Agenda packet — Orange County Power Authority Board of Directors, April 14, 2025

AGENDA

ORANGE COUNTY POWER AUTHORITY

REGULAR MEETING OF THE BOARD OF DIRECTORS
Monday, April 14, 2025
4:30 p.m.

This meeting will proceed as an in-person meeting at 15310 Barranca Parkway, Suite 250, Irvine, CA 92618, and 1302 W. Peachtree St. NW, Atlanta, GA, 30308. In addition, as a convenience to the public, the Orange County Power Authority is also providing an option for members of the public to remotely view and participate in the meeting. Further details are below. Please note that, in the event of a technical issue causing a disruption in the remote participation option, the meeting may continue unless otherwise required by law.

Public Comments: Any member of the public may provide comments to the Orange County Power Authority Board of Directors on any agenda items by requesting to speak during Item 4, or on any matter not appearing on the agenda but within the jurisdiction of the Board by requesting to speak during Item

5. When providing comments to the Board, it is requested that you provide your name and city of residence for the record. Commenters are requested to address their comments to the Board as a whole through the Chair. Comments may be provided in the following manner:

To provide comments during the meeting, in-person attendees, please fill out the public speaker slip and provide it to the clerk at the beginning of the meeting. Before Items 4 and 5, the Chair or Clerk will ask members of the public to join the queue to provide public comment. The queue will remain open for a reasonable amount of time to allow members of the public sufficient time to request to speak and inform the Board of the number of speakers. After such time, the queue will be closed and the members of the public who have joined the queue to speak will be recognized at the appropriate time may speak. To join the queue on Zoom video conference by computer or mobile phone, use the “Raise Hand” feature. If joining the meeting using the Zoom dial-in number, you can raise your hand and join the queue by pressing *9. Members of the public will not be shown on video but will be able to speak when called upon.

Comments shall generally be limited to three minutes when speaking, provided that the Chair may equally reduce each speaker’s time to accommodate a large number of speakers or a large number of agenda items.

Written Communications: If you have a written communication that you wish to be distributed to the Board, please provide it via e-mail to [email protected]. Written communications are public records and, if received by 5:00 p.m. on the day prior to the meeting, will be distributed to the Board prior to the meeting by either e-mail or hard-copy, posted on the Authority’s website and noted, but not read, at the meeting. Communications received after the 5:00 p.m. deadline will be retained in the Authority’s records.

The public may participate using the following remote options:

ZOOM WEBINAR
Please click the link below to join the webinar:

Launch Meeting - Zoom
Dial-in: 1-669-900-6833
Webinar ID: 876 3556 3773

1. CALL TO ORDER

2. PLEDGE OF ALLEGIANCE

3. ROLL CALL

4. PUBLIC COMMENTS ON AGENDA ITEMS
Opportunity for members of the public to address the Board on any items on the agenda.

5. PUBLIC COMMENTS ON NON-AGENDA ITEMS
Opportunity for members of the public to address the Board on any items not on the agenda but within the jurisdiction of the Board.

6. DIRECTOR ANNOUNCEMENTS & REPORTS ON CONFERENCES/EVENTS

ATTENDED
Board Members may briefly provide information to other members of the Board and the public, ask questions of staff, or report on conferences, events, or activities related to Authority business. There is to be no discussion or action taken on comments made by Board Members unless authorized by law.

7. CONSENT CALENDAR
All items listed under the Consent Calendar are considered to be routine and may be enacted by one motion. Prior to the motion to consider any action by the Board of Directors, any public comments on any of the Consent Items will be heard. There will be no separate action unless members of the Board of Directors request specific items be removed from the Consent Calendar.

1. MINUTES FOR THE SPECIAL BOARD MEETING OF MARCH 21, 2025 Recommended Action:

Approve as submitted.

2. MINUTES FOR THE REGULAR BOARD MEETING OF MARCH 10, 2025 Recommended Action:

Approve as submitted.

3. COMMUNITY ADVISORY COMMITTEE (CAC) REPORT
Recommended Action:

Receive and file.

4. LEGISLATIVE AND REGULATORY UPDATE
Recommended Action:

Receive and file.

5. RATIFY RATES EFFECTIVE MARCH 24, 2025
Recommended Action:

Ratify rates effective March 24, 2025.

8. REGULAR CALENDAR
The following items call for discussion or action by the Board of Directors. The Board may discuss and/or take action on any item listed below if the Board is so inclined.

1. COMMUNITY POWER PLAN AND OTHER OUTREACH SERVICES RFQ

ANALYSIS AND RECOMMENDATION
Recommended Actions:

1. Receive panel recommendations for Request for Qualifications for Community Power Plan Outreach & Other Services solicitation.

2. Direct staff to negotiate and establish an agreement for Community Power Plan Outreach Services with the Asian Business Association of Orange County.

3. Authorize the Chief Executive Officer to establish outreach services agreements, consistent with OCPA’s Procurement Policy No. 1, with recommended vendors as needed for the development of the Community Power Plan and the administration of the Equitably Building Decarbonization – Direct Install grant.

2. APPROVAL OF SOLAR REBATE AND EV CHARGER REBATE PROGRAM Recommended Actions:

1. Approve the launch of a Solar and Battery Rebate Program, and an Electric Vehicle (EV) Charger Rebate Program. The Solar and Battery Rebate Program will provide a $1,000 rebate for solar panels with battery storage or battery storage alone. The EV Charger Rebate Program will provide a not-to-exceed $1,000 rebate for residential Level 2 EV chargers on the OCPA Marketplace, making them no cost after rebate.

2. Authorize the Chief Executive Officer to take all necessary actions to implement, administer, monitor, manage, and ensure compliance with the programs, including but not limited to adopting, amending, executing and enforcing terms and conditions for program participation.

3. ENERGY STORAGE SYSTEMS UPDATE
Recommended Action:

Receive and file.

9. STAFF REPORT
Staff may briefly provide information to the Board and the public. The Board may engage in discussion if the specific subject matter of the report is identified, but the Board may not take any action. There is to be no other discussion or action taken unless authorized by law.

10. ADJOURNMENT
Compliance with the Americans with Disabilities Act
Board of Directors meetings comply with the protections and prohibitions of the Americans with Disabilities Act. Individuals with a disability who require a modification or accommodation, including auxiliary aids or services, in order to participate in the public meeting may contact 949- 263-2612. Requests for disability-related modifications or accommodations require different lead times and should be provided at least 72-hours in advance of the public meeting.

Availability of Board Documents
Copies of the agenda and agenda packet are available at www.ocpower.org. Late-arriving documents related to a Board meeting item which are distributed to a majority of the Board prior to or during the Board meeting are available for public review as required by law. Public records, including agenda-related documents, can be requested electronically at [email protected] or by mail to 15642 Sand Canyon Avenue, P.O. Box 54283, Irvine, CA 92619-4283. The documents may also be posted at the above website. Such public records are also available for inspection, by appointment, at 15310 Barranca Parkway, Suite 250, Irvine, CA 92618. Please contact [email protected] to arrange an appointment.

OCPA ACRONYM LIST
Last revised on 4/7/2025
Displaying regularly used acronyms is beneficial for public agencies, enhancing clarity and efficiency in communication. OCPA’s Acronyms Lists contain terms that are often used and abbreviated to simplify complex terms and processes, making information more accessible to both employees and the public.

Our hope is to ensure that everyone understands the terminology we use, reducing confusion, and misunderstandings. When members of the public can easily decode acronyms, they feel more informed and engaged with the agency's operations. This practice also supports training and onboarding efforts, as new employees can quickly familiarize themselves with commonly used terms, accelerating their integration into the team.

