scenario). PGE continues to encourage projects that are uniquely situated and likely to be able to meet the CODs identified in this RFP to submit a narrative on their specific transmission situation for review.

PGE's RFP Team will evaluate the cost and benefits of all project years as full years following COD.

In the draft RFP documents, PGE requires that bids have a Facility Study Agreement to be considered for the final shortlist. If a bid is unable to satisfy this requirement then the bidder is invited to provide a narrative describing how the project will secure a Facilties Study to support the project's COD.

In the bid form, please provide the expected output of the facility without adjusting for a projected transmission curtailment or unavailability. Instead, please ensure that you have provided the transmission product type and any supporting info requested in the bid form - PGE will use that information to determine how to model the expected delivery at the point of delivery.

We may need to adjust the schedule depending on the regulatory timeline. We anticipate a follow up regulatory filing no later than September 11 with proposed next steps on the regulatory schedule, and we may adjust the RFP issuance and review timelines if needed.

Please plan to follow our Large Generator Interconnection Process. Section 1.1.1 of our OATT advises that if a small generator is planning to use Network Resource Interconnection Service, the resource must follow the large generator interconnection process. Using Network Resource Interconnection Service is an interconnection requirement in this RFP.

The economic life considered for each technology is based on our depreciation study of electric property, which is filed with our regulators (most recently in Docket No. UM 2152). We are not open to consideration of longer depreciation periods.

This a clarification question regarding the approved suppliers in the RFP Tech Specs.

The solar specs do not list specific factory locations Main Power Transformer Suppliers, however the wind and BESS specs do. Can you explain why this is the case? E.g., Hitachi ABB is listed as an approved Vendor for Substation MPT in the Solar specs however in the BESS and Wind Specs only the Canada, Missouri, Virginia, and Germany ABB shops are listed.

The approved substation main power transformer suppliers and their respective shops are intended to be the same across all project technology types. For any discrepancies, please refer to the shops listed in the BESS and Wind technical specifications. Any proposed deviations from the pre-approved suppliers list would require PGE approval.

We will update the solar tech specs to aligns with the BESS and wind specs.

The ratios represent solar: storage.

Enter the nameplate of the solar component. Also, you can read more about hybrid resource modeling in this IRP roundtable.

Yes, this is correct.

As described in our latest redline of the RFP Main Document, which was included with our reply comments on 12/21/23: Completed bid forms must be sent via email to rfp@pgn.com with the IE copied (Frank.Mossburg@bateswhite.com) once PGE notifies bidders that the bid window is open. After receiving completed bid forms, PGE will send bidders a link to an online submission form to upload supporting documentation for the respective bid forms.

The Contiguous POD is a set of individual PODs sharing a common boundary service area that are aggregated and treated as a single POD in a Point-to-Point Transmission Service Request (TSR). PGE Contiguous is comprised of Bethel 230 kV, Keeler 230 kV, Forest Grove 115 kV, McLoughlin 230 kV, Pearl 230 kV and Rivergate 230 kV.

• Wind:

  • Minor language change to approved suppliers on protective relays. Identified by redlines.

  • Redline changes to M1-05-04 identified as redlines

• Solar:

  • Conformed the approved suppliers list across all technologies. For solar, that’s M3-01-08 and is not redlined due to the number of changes.

  • Minor redlines from the April version identified in M1-05-04

• Storage:

  • Multiple updates to the main spec, M4-01-01 identified as redlines and based on recent lessons learned from ongoing projects.

    • Minor changes to M1-02-01 based on lessons learned

• Same updates to M1-05-04 as wind and solar

PGE will allow Bidders to submit a narrative explanation if they are unable to meet the permitting matrix timeline included in this RFP. PGE views the permits and associated timelines as key to reducing risk and retains the discretion – to be discussed with the IE – to determine whether the explanation provided has sufficient merit to allow the bid to proceed.

Yes, bids must have a complete system impact study by the initial shortlist and a completed facilities study for the final shortlist. If a bid is unable to satisfy these requirement then the bidder is invited to provide a narrative describing how the project will secure a Facilities Study to support the project's COD.

1. Bids that directly interconnect to PGE do not need an active OASIS TSR.

2. Bids relying on BPA for transmission service are required to have either: 1) previously granted eligible transmission service, or 2) an eligible and active OASIS status Transmission Service Request (TSR) participating in the 2022 or prior BPA TSR Study and Expansion Process. Bidders participating in the ongoing 2023 process may submit a narrative if they believe their project is uniquely situated to receive service that complies with the commercial online date and transmission product requirements of this RFP.

3. PGE is not making available any transmission rights in this solicitation.

1. There is no fee for a Straw Bid proposal.

2. Bidders wishing to address security concerns in their straw proposals should plan to articulate how they will reduce the threat associated with multi-entity operations. PGE recommends bidders consider proposing roving patrols around the asset, secured entry onto the property, detection and monitoring (such as thermal cameras and fence detection), and commitment to closely coordinate with both PGE security and local law enforcement.

3. The straw bid COD must align with the RFP requirement that projects must be online by the end of 2027.

Straw bids are hypothetical proposals and there is no requirement that PGE procure these bids.

The only requirement is that the project conform with the minimum bidder requirements expected of all bids. PGE does not have an expressed desired ratio of BESS to generation nameplate.

Appendix P contains all information pertaining to Benchmark bid details.

The LTSA costs provided in Appendix P relate to utility owned projects. The cost information is a data point for the IE when evaluating LTSA costs received from bidders in the 2023 RFP.

Each bid form is intended to accommodate a single bid variant. The bid form contains multiple tabs and fields for multiple renewable, hybrid storage, and storage resources, however this is intended for input flexibility in support of a single bid variant.

A non-investment grade bidder can provide a LoC, if issued from a qualified institution. Any PGE draw would result from the Bidder’s non-performance, which would be defined in the APA form contract (to be negotiated).

Due to the current uncertainty around claiming the domestic content adder for the PTC and ITC, we will not give any value for it in evaluation for utility owned structure bids.

Yes, you can send an updated version of a previously sent bid form as long as its in by the submission deadline.

The path connecting at Grassland to SLATT has not yet been studied for a total transfer capability (TTC). However, the path was originally constructed and operated with both Carty and Boardman online. Therefore, we can assume that the path should be able to function with generation equivalent to the previous Boardman capacity of approximately 500MWs in addition to Carty's current capacity. Until studies are conducted, the actual TTC for that path remains unknown.

No BPA transmission is being made available by PGE in this RFP. We expect bidders to provide a plan/narrative of delivering the energy to PGE’s accepted points of delivery (as noted in Appendix N).