FAQs

Here are frequently asked questions we receive about our work.

Is there a recording of the technical conference?

Does the RFP require bidding parties to have Network Resource Interconnection Service if the generation being bid is outside of PSO service territory?

Is there a DISIS cycle cut off for the generator?

Will generation located in MISO be considered?

Can you send the confidentiality agreement?

Is there a preference for Energy storage technology type or duration for the Dover sites? For any of the PSO available sites.

Does congestion of project POI vs. PSO load bus play into price scoring? If so how?

For the PSA option, will PSO require the land to be owned by the project or is a lease structure acceptable?

Will any benefit be assigned to projects that can achieve COD prior to December 2027, for example in 2026?

Are proposals for tolling agreements standalone storage not accepted? Are standalone BESS resources eligible for only PSA offers?

What is the pricing structure expected for the capacity agreement, particularly for energy storage? Would this be similar to a full tolling agreement (to include energy) or only capacity will be purchased?

Will there be a bid fee?

Can you comment on how capacity accreditation will be calculated for renewable projects that are being offered with collocated Storage systems?

What is PSO's expected timing around regulatory approvals?

If we use the POIs provided by PSO (Dover, Northeastern 1 & 2, and/or Rock Falls do we need to have an SPP queue number/current queue position?

Does "established site control" mean a project must have 100% site control? What would happen in evaluation to a project with 75% site control at the time of submission which had a line of sight on securing control for remaining acreage?

Will bidders submitting a PPA bid be required to redline PSO's form PPA - or will PPA negotiations commence after shortlist?

Is the 1500 MW procurement target and ELCC adjusted number? Follow up to this, how does selecting diverse technologies play into PSO selection criteria, given ELCC & PSO's load shape?

Will PSO accept consortium "self build" thermal generation proposals at the POI sites?

If project is in a later queue, but can meet the COD target, would it still be eligible?

How do bidder's submit an "Intent to Bid" ?

For repower projects, a 30-year useful life from a repower date might not be feasible. How is PSO accounting for this?

In regards to proof of site control for obtaining the CA. Is a recorded Memorandum of Lease is acceptable proof of site control?

Will PSO accept proposals for the sale of development rights?

When submitting an Intent to Bid, does this bind us to submit bids for every project that is listed?

When can site visits for each PSO Owned location (Northeastern, Dover and Rock Falls) be scheduled?

Can AEP provide us with an Approved Vendor List (AVL) for the Main Power Transformers? Is AEP willing to accept vendors that are not on the AVL and if so, what does that process look like to add a vendor?

Section 2.5 of the draft RFP states "For PSA Proposals, while qualifying for Federal Tax Credits is not an Eligibility and Threshold Requirement (Section 9.1) for participating in the RFP, the value brought to the Proposals in buying down the cost of energy by utilization of these tax credits is significant, and is included in the Company’s Economic Analysis (Section 9.2) and ranking of each of the respective Proposals." Later, Section 3.8.14 states "Proposals for non-thermal bids must comply with Prevailing Wage and Apprenticeship Requirements (PWAR) providing full value Federal Tax Credits (e.g., PTCs and ITCs) under the Inflation Reduction Act. Bidders should explain in detail any additional Federal Tax Credits available to proposed Projects associated with energy community or domestic content qualification (Bonus Credits)." Could you please provide further clarity on bid requirements regarding ITC? Would standalone storage proposals be required to comply with PWAR and obtain full ITC and Bonus Credits?

In Cases of Repower of existing sites, will PSCO consider the market-based value of the incremental MWh relative to existing contracts? In other words, if a wind site can produce 10% more energy via a repower, but such production is forecasted to occur when merchant prices are 2x higher than the average wind generation profile, how will PSCO account for this?

How will PSCO account for reliability of resource, and resource diversification. In cases of combined technology, ie solar and wind together under one IA, there is additional generation certainty and minimized risk due to outages and solar/wind resource. How is this reflected in the valuation methodology. Further, for an operating plant with existing generation data, PSCO likely will experience a benefit in certainty of wind resource.