AB Assembly Bill
ACC Avoided Cost Calculator
AL Advice Letter
ALJ Administrative Law Judge
ARB Air Resource Board
BA Balancing Authority
BESS Battery Energy Storage System
BioMAT Bioenergy Market Adjusting Tariff
C&I Commercial & Industrial
CAISO California Independent System Operator
CALCCA California Community Choice Association
CAM Cost Allocation Mechanism
CAPP California Arrearage Payment Program
CARB California Air Resources Board
CARE California Alternate Rates for Energy (Low Income Discount Rate) CCA Community Choice Aggregation
CEC California Energy Commission
CEC California Energy Commission
CP compliance period
CPE Central Procurement Entity
CPP Critical Peak Pricing
CPUC California Public Utilities Commission
CRR Congestion Revenue Right
DA Direct Access (Private Retail Energy Supplier)
DAC Disadvantaged Community (As Defined by Calenviroscreen 3.0) DAME Day-Ahead Market Enhancements
DCPP Diablo Canyon Power Plant
Demand
The rate at which electric energy is delivered to or by a system or part of a system, generally expressed in kilowatts (kW), megawatts (MW), or gigawatts (GW), at a given instant or averaged over any designated interval of time. Demand should not be confused with Load or Energy DER Distributed Energy Resources
DER Distributed Energy Resources
DERMS Distributed Energy Resource Management System
Distribution The delivery of electricity to the retail customer’s home or business through low voltage distribution lines
DLAP Default Load Aggregation Point
DR Demand Response
DRP Distributed Resource Plans
DWR Department of Water Resources
ECR Enhanced Community Renewable
ED Energy Division
ED Energy Division
EDAM Extended Day-Ahead Market
EE Energy Efficiency
ELCC Effective Load Carrying Capacity
ELRP Emergency Load Reduction Program
EPIC Electric Program Investment Charge
ERRA Energy Resource Recovery Account (SCE Generation Rate Setting) ERRA Energy Resource Recovery Account
ES Energy Storage
ESA Energy Storage Agreement
ESP Energy Service Provider
EV Electric Vehicle
EVSE Electric Vehicle Supply Equipment (EV Charger)
FERA Family Electric Rate Assistance (Low Income Discount Rate) FERC Federal Energy Regulatory Commission
GHG Greenhouse Gas
GRC General Rate Case
GTSR Green Tariff Shared Renewables
GWh Gigawatt-hour
ICA Integration Capacity Analysis
IDER Integrated Distributed Energy Resources
IDSM Integrated Demand-Side Management
IEPR Integrated Energy Planning Report
IGFC Income-Graduated Fixed Charge
IOU Investor-Owned Utility
IOU Investor-owned utility
IRP Integrated Resource Plan
JPA Joint Powers Authority
kW Kilowatt
kWh Kilowatt-hour
LCFS Low Carbon Fuel Standard
LCR Local (RA) Capacity Requirements
LMP Locational Marginal Price
LMS Load Management Standards
LNBA Locational Net Benefits Analysis
Load An end use device or customer that receives power from an energy delivery system
LOLE Loss of load expectations
LSE Load Serving Entity
LTPP Long-Term Procurement Rulemaking
MB Medical Baseline (Discount Rate for Medical Equipment Needs) MEO Marketing Education and Outreach
MPB Market Price Benchmark
MTR Mid Term Reliability
MW Megawatt
MWH Megawatt-hour
NBC Non-Bypassable Charge
NBC Non-Bypassable Charge
NBT Net Billing Tariff (NEM 3.0) Also known as Solar Billing Tariff or Solar Billing Plan
NDA Non-Disclosure Agreement
NEM Net Energy Metering (Usually for Customers with Solar) NP-15 North Path 15
OAT Other Applicable Tariffs
OIR Order Instituting Rulemaking
OSC Order to Show Cause
OSW Offshore Wind
PA Program Administrator
PCC1 Renewable Energy Generated Inside California
PCC2 Renewable Energy Generated Outside California
PCC3 A REC from A Renewable Resource, Delivered Without Energy PCIA Power Charge Indifference Adjustment
PCL Power Content Label
PD Proposed Decision
PfM Petition for Modification
PG&E Pacific Gas & Electric
PHC Prehearing Conference
Pnode Pricing Node
POLR Provider of Last Resort
POU Publicly owned utility
POU Publicly Owned or Municipal Utility
PPA Power Purchase Agreement
PRP Priority Review Project
PRRR Progress on Residential Rate Reform
PSD PowerSource Disclosures
PSPS Public Safety Power Shutoff
PUC Public Utilities Code
PURPA Public Utilities Regulatory Policy Act
PV Photovoltaic (Solar) Panels
RA Resource Adequacy
RAM Renewables Auction Mechanism
RCPPP Reliable and Clean Power Procurement Program
RE Renewable Energy
REC Renewable Energy Credit or Renewable Energy Certificate RES-BCT Renewables Energy Self-Generation Bill Credit Transfer RFI Request for Information
RFO Request for Offers
RFP Request for Proposals
RFQ Request for Qualifications
RIN Rate Identifier Number
RPS Renewable Portfolio Standard
SB Senate Bill
SBT/SBP Solar Billing Tariff/Solar Billing Plan
SCE Southern California Edison
SDG&E San Diego Gas & Electric
SGIP Self-Generation Incentive Program
SOD Slice of Day
T&D Transmission and Distribution
TBS Transitional Bundled Service
TE Transportation Electrification
Time-of-Use
(TOU) Rates
The pricing of delivered electricity based on the estimated cost of electricity during a particular time-block
TOU Time Of Use (Used to Refer to Rates that Differ by Time Of Day) TPP Transmission Planning Process
Unbundled RECs
Renewable energy certificates that verify a purchase of a MWH unit of renewable power where the actual power and the certificate are “unbundled” and sold to different buyers.

VAMO Voluntary Allocation, Market Offer
VPP Virtual Power Plant
WECC Western Electricity Coordinating Council
WEIM Western Energy Imbalance Market
WREGIS Western Renewable Energy Generation Information System

MINUTES

SPECIAL MEETING

BOARD OF DIRECTORS

ORANGE COUNTY POWER AUTHORITY
Friday, March 21, 2025
OCPA Board Special Meeting of March 21, 2025 Page 1

1. CALL TO ORDER
Chair Sonne called to order the Special Meeting of the Orange County Power Authority Board of Directors at 4:31 p.m. on Monday, March 21, 2025.

2. PLEDGE OF ALLEGIANCE
Director Go led the Pledge of Allegiance.

3. ROLL CALL

Present: Director William Go City of Irvine
Director Glenn Grandis City of Fountain Valley
Director Fred Jung City of Fullerton
Vice Chair James Mai City of Irvine
Chair Susan Sonne City of Buena Park

4. PUBLIC COMMENTS ON AGENDA ITEMS
None.

5. ANNUAL BOARD STRATEGIC PLANNING WORKSHOP
Chair Sonne requested that staff facilitate the workshop.

Chair Sonne recessed the Board at 10:25 a.m.

Chair Sonne reconvened the Board at 10:47 a.m. with all five members present.

Chair Sonne recessed the Board at 11:53 a.m. for lunch.

Director Jung left the meeting at 12:00 p.m.

Chair Sonne reconvened the Board at 12:40 p.m. with four members present.

Actions Taken:

1. Participation, discussion, and identification of priorities related to OCPA strategic goals and objectives for the following fiscal year.

2. Establish a common consensus to inform the revising and updating of the OCPA Strategic Plan.

OCPA Board Special Meeting of March 21, 2025 Page 2
A consensus on direction to staff was gained by the Board Members and the final action on the discussed items would be placed on the May Board meeting agenda for approval.

6. ADJOURNMENT
There being no further business to come before the Board, Chair Jung adjourned the March 21, 2025, Orange County Power Authority Board Special meeting at 1:09 p.m.

Submitted by:

Pat Jacquez-Nares, Authority Secretary

MINUTES

REGULAR MEETING

BOARD OF DIRECTORS

ORANGE COUNTY POWER AUTHORITY
Monday, March 10, 2025
OCPA Board Regular Meeting of March 10, 2025 Page 1

1. CALL TO ORDER
Chair Sonne called to order the Regular Meeting of the Orange County Authority Board of Directors at 4:31 p.m. on Monday, March 10, 2025.

