SCPPA New Resource and Transmission RFP Addendum 5 - Updated RFP Timeline/Schedule

"NOTICE - THIS DOCUMENT HAS BEEN MODIFIED BY THE ADDENDA TO THE
RFP. PLEASE REFER TO THE RFP ADDENDA FOR LATEST VERSION."
SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY
REQUEST FOR PROPOSALS FOR
New Resource and Transmission
ISSUANCE RESPONSE
January 30, 2026 August 31, 2026
DATE: DEADLINE:
I. INTRODUCTION
The Southern California Public Power Authority (SCPPA), on behalf of its member agencies
(Member Agencies) is issuing this Request for Proposals (RFP) with the intent to procure and
connect renewable and carbon-free generation resources (with or without energy storage solutions)
and associated transmission infrastructure directly to the designated Points of Delivery (PODs)
listed in Section V within the Los Angeles Department of Water and Power (LADWP) Balancing
Authority Area. Respondents to this RFP (Respondents) are responsible for constructing and
providing the necessary transmission infrastructure to ensure energy can be delivered efficiently to
the listed PODs. An energy storage component may be included with a proposed energy project as
set forth below in Section V. However, stand-alone energy storage projects are not included in this
RFP. Stand-alone energy storage projects may be proposed under SCPPA's separate Standalone
Energy Storage RFP posted biannually, and located here: https://scppa.org/rfps-bids/rfps-
resourceproject/.
California's Renewables Portfolio Standard (RPS) program was established by Senate Bill (SB)
1078, and has been subsequently modified by SB 107, SB 1036, SB 2 (1X), SB 350 and SB 100.
The RPS program is codified in Public Utilities Code Sections 399.11-399.33. Eligible products
should comply with the California Renewable Energy Resources Program (Public Resources Code sec.
25740 et seq.) and the California RPS program.
SCPPA and its participating Member Agencies are targeting proposals for projects with commercial
operation or delivery starting in 2036 or later, supporting the goal of 100% fossil-fuel free electricity
by 2045 or earlier. Selected projects may be selected for execution of a power purchase agreement
with an ownership option (PPA). The resulting PPA may be executed by SCPPA or the participating
Member Agency (such entity is referred to in this RFP as the "Buyer").

New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
The deadline to submit Proposals for this RFP is August 31, 2026, as described further in Sections
IV and VII.
II. BACKGROUND
SCPPA is a joint powers authority and a public entity created by its Member Agencies pursuant to the
California Joint Exercise of Powers Act (found in Chapter 5 of Division 7 of Title 1 of the Government
Code of the State of California.) and through the SCPPA Joint Powers Agreement for the purpose of
planning, financing, developing, acquiring, constructing, operating, and maintaining project for the
generation or transmission of electric energy and associated products and services. SCPPA is a
"cafeteria style" joint powers authority where Member Agencies can select the projects that they are
interested in pursuing at any time during the open period of the RFP. SCPPA can procure resources on
behalf of one or more of its Member Agencies.
Member Agencies comprise eleven cities and one irrigation district that provide retail electric service to
customers within their respective jurisdictional boundaries. Member Agencies are the cities of Anaheim,
Azusa, Banning, Burbank, Cerritos, Colton, Glendale, Los Angeles, Pasadena, Riverside, and Vernon,
and the Imperial Irrigation District. Anaheim, Azusa, Banning, Cerritos, Colton, Pasadena, Riverside, and
Vernon are in the California Independent System Operator's (CAISO) Balancing Authority Area (BAA).
Los Angeles, Burbank, and Glendale are in the LADWP BAA. The Imperial Irrigation District operates its
own BAA.
SCPPA is governed by a Board of Directors (Board), which consists of a representative from each of its
Member Agencies. The management of SCPPA is under the direction of an Executive Director who is
appointed by the Board. Member Agencies' electric utilities are governed by their respective city councils
or other locally elected governing bodies.
Many Member Agencies have established voluntary renewable targets, including the percentage of
renewable energy they wish to obtain within their portfolio. California legislation, including SB 100,
requires retail sellers and local publicly owned electric utilities to procure a minimum quantity of electricity
products from eligible renewable energy resources so that the total kWh of those products sold to their
retail end-use customers achieve 60% of retail sales by December 31, 2030. California law also
establishes a state policy that eligible renewable energy resources and zero-carbon resources supply
90% of all retail sales of electricity to California end-use customers by December 31, 2035, 95% by
December 31, 2040, and 100% by December 31, 2045.
III. AREAS OF INTEREST
The minimum capacity size that may be proposed in response to this RFP is 100 MW.