How will PSCO account for the benefit of high capacity factor utilization of a project with an existing interconnection agreement? In the event for example surplus solar is added to an existing wind interconnection agreement, the cost and schedule risks are materially lower than standard projects in the SPP queue subject to price swings and schedule uncertainty.

For existing contracts, how does PSCO account for the financial burden to PSCO associated with existing assets curtailment reimbursement (if applicable), and the potential benefit of restructuring.

How is PSCO accounting for the value of solar or battery capacity that may be deployed in the near term? In the event of shortages in capacity in over the next few years, is PSCO valuing near term capacity, for a 2025 COD date, in a different way than, for example, a 2028 COD date?

Given the option to submit proposals for either a 12/15/2027 or 12/15/2028 COD, what COD should be assumed for energy storage proposals at the Dover, Northeastern and Rock Falls sites? Does PSO have a preference?

Can PSO share the ELCC methodology (average, marginal, critical hours, etc.) that are currently being used or are expected to be used by SPP to determine the number of MWs that the Company will be credited? Can PSO share the accreditation year that they expect to use to evaluate the number of MWs that the Company will be credited?

Does PSO accept projects in queues other than SPP that will joint SPP in the near future(2026-27)?

In section 6.6 of the RFP, it references not getting the form CA without providing additional information. Since the CA was available on the RFP site, can you explain what this is for?

What is the code for PSO's LMP price node/load zone?

Do proposals for storage projects need to be inclusive of augmentation?

If a bidder submits various designs for one individual project, does there need to be a separate Project Summary form (Appendix A) for each design?

Similar to the requirement for wind resources, is there a requirement that solar production estimates need to be prepared by an independent consultant as well?

Will there be a virtual Q&A or site walk through option for those who might be unable to attend? Either the same day or on a later date?

For operating assets, are bidders required to have section A12 completed (related to Environmental)? Or is this more for new projects in which environmental impacts need to be taken into consideration?

Are operating assets required to submit independent reviews as indicated in Section 3.8.4, or can operational data be provided?

If the developer is bidding a repower on an existing asset, will the developer need to completely scrap/rebuild all aspects of the project to AEP technical specifications or can the developer utilize the existing resources/design? Additionally, if existing resources/design can be utilized, what standards/specs do they need to meet? Mainly asking about the 30-year design life.

Are projects offering exclusively PPA Products obligated to satisfy the AEP GENeration Facility Standards (Appendix F)?

Are 3rd party wind reports required for all wind projects being bid, or is this only required for wind projects being bid as a Build Transfer?

I will not be able to attend the site visit. Will there be a virtual portion, or any additional meetings or information that would be provided to those who are unable to attend but are interested in the site.

Where will the collector substation access road be located?

When are progress payments expected to be made?

Can AEP summarize the locations and voltage levels of the circuits within the allocated BESS space depicted on the General Arrangement in Appendix R-A, and for circuits that are existing between the NE 1,2 existing substation and allocated BESS space?

Is it possible to use the proposed NE 1,2 BESS footprint for the substation location (project substation) to interconnect an external project to the NE 1,2 substation POI?

Can AEP share the height of poles located adjacent to the helipad and any other spacing requirements?

For the NE 1,2 POI, are there restrictions proposing a hybrid facility combining an off-site project (Non-BESS technology) and an on-site BESS project at NE 1,2 while utilizing the NE 1,2 allocated space within the Appendix-R General Arrangement for the project substation?

For a repower project, we are planning to submit technical and commercial specifications the same way we would an operational project, just with our new turbine scenario. Does AEP have any objections/adjustments to Bidder taking this route?

Is there an Appendix that requires energy production profile information? If so, can you please confirm which?

For the Northeastern, Dover, and Rock Falls BESS offerings, would the bidder be responsible for construction of these facilities or would PSO be responsible for construction?

For PPA bids, are bidders required to submit Appendix M (Land Lease, Decommissioning and Property Taxes form)?