2. PLEDGE OF ALLEGIANCE
Director Jung led the Pledge of Allegiance.

3. ROLL CALL

4. PUBLIC COMMENTS ON AGENDA ITEMS
None.

5. PUBLIC COMMENTS ON NON-AGENDA ITEMS
Vicki Johnson
Dominic Bendinelli

6. DIRECTOR ANNOUNCEMENTS & REPORTS ON CONFERENCES/EVENTS

ATTENDED
None.

7. CONSENT CALENDAR
ACTION
Director Jung made the motion, seconded by Director Grandis to:

Approve consent calendar items 7.1 – 7.8.

The motion carried unanimously by the following 5-0 vote:

Ayes: Chair Sonne, Vice Chair Mai, Director Jung,
Director Grandis, Director Go
Noes: None

Absent: None
OCPA Board Regular Meeting of March 10, 2025 Page 2

1. MINUTES FOR THE REGULAR BOARD MEETING OF FEBRUARY 10, 2025
Action Taken:

Approved as submitted.

2. COMMUNITY ADVISORY COMMITTEE UPDATE
Action Taken:

Received and filed.

3. LEGISLATIVE AND REGULATORY UPDATE
Action Taken:

Received and filed.

4. SUPPORT SB 540 - INDEPENDENT SYSTEM OPERATOR:

INDEPENDENT REGIONAL ORGANIZATION AND SB 239 – OPEN
MEETINGS: TELECONFERENCING: SUBSIDIARY BODY
Action Taken:

Approved positions on legislation as recommended by Staff: Support SB 540 - Independent System Operator: independent regional organization and SB 239 - Open meetings: teleconferencing: subsidiary body.

5. MARKETING AND COMMUNICATIONS UPDATE FOR JANUARY-FEBRUARY 2025 Action Taken:

Received and filed.

6. TREASURER’S REPORT – FISCAL YEAR ENDED DECEMBER 31, 2024 AND Q4 2024 CHECK REGISTER
Action Taken:

Received and filed.

7. PUBLIC RECORDS ACT REPORT
Action Taken:

Received and filed.

8. 2024 SUPPLIER DIVERSITY REPORT & 2025 ANNUAL PLAN
Action Taken:

Received and filed.

OCPA Board Regular Meeting of March 10, 2025 Page 3

8. REGULAR CALENDAR

1. ADVANCED METERING INFRASTRUCTURE TRI-ANNUAL AUDIT
Management Analyst Viramontes provided a brief summary of this item.

Action Taken:

Received and filed.

2. APPROVE FISCAL YEAR 2024-25 MID-YEAR BUDGET AMENDMENT Chief Financial Officer Law provided a brief summary of this item.

Director Jung made the motion, seconded by Director Grandis to:

Approve Fiscal Year 2024-25 Mid-Year Operating Budget Amendment, as proposed in Attachment 1.

The motion carried unanimously by the following 5-0 vote:

Ayes: Chair Sonne, Vice Chair Mai, Director Jung,
Director Grandis, Director Go
Noes: None

Absent: None

3. A LOCAL GENERATION PROJECT AT THE GREAT PARK IN IRVINE Power Resources Director Ting provided a brief summary of this item.

Action Taken:

Received and filed.

9. STAFF REPORT
CEO Mosca provided his full report in the agenda packet.

10. ADJOURNMENT
There being no further business to come before the Board, Chair Sonne adjourned the March 10, 2025, Orange County Power Authority Board Regular meeting at 6:03 p.m.

Submitted by:

Pat Jacquez, Authority Secretary

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item No. 7.3
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Jacquie Henderson, Director of Communications & External Affairs Andrew Di Giovanna, External Affairs Manager
Linda Kraemer, Community Engagement Manager
Approved By: Joe Mosca, Chief Executive Officer
Subject: COMMUNITY ADVISORY COMMITTEE (CAC) REPORT
Date: April 14, 2025
--------------------------------------------------------------------------------------------------------------------

RECOMMENDED ACTION
Receive and file.

BACKGROUND
On Monday, March 10, 2025, at 6:00 p.m., the Community Advisory Committee (CAC) held its regular monthly meeting. The meeting included a detailed update on the Community Power Plan progress, a discussion on energy affordability and the role of Community Choice Aggregators (CCAs), a presentation on public communication techniques, an overview of OCPA’s public engagement activities for the coming months, and adoption of the 2025 CAC meeting calendar to avoid scheduling conflicts with Board meetings.

The CAC regular meeting on Monday, March 10, 2025, covered the following topics:

Community Power Plan Update
Staff presented an update on the Community Power Plan, highlighting the progress on the community needs assessment and outreach strategy. The assessment aims to guide future programs by identifying local energy priorities. Surveys are available in multiple languages, and over 200 responses have already been received. Committee members were asked to support outreach through their networks.

OCPA is evaluating seven applications from community-based organizations submitted through a recent Request for Qualifications (RFQ).

Energy Affordability and the Role of CCAs
OCPA staff discussed strategies to maintain energy affordability through competitive rate structures and advocacy. The agency’s Basic Choice product remains 3% below SCE’s rates. Staff emphasized legislative work aimed at curbing rate volatility, improving transparency, and reducing resource adequacy costs. Committee members were encouraged to direct residents to assistance programs like CARE and FERA. Public outreach materials are available in multiple languages to ensure broad access to cost-saving resources.

Speaking with the Public – Effective Techniques
Staff and committee members discussed best practices for public engagement. The session emphasized using approachable language, asking open-ended questions, and tailoring responses to community interests such as affordability or clean energy. Members were encouraged to share key facts about OCPA’s mission and services and to refer technical inquiries to staff. Outreach tools like flyers and promotional items were highlighted as ways to spark conversations during events and tabling.

Consideration of 2025 Calendar of Meeting Dates
The committee reviewed and approved the 2025 meeting schedule with the intent of avoiding conflicts with Board of Directors meetings. The goal was to maintain appropriate timing so the CAC can provide input before Board decisions are made. Staff coordinated dates to ensure availability of members and alignment with OCPA’s strategic planning and outreach timelines, and the proposed calendar was adopted without changes.

Updates from Staff
Staff shared recent outreach highlights, beginning with the award of nearly $128,000 in Calpine community grants to seven organizations supporting sustainability, workforce development, and education. The "Picture a Better Tomorrow" student art contest received 117 creative entries across all member cities, with winners to be displayed in OCPA’s lobby and featured in blog posts. Staff also recapped community engagement activities, including event participation across the county, a multicultural community leaders briefing, and sponsorship of the Fullerton Strong Towns event.

Members also attended the "Sustainable Communities, Solutions & Resilience" conference, where OCPA’s Director of Power Resources presented on the topic of community resilience.

FISCAL IMPACT
None

ATTACHMENT
None

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 7.4
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Steven Halligan, Regulatory and Legislative Manager Approved by: Joe Mosca, Chief Executive Officer
Subject: LEGISLATIVE AND REGULATORY UPDATE
Date: April 14, 2025
--------------------------------------------------------------------------------------------------------------------

RECOMMENDED ACTION
Receive and file.

BACKGROUND
Orange County Power Authority (OCPA) staff actively participate in several regulatory proceedings at the California Public Utilities Commission (CPUC), California Independent System Operator (CAISO), and the California Energy Commission (CEC). A summary and status update of active legislation and regulatory proceedings since the previous update is included below. OCPA is currently tracking 123 bills in the state legislature, 13 of which have been flagged as high priority. A bill tracker is included in Attachment 5.

The California legislature began spring recess on April 10 and will reconvene on April 21. Fiscal bills have until May 2 to pass out of their committees, and policy bills have until May 9 to pass out of their committees.