Member Agencies seek tangible and timely opportunities to add proven renewable technologies to their
generation portfolios and thus will not entertain experimental or speculative proposals.
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1. Ownership Participation
SCPPA is well positioned and experienced in facilitating joint ownership structures for renewable energy,
carbon-free energy, energy storage projects, and transmission infrastructure projects for the benefit of
Member Agencies. SCPPA can acquire an ownership interest in a project and sell 100% of the output to
interested Member Agencies at SCPPA's cost. SCPPA or its Member Agencies may also enter into PPAs,
either with or without an option to purchase the project during the term of the agreement. Proposals
submitted in response to this RFP must include an option to purchase a project during the term of a PPA.
Whether the project is structured as a PPA with an ownership option or an outright ownership, SCPPA
and Member Agencies request the structure to consider and include opportunities for all parties to benefit
and take advantage of state and/or federal legislation, including tax incentives, grant opportunities, and
other incentives as available.
2. Regulatory Compliance
SCPPA continues to seek cost-effective resources to support Member Agencies' RPS and carbon-free
objectives for 2026 and beyond. This RFP seeks to find the best combination of projects or products to
deliver energy from facilities that will be RPS compliant (pursuant to Public Utilities Code Sections 399.16
(b)(1), (b)(2) and (b)(3), i.e., energy and associated Renewable Energy Credits (RECs) in Portfolio
Content Category 1, 2 and 3, and compliant with the emissions performance standard (EPS) regulations
adopted by the California Energy Commission (20 Cal. Code of Regulations section 2900 et seq.) upon
Commercial Operation Date (COD) and throughout the term of the agreement. Projects shall be carbon-
free and comply with all applicable federal laws and regulations, California laws and regulations, including
RPS program requirements, and prudent utility practices, including but not limited the standards
established by the North American Electric Reliability Corporation (NERC) and Western Electricity
Coordinating Council (WECC).
3. Project Requirements
Project requirements include but are not limited to the following. Please also refer to Section V of this
RFP and the Term Sheet and other documents attached as Appendices to this RFP for additional
information and requirements.
* Regulatory Compliance: Buyer requires that during the term of the PPA, Respondent shall
assume the risk of maintaining and bringing the facility or project into compliance should there be
a change in law that renders the facility noncompliant with regulatory mandates, including RPS,
EPS, and other clean energy mandates as described in the Term Sheet attached as Appendix
A.
* Buyer's Step in Right: Respondent will be responsible for site control. Buyer must be allowed to
assume or cure any default by Respondent in the site control documents.
* Environmental Liabilities: Respondent will be responsible for environmental liability, hazardous
materials, and removal.
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New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
* Environmental Attributes: Buyer shall receive all environmental attributes associated with the
generation facility and its output, including but not limited to renewable energy credits and air
emissions credits or offsets (i.e., greenhouse gas credits at the location of source and for the
gross output of the plant or otherwise credited).
* Permitting: Respondent will be responsible for obtaining all construction, operational, and
environmental permits and licenses and construction financing for the project and facility.
IV. RFP TIMELINE / SCHEDULE*
NEW RESOURCE AND TRANSMISSION RFP
TIMELINE
SCHEDULE OF REQUIREMENTS TARGET DATE(S)
Issue RFP January 30, 2026
RFP Open Period January 30, 2026-August 31, 2026
Optional Pre-Bidders Meeting 1 February 23, 2026
Optional Pre-Bidders Meeting 2 March 23, 2026
Clarification Questions Due On or Before June 12, 2026
10 Business Days
Responses to Clarification Questions Due
After Submitted
Proposals Submittal Deadline August 31, 2026
*Timeline/Schedule is subject to change.
V. PROPOSAL SUBMISSION REQUIRED ELEMENTS
1. TRANSMITTAL LETTER CONTENT:
A. An officer authorized to bind Respondent must sign the proposal on behalf of
Respondent and must include the following declarations on the transmittal letter:
"This proposal is genuine, and not sham or collusive, nor made in the interest
or in behalf of any person not herein named; Respondent has not directly or
indirectly induced or solicited any other Respondent to put in a sham bid, or any
other person, firm or corporation to refrain from submitting a proposal; and the
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New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
Respondent has not in any manner sought by collusion to secure for itself
an advantage over any other Respondent."
2. RESPONDENT INFORMATION:
Provide legal name of Respondent company or individual, physical street address, the name(s) and
title(s) of the individual(s) authorized to represent Respondent, including telephone number(s) and
email address(es). If the Respondent is a Joint Venture, please provide such information regarding
all entities that form part of the Joint Venture company.