In reference to section 4.4 of the RFP document can you please share how firm PSO is in regards to first payment occurring at mechanical completion of the energy storage project? Our company’s standard payment structure requires several progress payments prior to mechanical completion. Is PSO open to negotiate payment terms?

Can the PSO team please opine as to whether certain vendors are approved for this RFP?

Could further elaboration be provided on the requirement in section 4.6 that states "Prices must be firm, representing a best and final bid. Proposals and bid pricing must be valid for at least 270 days after the Proposal Due Date."? As BESS pricing is largely dependent on commodity costs (I.e. lithium) pricing fluctuates regularly and is unlikely to hold firm for 270 days. Could the 270 days of validity timeframe be reevaluated?

Would PSO be open to PPA or PSA bid pricing that would allow for price adjustment (e.g., indexed pricing)? Or does bid pricing have to be fixed in nature?

Could the bidder provide an augmentation schedule to meet 100% of energy capacity at the POI throughout all 20 year of the Battery energy storage system (BESS) lifetime? This augmentation schedule would differ from the degradation criteria outlined in the "Battery Storage Design Criteria Data Sheet_ PSO 2023" document in appendix J.

Please advise if you are only interested in new build projects and/or purchase of asset agreements.

In the cycles section of "Battery Storage Design Criteria Data Sheet_ PSO 2023" of Appendix J, the maximum cycles per year is assumed to be 300. DEPCOM has experience designing and building BESS systems to withstand 365 cycles per year. Could the BESS be designed for 365 cycles/year instead of 300?

For the Northeastern site, there are railway tracks and an access road passing through the area designated as a Battery energy storage system area. Is this railroad and road undergoing deconstruction or is the EPC to consider these areas as non-buildable? Could easements for the road and railway be provided?

Would PSO accept a bid with vendor on PSO's Battery Approved vendor list?

Will you be posting Exhibit L - Emerging Tech Data Reivew Form on the portal?

What Point of Receipt in PSO's system would PSO contemplate for a wind project located in southwestern Kansas?

For PSA bids that include storage (hybrid or standalone), are bidders required to offer both 4-hour and 6-hour designs? Vice versa for PPA bids, are bidders required to both 4-hour and 6-hour designs, or is it up to the bidder's discretion on duration?

If we only plan to submit a PPA bid for a wind project, what information in Appendix H is applicable? As some of the items listed appear to be more geared towards PSA bids?

Are we supposed to submit any of the materials in Exhibit N at this juncture? Or is this just a list of items that will need to be completed if selected?

How does PSO plan to address the fact that SPP's ELCC accreditation methodology for wind and solar is currently not final (given FERC rejection of SPP's ELCC methodology in March 2023), and that the ELCC accreditation calculations are expected to be changing year-over-year (creating dynamic values over time, introducing volumetric changes, notably for wind generation) given that bids are to be fixed and firm for the full term proposed? How will PSO treat this in Capacity Purchase Agreements?

Per the FAQ's "Solar Resources are required to attach an 8760 calendar year hourly energy forecast, net of all losses using the Company’s form spreadsheet (SolarEnergyInputSheet_2023.xls)." Where is this spreadsheet located?

For the Purchase and Sale Agreement option, is PSO open to being a partner in a Limited Liability Company (LLC) with a Tax Equity Investor (TEI)? In this scenario, PSO would purchase 100% of Class B units (owned by the RFP Proponent), and the TEI would continue to own 100% of Class A units. Post-PSO acquisition of 100% of Class B units, the resulting LLC would be a partnership (governed by an LLCA) between PSO and the TEI. Thanks,

Section 4.1.1 (PSA Bid Structure) of the RFP states that “Wind Projects must be designed for a minimum 30-year life” and that “Pricing for Wind Projects must include, but not be limited to, approved wind turbine generators with 30-year life certifications (as sited) from manufacturer…”. In Section 9.19 (RFP Proposal) it states that “New Wind…must have a minimum design life of 30 years”. Does this requirement for “30-year life certification from manufacturer” apply only to NEW wind projects, or also to operational wind? Or does this requirement only apply to PSA bids – if so, just for new wind projects?