ANALYSIS AND DISCUSSION
Legislative Updates
Joint Federal Letter
On April 1, 2025, twelve Community Choice Aggregators (CCAs) including OCPA signed a joint letter to Congressional Leaders (Attachment 1). The letter highlighted several federal issues that could have significant impacts on CCA’s and the energy market in California. The first request was for Congress to maintain the tax-exempt status for municipal bonds. Many CCA’s currently utilize municipal bonds to execute prepay agreements. OCPA is exploring entering into these types of agreements in the future. Secondly, the letter requests Congress to maintain federal energy tax incentives. These incentives help reduce the cost of new generation projects. The letter also asks Congress to explore ways to streamline and improve the Federal government’s transmission planning and permitting process. The letter also warns that tariffs on energy manufacturing components will increase costs of developing new generation. Lastly, the letter requests Congress uphold existing lease contracts and commitments to federal grants and loan awardees.

Joint Assembly Letter to CPUC
On March 25, 2025, Assemblymember Petrie-Norris and several others from Orange County (Assemblymember Ta, Assemblymember Davies, Assemblymember Quirk-Silva, and Assemblymember Chen) signed onto a joint letter to the CPUC (Attachment 2) urging the CPUC to reject Southern California Edison, SoCalGas, and SDG&E's requests to increase their return on equity (ROE) by approximately 1%. They are requesting that the CPUC conduct its own independent analysis of ROE and pursue alternative financing options for Investor-Owned Utility capital needs.

Legislative Letters of Support
On April 2, 2025 OCPA sent two letters of support to State Senators after the Board voted to support both measures at their March 10, 2025, Board meeting. The first letter (Attachment 3) was in Support of SB 540 (Becker & Stern). SB 540 facilitates the establishment of a regional organization, enabling CAISO to operate and participate in an independently governed entity overseeing a day-ahead electricity market across the Western United States. The second letter (Attachment 4) was in support of SB 239 (Arreguin). SB 239 seeks to modernize the Brown Act teleconferencing rules for public subsidiary bodies that serve in an advisory capacity to legislative bodies.

Power Charge Indifference Adjustment – R.25-02-005
Background: This rulemaking was initiated to consider changes to the Power Charge Indifference Adjustment (PCIA), as well as changes to rules and processes applicable to the Energy Resource Recovery Account (ERRA) annual forecast and compliance proceedings. The proposed scope of the proceeding has two tracks: (1) Track 1, considering on an expedited basis updates to the Resource Adequacy (RA) Market Price Benchmark (MPB) on an expedited basis, with a proposed decision expected in May 2025; and (2) Track 2, considering other issues including (a) additional review or revisions to MPBs, (b) ERRA guidance for RA program changes, include the Slice-of-Day framework, (c) Bundled Procurement Plan guidance changes, (d) improved PCIA and ERRA mechanisms to reduce rate volatility, and (e) guidance for PCIA resource vintaging. OCPA is a party in this case.

Update: CalCCA filed joint CCA comments on behalf of OCPA and other CCA’s on the OIR on March 18, 2025, recommending that:
• The Commission should approach the OIR in the context of its obligation to both bundled and unbundled customers to administer the PCIA framework fairly and accurately; • The Commission should consider the broader context surrounding PCIA policy and current market conditions;
• For the Track One Staff Proposals, the Commission should:
o Model the impacts of all scenarios on the RA MPB (including the combination of Proposals Two and Five) and require the IOUs to demonstrate the estimated system average PCIA rate impacts of different proposals;
o Reject Proposal One. Upending the RA MPB framework by including in the costs of all transactions deliverable in a year, rather than near-term transactions executed for that year, produces an outcome-driven solution that does not reflect current market value as required by the “mark to market” portfolio valuation methodology adopted in D.18-10-019. It thus leaves the overall methodology with a mix of apples and oranges: current prices for energy and RPS versus a blend of current and historical prices for RA.
o Adopt Proposals Two through Five. Each of the Proposals will increase the accuracy, but not upend the framework, of the RA MPB:
 Proposal Two utilizing a single RA MPB incorporating System, Local, and Flex values should be adopted to maximize representative transactions;  Proposal Three excluding affiliate transactions from the MPB calculation should be adopted given the risk of market manipulation;  Proposal Four excluding swap and sleeve transactions should be adopted to the extent the Commission can objectively and transparently identify such transactions; and
 Proposal Five utilizing monthly values for the overall RA MPB should be adopted to best reflect seasonality of RA prices.
• Order legal briefing on the complex issue of retroactively applying any of the Track One modifications to true-up the 2025 Forecast RA MPB;
• While the Track Two scope should only be finalized after the completion of Track One, CalCCA preliminary proposes the following scoping items for Track Two:
o Consideration of structural changes to the PCIA including:
 Sunsetting the PCIA to allow IOUs unencumbered access to the PCIA portfolios in an environment of growing load and the ability to take advantage of the hedge value of the long-term resources in the PCIA portfolio;
 Allocating PCIA resources proportionally to unbundled and bundled customers to minimize ongoing debates on valuation methodology, to more accurately account for full value, and to reduce customer rate volatility; and  Revisiting the PCIA GHG-free methodology to ensure GHG-free resources are accurately valued in the PCIA portfolio;
o Adopting scoping issues proposed in the OIR, including:
 Consideration of ERRA-specific implementation guidance for the RA Slice of Day Framework;
 Consideration of a framework for re-vintaging utility-owned PCIA eligible resources and contract vintaging; and
 Consideration of Bundled Procurement Plan processes; and o Consideration of the treatment of pre-2019 banked RECs; and o Examination of the IOUs’ Common Cost Allocation methodologies.

Integrated Resource Planning – R.20-05-003
Background: The Integrated Resource Planning (IRP) proceeding considers the CPUC’s electric procurement policies and programs to ensure safe, reliable, and cost-effective electricity supply.

The proceeding evaluates system, local, and flexible reliability needs ten years out, authorizes procurement, and reviews load-serving entities’ (LSEs) procurement plans.

Update: On March 21, 2025, SCE filed a Petition for Modification (PfM) of D.23-02-040 and D.24-02-047, requesting to eliminate Mid-Term Reliability (MTR) bridge procurement requirements for generic and Long Lead Time (LLT) MTR procurement in non-summer months if the Load Serving Entity (LSE) using the bridge capacity has met its Resource Adequacy (RA) requirements in the non-summer months. Responses to the PfM are due April 21, 2025.

Resource Adequacy – R.21-10-002 and R.23-10-011
Overview: The Order Instituting Rulemaking (OIR) for R.21-10-002 set forth the following objectives: to continue the CPUC’s oversight of the Resource Adequacy (RA) program, to consider broader structural reforms to the program, and to establish RA procurement obligations for LSEs beginning with the 2023 RA year. This proceeding is split into two tracks. The implementation track has considered near term reforms, including the adoption of the local and flexible capacity requirements, reforms to the CPE structure, modifications to the planning reserve margin (PRM), and revisions to RA counting. The reform track considers broader structural changes to effectuate a 24-hour slice of day (SOD) framework.

The OIR for R.23-10-011 continues the CPUC’s oversight of the RA program, establishes forward RA procurement obligations applicable to LSEs beginning with the 2025 compliance year, and considers structural reforms to the program. This proceeding is the successor to proceeding R.21- 10-002 and includes the following issues in scope:
(1) adoption of local and flexible RA requirements;
(2) loss of load expectation (LOLE) study and PRM;
(3) 24-hour SOD framework;
(4) unforced capacity (UCAP);
(5) QC counting conventions;
(6) RA compliance and penalties; and
(7) other refinements to the RA program.

Update: CalCCA submitted Reply Comments on Track 3 Proposals on March 17, 2025. CalCCA recommends that the CPUC:
• Reject MRP’s, PG&E’s, and SDG&E’s unfounded recommendations to defer the adoption of hourly load obligation trading;
• Implement a system RA waiver, because although party comments diverge on the exact level at which to set the PRM and which Energy Division proposed to adopt, it is clear that RA price mitigation is necessary and that a system RA waiver best meets affordability and reliability objectives;
• Commit to collaborating with CAISO to address open issues associated with allowing EO co-located resources to provide RA value;
• Adopt PG&E’s recommendation to publish test UCAP values in 2027 to allow LSEs to assess their existing portfolios;
• Reject SCE’s proposal to reverse the local RA CPE timeline change, as it is premature and unsupported by new facts or evidence, as explained by Shell and Microsoft; • If the CPUC adopts SCE’s proposal to clarify the local RA CPE procurement obligations resulting from the data request, as supported by parties, it must retain the ability for LSEs to sell to the CPE;
• Consider how best to account for LDES and PSH charging sufficiency needs in a future RA proceeding; and Adopt Leap’s change to the AAH and consider broader reforms to enable greater DR participation in a future proceeding.