3. RESOURCE TECHNOLOGY TYPE:
Clearly identify the proposal as one or more of a combination of one or more of the following renewable
and/or carbon-free generation resources complying with the current edition of the California Energy
Commission Renewables Portfolio Standard Eligibility Guidebook (CEC Guidebook) or carbon-free
mandates:
a. Solar, including all photo-voltaic and photo-optic technologies where light is directly converted to
electricity. Any solar overbuild beyond 1.2 DC/AC ratio should be noted. If there is a hybrid energy
storage with the facility, please provide a description of how the energy storage facility will be
charged.
b. Wind, including all air-flow technologies involving a turbine of any type (i.e., offshore, or onshore).
c. Geothermal, including all temperature gradient technologies.
d. Hydro, including all mass-in-motion technologies involving fluids and hydro efficiency
improvements.
e. Solar Thermal, including all concentration technologies where a heat transfer medium is used to
generate electricity.
f. Fuel cell utilizing a renewable fuel such as hydrogen that uses green hydrogen technologies.
g. Flexible resources, such as wind, solar, and/or geothermal with the ability to ramp up/down to
provide reserve margins and other grid benefits.
h. Hydrogen, the production and utilization of green hydrogen technologies.
i. Hybrid projects: resources may be bundled together but pricing options for individual technologies
should be itemized. Include hourly seasonal guarantee capacity factors for both the renewable
resource only, as well as for renewable resource plus battery storage.
j. Energy Storage combined with renewable energy projects; energy storage with a capacity of at
least one half the total interconnection capacity offered by the renewable resource.
k. Nuclear (i.e., Small Module Reactors).
4. ASSOCIATED TRANSMISSION INFRASTRUCTURE:
Respondent shall provide a well-developed plan for the design, permitting, and construction of any
associated transmission infrastructure necessary to interconnect the proposed resource to the designated
PODs. Generation resources must be developed in conjunction with the transmission infrastructure,
which deliver to the Los Angeles basin via new transmission by the COD. All associated costs must be
included in the proposed pricing.
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5. CO-LOCATED ENERGY STORAGE SOLUTIONS (ESS):
Member Agencies have a strong interest in the rapidly developing energy storage market, and certain
Member Agencies have energy storage targets beyond the targets specified in AB 2514. All types of
energy storage technologies are open for consideration when combined with a qualified renewable
energy resource to be added into Member Agencies' resource portfolios, if they are determined to be
cost-effective. Separate stand-alone ESS are not a part of this RFP. Standalone ESS proposals may
be submitted in response to SCPPA's Standalone Storage RFP.
6. INFLATION REDUCTION ACT OF 2022 (IRA) AND TARIFF CONSIDERATIONS:
Respondent must identify any benefits, opportunities, and risks associated with the IRA for any
proposed project structures, as well as any specific pricing impacts, and assumptions regarding
IRA tax credits, and the necessary obligations, including timelines, to achieve such benefits and
/or bonuses. Respondent must also clearly identify any contingencies in the event that the IRA
benefits are reduced, or made unavailable, due to evolving federal policy or tariffs. IRA
considerations may include, but are not limited to:
a. Investment Tax Credits for PPAs
b. Productions Tax Credits for PPAs
c. Domestic Content Bonus Credit
d. Wage and Apprenticeship Credit
e. Energy Community Bonus Credit
f. Low-Income Communities Bonus Credit
g. Direct Pay Credits/Benefits for SCPPA Ownership
h. Other credits and/or bonuses under the IRA or subsequent revisions
7. PROJECT DETAILS:
Clearly identify the proposed project, including the following information:
a. Project Description: Project names and locations, and phases of development, if applicable.
b. Contract Quantity: In MW and GWh/year, and by project phase if applicable, including
nameplate rating and proposed amount of energy to be delivered. Specify the guaranteed
capacity for each contract year. Please provide all MW increment options available for the
project.
c. Pricing: Please provide pricing structure as described below. Any price increase
subsequent to proposal submittal could result in a disqualification.
i) Energy Price (fixed): Expressed in nominal dollar value (as of the year of COD) in
$/MWh, with no escalation, covering energy, capacity right, RECs, transmission costs,
and all other products.
ii) Energy Storage Price: In addition to the energy price, Respondents shall provide a
separate price for energy storage (if proposed). Storage pricing shall be expressed in
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New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
nominal dollars (as of the year of COD) with no escalation and provided in $/MWh and
$/kWmonth. If proposals include energy storage, Respondents shall also provide the
project price excluding energy storage.