Please confirm that Wind SOW Rev. 5 (in Appendix F) is only for PSA bids -- this is presumed as the first paragraph states it is a schedule “attached to the Purchase and Sale Agreement”. Please confirm that Wind SOW Rev. 5 is not applicable to operational wind projects (the document is written in future tense, as if for new builds).

The Schedules and Exhibits of Appendix D - BESS PSA are not included in the document provided in the RFP website. Could you please provide these schedules and exhibits, as they contain information that impacts bid pricing, particularly Exhibit M - Scope of Work and Specifications.

What is the preferred approach, submission of a 70 bid with the option to increase by 30, or submission of a 100 bid?

For Appendix E - Solar / Wind REPA Forms, under section 11.1, there is a Seller Security Fund established as a $100,000 per MW requirement. Does this hold for both the construction and operating term of each project offered as a PPA?

Section 4.2.1 requires that PSA proposal pricing must include the costs associated with “a minimum of two-year comprehensive warranty from a creditworthy entity for all equipment, including design, labor and materials, and fitness for purpose”. Please confirm this is required only for new wind projects, not operational wind projects.

Section 9.2 states, in the definition of “Total Cost”, that “Transmission and Congestion costs will be considered for “PSA Proposals”, but this language is absent in the next sentence, for “PPA bids”. Please clarify if Transmission and Congestions costs will also be considered for PPA proposals.

Could the easement/path for the gas pipeline crossing through "the southernmost section of the project boundary" be provided? This gas pipeline is mentioned in the "PSO_Final_NEU1and2_ConstraintsAnalysis_2023-10-13" document in appendix R-N.

Are BESS projects that are co-located with solar eligible for a Power Purchase Agreement?

Existing natural gas generators are NOT eligible to participate in the PPA portion of the RFP. Only new gas generators may participate in the PPA portion of the RFP. Existing gas generators may participate in the PSA portion of the RFP. Is my understanding correct?

Given the volume of land agreements that any one project may have, will a summarized detail of agreements listing the agreement type, landowner, acreage, and dates suffice for proof of site control?

Is PSO considering extending the RFP due date given the additional site visit planned?

Is the fuel tank active?

Under the Wind REPA (Appendix E) Section 5.6_Scheduling Arrangements, the REPA doesn't specify whether it is the Seller or Purchaser determining the day-ahead offer price for the asset. Please clarify which Party determines the day-ahead price offered into SPP?

With respect to the AEP West Load Zone (AEPM_CSWS), what does CSWS stand for?

Regarding Appendix I and the Solar Modeling Input Sheet, under Site Information the form is asking bidders to provide a map showing buildings or objects shading the array. Could PSO please define and/or provide examples of types of "small objects" that should be noted. Given the nature of this ask, this could be intensive to prepare.

If we plan to bid in a wind resource for a PPA and have one of the offtaker's term ending at 12/31/2028, would you accept a PPA starting on 1/1/2029?

Is there a penalty for withdrawing from the RFP during the review period (or at any time)?

The link in Appendix G is not working. Please provide the Requirements for Connection of Facilities. Is this a requirement that applies to PPA products?

In the RFP FAQ section it is stated, "Completed interconnection study as follows: Except for operating resources, those holding existing interconnection rights and those utilizing PSO's existing interconnection injection rights and/or PSO sites (as specified in Sections 3.8.2 and 3.8.3), projects must be active in SPP Queue Cluster 2021-001 or earlier. Projects in later queue clusters will not be able to participate in this RFP." If a Bidder's project is not in SPP Queue Cluster 2021-001 or earlier but is able to achieve the RFP secondary COD target date would the Bidder's project still be excluded from the RFP?

Is the "Gen 4570 BESS Technical Specification Rev. 6" in Appendix F for PSA products only? I.e. if we are offering a solar PPA with storage option (not a PSA), does the BESS proposal have to satisfy the standards in Appendix F - or only comply with the completed Battery Storage Design Criteria Data Sheet (Appendix J)?