A Proposed Decision is expected in May 2025.
2025 Integrated Energy Policy Report Update (25-IEPR-01) Overview: On March 20, 2025, the CEC issued a scoping ruling for the 2025 IEPR. There are three broad topics included in the scope:

1. Advancing clean energy deployment: The proposed focus of the IEPR is advancing clean energy deployment including potential for hydrogen and firm zero-carbon resources. In addition, the 2025 IEPR will identify barriers and solutions to accelerate connection with the grid.

2. Electricity and gas forecast: The 2025 IEPR will include a full update to the 15-year electricity and gas forecast, using the latest demographic and economic data. The new forecast will include scenarios that estimate the impacts of the state’s decarbonization strategies on electricity and gas demand including pricing. There will be a focus on developing a weather-dependent stochastic hourly electricity load dataset consistent with demand forecast assumptions to inform system planning for extreme weather events.

3. Load-shift goal update: The 2025 IEPR will provide updates on California’s load-shift resource potential and make policy recommendations to reduce net-peak electricity. This analysis will also discuss potential strategies and market reforms to reach the seven GW goal by 2030, as adopted by the CEC in 2023 in consultation with the CPUC and the California ISO.

Events, Workshops, and Meetings
During the past month staff attended several events, workshops, and meetings. These include:
• CalCCA Regulatory Policy meetings – including several tiger team meetings covering PCIA and RA proceedings
• Weekly CalCCA Legislative Policy meetings - including several Tiger teams such as Infrastructure, Building Decarb, ZEV, Autonomy, and Affordability • CalCCA Federal Policy meetings
• California Assembly Utilities and Energy and Senate Energy Utilites and Communications Committee meetings and hearings
• CalCCA Regulatory Directors meetings
• CalCCA Compliance meetings
• CPUC Voting Meeting
• CEC Business Meeting
• Little Hoover Hearing on Electricity Costs Part 2
• Pathways Stakeholder Meeting
• OCPA’s Staffers Luncheon
• Informational Hearing on Greenhouse Gas Reduction Fund

FISCAL IMPACT
None

ATTACHMENTS
Attachment 1 – Joint CCA Federal Priorities Letter
Attachment 2 – Assembly Letter to CPUC
Attachment 3 – SB 540 Support Letter
Attachment 4 – SB 239 Support Letter
Attachment 5 – OCPA 2025 California Bill Tracker
April 1, 2025
Dear Congressional Leaders,
We, the undersigned California Community Choice Aggregators (CCAs), write to thank you for your ongoing support for local customer choice in energy. Formed and led by local governments in more than 200 towns, cities, and counties throughout the state, California’s 25 CCAs collectively serve over 14 million residents and businesses with electric service options that support local energy priorities. Our organizations support lowering energy costs, creating good jobs, and increasing America's economic competitiveness. California CCAs have invested billions of dollars in over 18 gigawatts of new-build generation and energy storage projects, supporting over 36,000 energy construction jobs and helping California and the West reliably meet the rising demand for electricity while providing savings for our customers.

As the 119th Congress considers energy and tax legislation, we want to share our priorities and urge you to help ensure that Californians can continue to receive affordable and reliable electricity for years to come.

Maintain the tax-exempt status for municipal bonds
Securing long-term power purchasing agreements (PPAs) with our energy developer partners is critical to the CCA mission of delivering reliable energy to customers at competitive rates. As local government agencies, many CCAs leverage the municipal bond market and execute “prepay” transactions that provide meaningful energy procurement cost savings.

Through prepay transactions, CCAs are financing the development of new large-scale energy projects that create good-paying jobs and help meet rising energy demand across the most populous state in the country – all while reducing costs for our customers. Since 2021, the California Community Choice Financing Authority (CCCFA) has issued $16 billion in prepayment tax-exempt bonds on behalf of CCAs, saving participating community choice customers roughly $100 million annually in electricity costs. The savings enabled by this crucial financial mechanism would not be possible without the U.S. tax code excluding interest earned on the bonds from gross income for federal income tax purposes.

As Congress considers new tax legislation in 2025, we urge members to preserve the tax-exempt status of municipal bonds so that CCAs and local governments throughout the country have the economic certainty they need to continue making meaningful investments in the communities they serve.

Preserve federal energy tax incentives
To meet the nation’s growing demand for electricity and create good-paying jobs, power producers rely on certainty and stability in the U.S. tax code to finance new generation projects.

CCAs, as purchasers of wholesale electricity, depend on the continued steady development of new energy projects to serve our customers. Likewise, customers throughout the state are benefiting from new and extended tax incentives to electrify their homes and make them more energy efficient, reducing their energy bills and their emissions footprint.

Since the Inflation Reduction Act (IRA) became law in 2022, its suite of tax incentives has spurred businesses and consumers to invest nearly $500 billion in energy projects and manufacturing located throughout the country, strengthening the U.S. supply chain and revitalizing the economy.1 These investments have also helped improve the reliability of the U.S. energy grid, increase U.S. energy production, and put downward pressure on energy prices.

Even more of this affordable energy supply is needed to meet customer demand in the future.

According to a recent study conducted by NERA Economic Consulting, a full repeal of the IRA’s investment and production tax credits would increase delivered electricity prices nationwide by an average of 9.2% by 2029.2 In California, rates could increase for residential customers by 9.6% and for commercial and industrial customers by 12.8%. Another study by Aurora Energy Research found that by 2040, customer energy bills could increase by an average of $142 a year and California could lose up to 6,500 clean energy jobs.3 It is clear that any changes to IRA tax credits will have harmful impacts; the only question is the exact timing and magnitude of those impacts.

We therefore urge members of Congress to ensure America continues to invest in the entire energy sector and remains competitive on the global stage by maintaining the energy tax incentives already on the books and strengthened by the IRA. That includes the Energy Efficient Home Improvement Credit (25C), Residential Clean Energy Credit (25D), Previously Owned Clean Vehicle Credit (25E), New Clean Vehicle Credit (30D), Commercial Clean Vehicle Credit (45W), Advanced Manufacturing Production Credit (45X), Clean Electricity Production Credit (45Y), Clean Electricity Investment Credit (48E), and the elective pay and transferability mechanisms associated with these credits.

Strengthen the U.S. energy grid through streamlined transmission development To truly address the nationwide energy emergency and meet rising demand for electrical power, we urge our Congressional leaders to pursue an “all of the above” energy approach that includes low-cost wind, solar, battery, and geothermal sources, and continue to improve and refine the Federal government’s transmission planning and permitting process.

According to the Department of Energy, the U.S. will need to expand transmission systems by 60% by 2030 and may need to triple those systems by 2050 to meet the country’s growing clean electricity demands.4 The California Independent System Operator (CAISO), in its latest 20- Year Transmission Outlook, estimates that the state will need anywhere from $45.8 billion to $63.2 billion in new high voltage transmission lines by 2045.5 All energy customers, regardless of the energy sources they use, stand to benefit from more reliable legal and regulatory processes to support the timely and cost-effective development of transmission needed to power our communities and increase energy resiliency.

Tariffs on critical energy manufacturing components may create new affordability headwinds
As U.S. domestic manufacturing ramps up to meet the country’s growing energy needs, having reliable access to critical manufacturing components (e.g., batteries, turbines, photovoltaic panels) is essential for maintaining a stable and affordable energy supply. Although ongoing Federal investments are being made to rapidly reduce U.S. dependence on foreign supply chains, the energy industry is still reliant on many key components produced in other countries to meet rising demand.