iii) Other Price Structures: If the proposal is for an agreement other than a PPA, please
describe the proposed structure in detail and provide information on pricing with an
explanation for such costs.
d. Delivery Term: Minimum term is 10 years with no maximum as the various Member Agencies are
seeking long-term (greater than 10 years) delivery of energy. Long-term delivery is defined in the
CEC Guidebook. Please provide all delivery term options available, including seasonal and/or
intra-day delivery profile options.
e. Energy Availability: Maximum and minimum monthly capacity factors (for hybrid projects, please
provide capacity factors for both resources, as well as for a resource with battery storage),
seasonal shapes, resource availability profile (i.e., 8760 resource profile of availability), reliability
indices (reliability of the distribution system distribution indices to potentially forced outage ratios
or planned outage ratios of generators), dispatchability (by unit or phase if applicable) and
scheduling requirements/limitations, if any, any rights for Buyer to perform full or partial dispatch
and economic curtailment.
f. Transmission Infrastructure: Respondents shall be responsible for designing, permitting and
building the dedicated transmission infrastructure and everything needed to connect the project
site and deliver the generation to the selected PODs.
i) All costs (including land rights, interconnection facilities, upgrades, construction, and
ongoing maintenance) must be included in the proposed energy pricing.
ii) The transmission infrastructure must be fully owned and operated by Respondent for the
entire contract term and comply with all applicable reliability and interconnection
standards.
iii) Respondents should describe their approach to risk assessment, schedule management,
and subcontractor selection, and provide evidence of bonding capability and financial
ability to complete the work.
iv) All other associated transmission infrastructure shall be fully operational by the project's
COD and maintained in compliance with all regulatory and operational standards
throughout the contract term.
g. Point of Delivery (POD): The following locations are delivery points from which one or more of
the Member Agencies can receive energy. Each POD is assigned to a group (e.g., Group A, B,
C). The maximum energy each group can accept is as follows.
i) Group A: 500 MW by 2036
* PODs included in this group:
Harbor 138kV Generating Station
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New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
ii) Group B: 1000 MW by 2036
* PODs included in this group:
Scattergood 230kV Generating Station, Fairfax 138kV Receiving Station, and
Century 230kV Receiving Station
iii) Group C: 1500 MW by 2036
* PODs included in this group:
Haynes 230kV Generating Station
Cost of transmission and delivery to the POD shall be included in the price of energy. The above
listings represent locations where Member Agencies may have existing capacity rights.
Where applicable, project point of delivery through CAISO must include a $/MWh price adder for
delivery through CAISO that is fixed for the duration of the contract term if energy is exported.
The proposed $/MWh price adder should be viewed as an export through CAISO if not a pseudo-
tie and include all transmission- and generation-related fees imposed by CAISO. The point of
delivery to the CAISO must indicate whether the project qualifies for Resource Adequacy and/or
Local Capacity Requirement capacity benefits.
Additional Groups and PODs may be added to this RFP via Addendum in the future.
Additionally, to assist in developing proposals that best match the specific needs of
LADWP, a desired profile of energy to be delivered will be provided in a soon-to-be
released Addendum.
Note: Project evaluations will include the full cost of delivery to the customers of Member
Agencies within Southern California.
h. Grid Charging: If energy storage is included, specify Buyer's ability to charge the energy storage
system with grid energy. Indicate price impacts for varying levels of grid charging % defined as
allowed volume of grid charging energy divided by total charging energy by energy storage
system per year.
i. Category of Environmental Attributes: Specify whether the project qualifies for Portfolio
Content Categories 1, 2 or 3 ("bucket 1, 2 or 3"); and "short-term" or "long-term" under the
California Public Resources Code (CPRC) and how the project would comply with the CPRC
and any future interpretations of relevant statutes by the California Energy Commission.
j. Capacity Rights/Shared Facilities: Ensure that Buyer shall receive all capacity rights
associated with the project and/or its produced energy, including but not limited to
resource adequacy, where applicable.
i) Identify any energy and/or associated project capacity to be provided/committed to
parties other than Buyer.
ii) Identify any project supporting/associated facilities that require shared use or third-party
access rights, such as intermediate distribution infrastructure, control rooms, or other
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New Resource and Transmission RFP: 1/30/2026 - 8/31/2026
intermingled facilities. Describe any controls or provisions to assure the continuation of
the described project capacity, e.g., for wind proposals, any adjacent or future proposals
encroaching on turbine spacing or airflow; for hydro proposals, any limitations, or
regulations on water flow, diversion, or water reservoir level maintenance requirements;
and other potential impacts on the proposed project.