The PSA references an Exhibit W – provisionally approved contractor list. Is this exhibit part of the bid materials?

What are the credit requirements for the RFP?

Can you please provide kmz files for each of the on-site standalone BESS locations (Rock Falls, Dover and Northeastern Units 1 & 2)?

The table under Section 5.4 of the RFP indicates that greenfield storage resources are eligible for PPA bids. Could you please provide the form Power Purchase Agreement that would apply for greenfield standalone storage resources?

Will dual MPTs be required?

What is PSO’s preference for providing commercial and/or legal exceptions to the Form Power Purchase Agreement when offering standalone storage as a capacity, energy, ancillary, etc. resource?

I would like to clarify whether Appendix G (AEP Requirements for Connection of Facilities) is required for resources that are not connecting to AEP’s system, but are still on the SPP system?

What form contract should bidders review and propose changes to for Supplemental Capacity Proposals?

For a Stand-alone, Greenfield BESS resource eligible to submit bids under the PPA and CPA construct which Appendix Document should the Bidder redline for the Bidder's proposal submission? Appendix E (Solar REPA) or Appendix E (Wind REPA)? Bidder does not see in the RFP download documents list a PPA ("Toll") for a SA BESS resource or CPA Appendix Contract document to redline.

For a PPA proposal, what are the transmission wheeling cost requirements for an NRIS project just outside of AEP's service territory but interconnecting into SPP?

Could you please clarify what items under "8.21 PSA bids for Operational Projects" (copied below) are required/not required for exclusively PPA proposals? For example, does a PPA bid require 8760 production data? 8.21 PSA bids for Operational Projects must contain: · Historical operational information over the last 5 years (or less if commercial operation was more recent), including: · Production data (8760) and availability as well as downtime issues and outlook · Congestion and curtailment o Environmental issues and violations o Safety issues o NERC violations and resolution o Major scheduled and unscheduled maintenance matters as well as resolution o Community relations / external affairs issues o Detailed annual operations budgets, including forecasted v. actual · Environmental and permitting summary · List and description of any outstanding legal matters · Facility Site Plan and General Arrangement · List of all warranties · Staffing · Summary of material contracts (interconnection agreement, operations & maintenance agreements, etc.) and confirmation that the project is in compliance with all such contracts, including land leases · Confirmation of whether the project holds firm transmission service and, if applicable, gas transportation capacity and gas supply · Property tax abatements and/or payments in lieu of taxes · Commercial operation date · For solar or wind projects, a description of the tax qualification strategy used to secure Federal Tax Credits for the project

I wanted to confirm if separate appendices are required for different bids iterations. Can we capture all details within a single set of appendices? Project intended to bid. •70 MW PV •70 MW PV + 70 MW BESS (4-hour) •70 MW PV + 70 MW BESS (6-hour)

Is the "Solar Data Review Form" referenced in Appendix I different than the "Solar Energy Input Sheet" or "Solar Modeling Input Sheet"?

For any proposed standalone storage bids onsite at Dover, Rock Falls or Northeast Units 1 & 2, must those proposals include all relevant information on the Appendix Q Proposal Content Checklist or only Appendix J (Energy Storage Resource Information)?

Recognizing PSO is making Units 1 & 2 of Northeastern available in this RFP, is there also a surplus interconnection opportunity at Unit 3 given its anticipated retirement in 2026?

The RFP document in Appendix A indicates that supplemental capacity for energy storage is priced in $/MWh. This is unusual as this product is generally priced as $/kW-mo. Can you confirm this should be priced similar to the Gas offers in $/kW-mo?

Appendix A references a Bundled Price ($/MWh) for a Wind or Solar Base Proposal with Storage Option, yet the BESS Tolling Agreement states that Purchaser will pay Seller the storage contract price equal to $/kW/month for all storage products. Can you please advise?

Can PSO define what is factored into union labor for the proposal bid pricing?

Will projects outside of the three mentioned sites with interconnection rights, with a COD before the cutoff date, but queued after DISIS Gen 2021-001 be reviewed as nonconforming bids, or will they be denied outright?