As the Administration contemplates the implementation of new and increased tariffs on imports, we urge federal leaders to carefully consider the impacts that these policies may have on the U.S. energy sector, the hundreds of thousands of Americans it employs in good-paying construction and manufacturing jobs, and the price customers pay for electricity. It is likely that new tariffs on steel, aluminum, and Chinese goods may impact the pricing of energy projects key to domestic energy generation and storage.

Uphold existing lease contracts and commitments to federal grant and loan awardees Many CCAs are partnering with the federal government to secure resources to complete customer-facing energy projects, including solar and storage installations for low-income households, building decarbonization retrofits, and electric vehicle charging. CCAs are also working with developers who have finalized lease agreements with the federal government to build much-needed energy generation and transmission infrastructure. These local electrification programs and new development activities increase resilience and reliability, create jobs, reduce customer energy bills, and provide added tangible benefits for the communities that CCAs serve, helping to alleviate the strain on our nation’s energy grid and ensuring all residents have access to affordable energy options.

The administration’s ongoing pause in federal grant and loan funding and uncertainty surrounding federal lease agreements are putting many of these projects – and others across the country – in jeopardy and adding costly and unnecessary delays, to the ultimate detriment of American taxpayers and businesses. We respectfully request our Congressional leaders to do everything in their power to ensure the federal government honors all its existing and future commitments so that awardees and counterparties have the certainty needed to deliver meaningful projects that enrich the lives of Americans everywhere.

Thank you again for your consideration and we look forward to continuing working together to strengthen community choice and expand energy savings for all our customers.

Sincerely,
Howard Chang
Chief Executive Officer
Ava Community Energy
Robert Shaw
Chief Executive Officer
Central Coast Community Energy
Greg Wade
Chief Executive Officer
Clean Energy Alliance
Ted Bardacke
Chief Executive Officer
Clean Power Alliance
Jeffrey Bernstein
Councilmember, City of Palm Springs
Chair of the Board
Desert Community Energy
Dawn Weisz
Chief Executive Officer
MCE
Joe Mosca
Chief Executive Officer
Orange County Power Authority
Shawn Marshall
Chief Executive Officer
Peninsula Clean Energy
1 Bermel, Lily, et al. Clean Investment Monitor: Tallying the Two-Year Impact of the Inflation Reduction Act. Rhodium Group, MIT Center for Energy and Environmental Policy Research, 7 Aug. 2024, https://rhg.com/wp-content/uploads/2024/08/Clean-Investment-Monitor_Tallying-the-Two-Year-Impact-of-the-Inflation-Reduction-Act-1.pdf. 2 Tuladhar, Sugandha, PhD, et al. Electricity Price Impacts of Technology-Neutral Tax Incentives With Incremental Electricity Demand from Data Centers. NERA Economic Consulting, 10 Feb. 2025, https://cebuyers.org/wp-content/uploads/2025/02/CEBA_Electricity-Price-Impacts-of-Technology-Neutral-Tax-Incentives-With-Incremental-Electricity-Demand-From-Data-Centers_February-2025.pdf. 3 Bonahoom, Lizzie, et al. Impact of Reform to Clean Energy Tax Credits on Investment, Jobs and Consumer Bills. Aurora Energy Research LLC, 6 Jan. 2025, https://auroraer.com/insight/impact-of-reform-to-clean-energy-tax-credits-on-investment-jobs-and-consumer-bills/. 4 U.S. Department of Energy. Queued Up… But in Need of Transmission. 2024, https://www.energy.gov/policy/queued-need-transmission. 5 California Independent System Operator. 2024 20-Year Transmission Outlook. 31 July 2024, https://www.caiso.com/documents/2024-20- year-transmission-outlook-jul-31-2024.pdf.

Elizabeth Burks
Executive Director
Redwood Coast Energy Authority
Karin Burns
Chief Executive Officer
San Diego Community Power
Zach Struyk
Acting Director
San Jose Clean Energy
Monica V. Padilla
Chief Executive Officer
Silicon Valley Clean Energy
CC: California Congressional Delegation
1 of 5
March 25, 2025
The Honorable Alice Reynolds
President, California Public Utilities Commission
505 Van Ness Avenue
San Francisco, CA 94102
Subject: Urge Rejection of Utility Cost of Capital Applications Dear President Reynolds,
We urge you to reject the March 20, 2025, applications of Pacific Gas and Electric (PG&E), Southern California Edison (SCE), Southern California Gas (SoCalGas), and San Diego Gas and Electric (SDG&E) as they relate to requested increases to their cost of capital, and specifically by approximately 1% in 2026 to the return on equity (ROE) portion.1 As academic literature has shown, an increase by one percentage point of the ROE leads to a 3-4% increase in capital assets.2 These capital assets have a larger cumulative impact on rates, as capital costs are recovered over a longer time horizon during which the higher ROE may be collected. The impact of approving such utility rate requests will be an increase to customer bills throughout the state. Nationwide, these excess costs have resulted in approximately $7 billion per year to the U.S. consumer.3
Californians are facing enormous strain at the kitchen table, and specifically with their electric and natural gas bills. The CPUC has long recognized this in its annual SB 695 Report, noting electricity rates have increased faster than inflation for customers of California’s electric investor-owned utilities (IOUs).4 Nearly 1 in 5 electric IOU customers are behind on their bills, with the average amount owed approximately $821.5 This trend is unsustainable. Yet little action has occurred to date. Continuing a business-as-usual approach, and approving these IOU requests to increase their profit structure, will inflict harm on an already pained system.
1 PG&E ROE = 10.28% in Jan 1, 2025 (D.24-10-008) requesting 11.3%; SCE ROE = 10.33% requesting 11.75%; SoCalGas ROE = 10.08% requesting 11%; and SDG&E ROE = 10.23% requesting 11.25% 2 Werner, K. D. and Jarvis, S.; “Rate of Return Regulation Revisited;” Energy Institute WP 329R; Energy Institute at Haas, University California at Berkeley; Revised September 2024. 3 Ibid.
4 CPUC; 2024 Senate Bill 695 Report; July 2024; https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/office-of-governmental-affairs-division/reports/2024/2024-sb-695-report.pdf 5 California Public Advocates Office Q3 2024 Report; December 2024; https://www.publicadvocates.cpuc.ca.gov/- /media/cal-advocates-website/files/press-room/reports-and-analyses/241205-public-advocates-office-q3-2024-rates-report.pdf 2 of 5
The utility sector is a capital-intensive industry, and utilities need investors to pay for the significant new investment needed to modernize the grid and decarbonize our economy. It is in all our interests that California’s utilities are healthy – any increase to their cost of borrowing or decrease to their credit rating results in higher costs to ratepayers, who shoulder the cost of utility financing. 6 However the
need for utilities to bring forward significant new capital investments must be balanced with our clear mandate to keep costs low. The IOUs’ proposals to increase their ROE does not strike an appropriate balance, and the CPUC should push back firmly.

In striking the right balance, we instead propose a pivot; in other words, a change in strategy without a change in vision. We have observed the CPUC traditionally employs a mix of analytical models and subjective judgement to set the ROE, seeking an ROE value that “is necessary to attract capital.” However such subjectivity has been found to introduce bias.7 And the traditional approach of benchmarking against other U.S. utilities, while sometimes advantageous, can cause rates to update very slowly when market conditions change.8 We urge a change in strategy:
1) The CPUC should conduct its own independent analysis of ROE. The CPUC should then center that analysis – which should optimize for customer affordability – as the starting point of the discussion, not the IOUs’ applications. In rate cases, the utilities are most knowledgeable about the future needs of their systems, workforce, and equipment. However, is the IOU insight into wider market forces or general investor sentiment (all necessary considerations for ROE) unique? The CPUC should lead the discussion of IOU cost of capital, not be a passive recipient of the IOUs’ wishes.
2) The CPUC should pursue alternative financing options in its evaluation of future capital needs. The IOUs cite increased wildfire risk, and the potential depletion of the state’s Wildfire Fund, as justification for their request for increased ROE.9 As PG&E notes, “investors have choices where to put their money, and customers will be adversely impacted if PG&E has to curtail its infrastructure…because we cannot obtain the funding…”10 It is in this atmosphere that the CPUC should more actively partner with the Legislature to explore alternative financing options to attract investment, outside of increases to IOU ROE. These can include securitized financing orders, partnerships with nonprofits, or even state revenue bonds to offset utility cost of borrowing. Both the Legislature and the CPUC should explore these additional tools, and bear them in mind when considering IOU ROE, rather than solely viewing IOU cost of capital as the only tool available to attract investment.