k. Ownership Options: Proposals must include an offer of ownership to Buyer. Please describe the
proposed ownership, terms and conditions, floors and ceilings for purchase prices at different
option dates, beginning after Federal Investment Tax Credit (ITC) and/or Federal Production Tax
Credit (PTC) recapture if applicable, and up to the end of the term, and ownership structures (e.g.,
100% Buyer-owned turn-key, corporation, general partnership, limited partnership, etc.).
i) In the case of an offer of initial ownership to Buyer, a purchase price at COD shall be
specified (and expressed as $/kW) along with an estimate of all recurring owner costs,
including but not limited to operation and maintenance costs, taxes, lease payments,
royalties, and insurance.
ii) For any offer of a PPA with a purchase option, the proposal shall include (a) a buyout price
or detailed formula to calculate such a buyout price for each future date on which a buyout
would be offered; (b) conditions for buyout, such as expiration of ITC or PTC recapture
period or other project events; and (c) an energy price in $/MWh without the buyout option.
iii) For PPAs, terms up to the life of the facility will be considered.
iv) No changes to a PPA will be permitted during project financing or a change in control
event.
l. Project Plan to COD: Identify the proposed COD and provide a satisfactory major milestone
schedule that includes at least the following:
i) Proposed schedule for obtaining and developing site access and control through
executed leases, fee purchases, approvals, or other means.
ii) Details of any prior or existing settlements made for environmental mitigation and clearly
identified post-construction or pass-forward mitigation obligations that would be forwarded
to Buyer in the event a contract is executed (e.g., reserve or offset land for environmental
habitat or reconstruction).
iii) Proposed schedule for obtaining construction, operational, and environmental permits
and licenses, construction financing, agreement negotiation, and contract execution.
iv) Proposed construction schedule, including expected construction start date, major
equipment purchasing, anticipated factory acceptance testing of major components, site
tests, commencement of test energy delivery and COD. Identify the source country(ies)
for all major equipment to be procured and the status of procurement efforts. If a Member
Agency is in the Energy Imbalance Market (EIM) and Energy Day Ahead Market
(EDAM), successful acceptance into the EIM and EDAM, as applicable, is required prior
to the delivery of any test energy. Respondent shall submit sufficient technical design
data to Buyer at least twelve months prior to delivery of any test energy in order to assist
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Buyer in the EIM and EDAM application process, as applicable.
v) For projects or operations requiring water or makeup water, description of the water
supply requirements and provisions for supply.
vi) Proposed schedule or application status to acquire necessary transmission and
interconnection service.
vii) Description of whether and to what extent any environmental studies have been carried
out with respect to the proposed project and how compliance with the California
Environmental Quality Act, which is a requirement before an agreement can be executed
by Buyer, might be effectuated, including, if the project is located outside California, how
Title 14 Section 15277 of the California Administrative Code is or will be addressed by the
project.
viii) Commentary to what extent a Project Labor Agreement could be established.
ix) Note that any test energy delivered before the COD shall be curtailable at any time by
Buyer without compensation.
x) Note that the project shall be certified as RPS-eligible by the California Energy
Commission no later than 180 days after COD.
xi) Note that the project shall be registered in WREGIS no later than 3 months before COD.
m. Power Purchase Agreement Term Sheet: Please provide as much information as possible in
Appendix A, New Resource and Transmission Term Sheet (posted as a separate document, link
available at http://scppa.org/page/RFPs-ResourceProject).
n. Applicable to Proposals including Energy Storage Solutions (ESS) in LADWP's Balancing
Authority Area only: Provide as much information as possible in Appendix B, Energy Storage
Specifications (posted as a separate document, link available at http://scppa.org/page/RFPs-
ResourceProject).
o. Financing and Tax Equity Investor: Describe how the project will be financed such as by
parent company, backflip leverage, or other specified financing structure.
p. Credit Support and Security: Express in nominal dollars the amount of performance
assurance provided from execution of the PPA through COD and the amount of performance
assurance provided after COD as a letter of credit.
q. Buyer Economic and Operational Curtailment: Buyer has the right to curtail output of the
facility for economic purposes annually in an amount equal to the guaranteed capacity x 50
hours.
r. Interconnection Agreements: Provide the status of the project's interconnection agreements
and expected timeline for completion, along with proposed schedule for obtaining and developing
interconnection to POD, through executed leases, fee purchases, approvals and other means. The
schedule should account for any network upgrades identified by the interconnection or affected
interconnection processes.
s. Site Control: Provide the status of the project's site control and expected timeline for completion.
Express whether site control is through a lease or if it will be purchased.
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