Californians are suffering at the increasing cost of their goods and services, including electric and natural gas bills. It is imperative we bear this reality in mind when evaluating any policy that may impact rates.

Achieving a reasonable ROE is a critical regulatory task, one that must balance attracting new investment while keeping consumer costs down. We propose the CPUC adopt the two strategies above in order to strike this balance.
6 Pg. 8, John Quackenbush, USAID, Cost of Capital and Capital Markets: A Primer for Utility Regulators; December 2019.
7 Rode, D. C., and Paul Fischbeck; “Regulated equity returns: A puzzle;” Energy Policy 133 (October): 110891; 2019. https://doi.org/10.1016/j.enpol.2019.110891.
8 Pg. 10 Werner, K. D. and Jarvis, S.; “Rate of Return Regulation Revisited;” Energy Institute WP 329R; Energy Institute at Haas, University California at Berkeley; Revised September 2024. 9 See applications of PG&E, SCE, and SDG&E
10 Pg. 1-4; Pacific Gas and Electric Company Cost of Capital 2026 Prepared Testimony; March 20, 2025. 3 of 5
Our energy sector is in a period of transformational change; our regulatory structures must transform alongside it. The Legislature stands ready to partner with you in this effort. And we urge you, as a first step, to reject the current IOU applications.

We look forward to receiving a response to our request.

Sincerely,
_______________________________ _______________________________ Cottie Petrie-Norris, 73rd Assembly District Rebecca Bauer-Kahan, 16th Assembly District Chair, Assembly Committee on Utilities & Energy
_______________________________ _______________________________ Joe Patterson, 5th Assembly District Buffy Wicks, 14th Assembly District Vice-Chair, Assembly Committee on Utilities & Energy
_______________________________ _______________________________ Tri Ta, 70th Assembly District John Harabedian, 41st Assembly District _______________________________ _______________________________ Greg Wallis, 47th Assembly District Catherine Stefani, 19th Assembly District _______________________________ _______________________________ Pilar Schiavo, 40th Assembly District Darshana Patel, 76th Assembly District _______________________________ _______________________________ Damon Connolly, 12th Assembly District Chris Rogers, 2nd Assembly District _______________________________ _______________________________ Jacqui Irwin, 42nd Assembly District Marc Berman, 23rd Assembly District 4 of 5
_______________________________ _______________________________ Laurie Davies, 74th Assembly District Sharon Quirk-Silva, 67th Assembly District _______________________________ _______________________________ Dawn Addis, 30th Assembly District Tina McKinnor, 61st Assembly District _______________________________ _______________________________ Nick Shultz, 44th Assembly District Gail Pellerin, 28th Assembly District _______________________________ _______________________________ Phillip Chen, 59th Assembly District Chris Ward, 78th Assembly District _______________________________ _______________________________ Robert Garcia, 50th Assembly District Celeste Rodriguez, 43rd Assembly District _______________________________ _______________________________ Mark Gonzalez, 54th Assembly District Matt Haney, 17th Assembly District _______________________________ _______________________________ Liz Ortega, 20th Assembly District Diane Papan, 21st Assembly District _______________________________ _______________________________ Alex Lee, 24th Assembly District Steve Bennett, 38th Assembly District _______________________________ _______________________________ Ash Kalra, 25th Assembly District Tasha Boerner, 77th Assembly District 5 of 5
_______________________________ _______________________________ Lisa Calderon, 56th Assembly District Gregg Hart, 37th Assembly District _______________________________ _______________________________ Esmeralda Soria, 27th Assembly District Cecilia Aguiar-Curry, 4th Assembly District Assembly Majority Leader
_______________________________ _______________________________ Sade Elhawary, 57th Assembly District Rhodesia Ransom, 13th Assembly District Cc: Commissioner Darcie Houck, California Public Utilities Commission Commissioner John Reynolds, California Public Utilities Commission Commissioner Karen Douglas, California Public Utilities Commission Commissioner Matthew Baker, California Public Utilities Commission April 2, 2025
The Honorable Josh Becker
California State Senate
1021 O Street, Suite 3350
Sacramento, CA 95814
RE: Support for SB 540 (Becker & Stern) – Independent System Operator:
independent regional organization
Dear Senator Becker,
On behalf of the Orange County Power Authority (OCPA), I am writing to express our support for Senate Bill 540, which will deliver ratepayer savings, reduce greenhouse gas emissions, and enhance grid stability. OCPA is committed to ensuring a reliable, affordable, and sustainable energy future for our communities, and we believe SB 540 is a critical step in advancing regional cooperation to achieve California’s clean energy and reliability goals. OCPA is pleased to support SB 540 (Becker & Stern).

As a Community Choice Aggregation (CCA) provider serving Orange County, OCPA recognizes the critical role of regional coordination in energy markets. SB 540 facilitates the establishment of a regional organization, enabling the California Independent System Operator (CAISO) to operate and participate in an independently governed entity overseeing a day-ahead electricity market across the Western United States.

Importantly, SB 540 (Becker & Stern) will:
• Preserve California’s and OCPA’s authority to make resource decisions that align with state and local goals while best serving customer needs. • Establish a transparent governance process that ensures equitable representation for all market participants.
• Provide a clear withdrawal mechanism to address potential federal actions or market rule changes that could negatively impact California ratepayers or conflict with state policy.
• Uphold California’s and OCPA’s commitment to union labor opportunities and retaining energy sector jobs within the state.

We appreciate your leadership in advancing policies that promote regional energy coordination and urge the Legislature to fully support SB 540. Please do not hesitate to contact us if we can provide additional information or assistance in advocating for this important legislation.

Sincerely,
Steven Halligan
Steven Halligan
Regulatory and Legislative Manager
Orange County Power Authority
April 2, 2025
The Honorable Jesse Arreguin
California State Senate
1021 O Street, Suite 6710
Sacramento, CA 95814
RE: SB 239 (Arreguin) Open meetings: teleconferencing: subsidiary body - SUPPORT
Dear Senator Arreguin,
On behalf of the Orange County Power Authority (OCPA), I am pleased to express our strong support for SB 239 (Arreguin), which seeks to modernize the Brown Act teleconferencing rules for public subsidiary bodies that serve in an advisory capacity to legislative bodies.

OCPA is governed by a Board of Directors and advised by a Community Advisory Committee (CAC), a subsidiary body that fosters public engagement and community participation. As Orange County’s locally driven clean energy provider, we deeply value opportunities to engage with the communities we serve.

Since our formation in 2021 and launch of service in 2022, we have seen firsthand the benefits of virtual and hybrid meetings. During the COVID-19 emergency, the temporary Brown Act teleconferencing provisions enabled broader public participation and improved accessibility for our Board meetings. Equally important, these provisions expanded the pool of individuals able to serve on our CAC, ensuring a more diverse and representative advisory body. Unfortunately, the rigid and outdated travel requirements of the Brown Act have resulted in the ineligibility of potential valuable CAC members as they are unable to attend in person.

The flexibility provided by teleconferencing is essential to maintaining an inclusive, engaged, and representative CAC. SB 239 would help preserve these benefits, ensuring that advisory bodies can continue to operate effectively while maximizing public participation.

For these reasons, OCPA strongly supports SB 239 (Arreguin). We appreciate Senator Arreguin’s leadership on this issue and urge the Legislature’s approval of this important measure. If you have any questions or would like to discuss OCPA’s perspective further, please feel free to contact me at [email protected].

Sincerely,
Steven Halligan
Steven Halligan
Regulatory and Legislative Manager
Orange County Power Authority
Orange County Power Authority
2025 California Bill Tracker (Updated 4/3/2025)
High Priority
Bill # Author Title Category Summary Status Position
AB 303 Addis Battery energy storage
facilities
Battery Storage This bill would prohibit the authorization of a development project that includes a battery energy storage system capable of storing 200 megawatthours or more of energy if the development project is located within 3,200 feet of a sensitive receptor or is located on an environmentally sensitive site, as specified.

In committee: Hearing
postponed by
committee.

AB 306 Schultz and Rivas Building regulations: state
building standards
Building Standards This bill would, from June 1, 2025, until June 1, 2031, inclusive, prohibit a city or county from making changes to the above-described building standards unless a certain condition is met, including that the commission deems those changes or modifications necessary as emergency standards to protect health and safety. By requiring a city or county to take certain actions relating to building standards, this bill would impose a state-mandated local program.

In Senate. Read first
time. To Com. on RLS.
for assignment.

AB 526 Papan Energy: new in-state
geothermal energy
generation
Geothermal The bill would require the Energy Commission, on or before June 1, 2026, to evaluate and quantify the maximum feasible capacity of new in-state geothermal energy to achieve reliability, ratepayer, employment, and decarbonization benefits, and to establish megawatt in-state next-generation geothermal planning goals for 2035 and 2045, as specified.

Re-referred to Com. On
U. & E., amended 3/24
AB 527 Papan California Environmental
Quality Act: geothermal
exploratory projects
Geothermal This bill would provide that a geothermal exploratory project, as defined, that the lead agency determines meets specified criteria is conclusively presumed to have satisfied the requirements of CEQA for the geothermal exploratory project, including to support the issuance of any permit, funding, or other approval by a state or local agency, as provided. The bill would require, for a project undertaken by a private entity that satisfies the requirements of CEQA pursuant to this provision, the project applicant to certify to the lead agency that either the entirety of the project is a public work or that certain prevailing wage requirements are satisfied.

Referred to Com. On
Nat. Res.

AB 531 Rogers Geothermal powerplants
and geothermal field
development projects:
certification and
environmental review
Geothermal This bill would expand the types of facilities eligible to be certified as environmental leadership development projects by the Energy Commission to include geothermal powerplants and geothermal field development projects, as defined.

Referred to Com. On U.
& E. and Nat. Res.

Orange County Power Authority
2025 California Bill Tracker (Updated 4/3/2025)
High Priority
AB 941 Zbur California Environmental
Quality Act: electrical
infrastructure projects
CEQA This bill would require the commission to determine whether to certify the environmental impact report for an electrical infrastructure project that is a priority project, as defined, no later than 270 days after the commission determines that an application for an electrical infrastructure project is complete, except as specified.

Passed Asm. U. & E. on
4/2. 17-0-1
SB 57 Padilla Data centers: special
tariff or program
Data Centers This bill, the Ratepayer and Technological Innovation Protection Act, would require the commission, on or before July 1, 2026, to establish a special electrical corporation tariff or program, or modify an existing tariff or program, for transmission and distribution service to data centers, as defined, that, among other things, avoids nonparticipating customers, such as existing residential, small business, and agricultural ratepayers, bearing cost shifts, such as the costs of interconnecting facilities or loads that fall short of initial projections and ensures electrical grid investments to serve a data center are fully recovered from the data center in the event that the data center ceases operations or uses less electricity than initially projected. The bill would require the commission, on or before January 1, 2030, to require all retail sellers subject to its jurisdiction to serve any data center subject to the tariff or program with electricity from 100% zero-carbon resources in a manner that does not result in resource shuffling and does not increase carbon emissions elsewhere in the western grid.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E., U & C.

SB 239 Arreguin Open meetings:
teleconferencing:
subsidiary body
Teleconferencing This bill would authorize a subsidiary body, as defined, to use alternative teleconferencing provisions and would impose requirements for notice, agenda, and public participation, as prescribed. The bill would require the subsidiary body to post the agenda at the primary physical meeting location. The bill would require the members of the subsidiary body to visibly appear on camera during the open portion of a meeting that is publicly accessible via the internet or other online platform, as specified. The bill would also require the subsidiary body to list a member of the subsidiary body who participates in a teleconference meeting from a remote location in the minutes of the meeting.

Senate L. Gov. and Jud.
- April 2
Support
Orange County Power Authority
2025 California Bill Tracker (Updated 4/3/2025)
High Priority
SB 283 Laird Energy Storage Systems Battery Storage This bill would require an application submitted to the Energy Commission in accordance with the above-described provisions relating to certification of facilities by the Energy Commission, and an application submitted to a local jurisdiction for an energy storage management system, to include the applicant’s certification that the facility has been designed in accordance with the NFPA 855, Standard for the Installation of Stationary Energy Storage Systems, and, at least 30 days before submitting an application, the applicant met and conferred with the local fire department responsible for fire suppression in the area where the facility or system is proposed, as provided.

The bill would also prohibit the approval of those applications unless the local jurisdiction requires as a condition of approval that the system be constructed, installed, commissioned, operated, maintained, and decommissioned in accordance with NFPA 855, that after installation is complete, but before commencing operations, the system be inspected by the local fire department responsible for fire suppression or by a representative or designee of the State Fire Marshal, and that the applicant bear the cost of the inspection. By imposing additional duties on local officers, the bill would impose a state-mandated local program.

Re-referred to Coms.
on E., U & C. and L.

GOV.

SB 302 Padilla Personal Income Tax Law
and Corporation Tax Law:
exclusions:
environmental credits
Tax Credits This bill, in conformity with federal law, for taxable years beginning on or after January 1, 2023, would exclude from gross income a refund payment made for the specified federal environmental credits described above and any payment received by a transferor as consideration for a transfer, as provided. The bill would also prohibit a transferee from deducting the amount paid as consideration for the transfer, in conformity with federal law.

Set for hearing April 7.

Orange County Power Authority
2025 California Bill Tracker (Updated 4/3/2025)
High Priority
SB 330 Padilla Electrical transmission
infrastructure: finacning
Transmission This bill would authorize the Governor to establish one or more pilot projects to develop, finance, or operate electrical transmission infrastructure that meet the specified criteria, including, among other things, that the transmission line is identified by the Independent System Operator in its transmission planning process as necessary to support clean energy generation to meet the state’s clean energy goals. The bill would require the Governor to designate existing state agencies, local public agencies, tribal organizations, or joint powers authorities to implement the pilot projects. The bill would authorize the pilot projects to develop, finance, operate, and maintain electrical transmission lines and all works, facilities, improvements, and property, or portions thereof, necessary or convenient for the conveyance of electricity, as specified. The bill would authorize the Governor to issue guidelines regarding application and certification of pilot projects.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E., U & C.

SB 540 Becker and Stern Independent System
Operator: independent
regional organization
Regional Organization This bill would delete the above-described provisions providing for the transformation of the ISO into a regional organization. The bill would authorize the ISO and the electrical corporations that are participating transmission owners whose transmission systems are operated by the ISO, in lieu of the ISO managing related energy markets, as provided, to use energy markets governed by an independent regional organization, provided that specified requirements are satisfied.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E., U & C.

Support
Orange County Power Authority
2025 California Bill Tracker (Updated 4/3/2025)
High Priority
SB 541 Becker Electricity: load shifting:
dynamic pricing
Dynamic Rates This bill would require all retail suppliers, as defined, to provide rate information to the Energy Commission’s Market-Informed Demand Automation Server in order to provide third-party devices with access to real-time rate information for the purpose of efficiently automating load flexibility.

The bill would require the commission, on or before January 1, 2028, to require all load-serving entities to offer optional dynamic pricing tariffs, as specified, and the governing boards of each local publicly owned electric utility to consider offering dynamic pricing tariffs, as specified. The bill would require the commission, as part of a new or existing proceeding, to consider (1) whether larger differentials between peak and off-peak time-of-use periods, including larger differentials for the transmission and distribution portion of rates, would be a cost-effective way to address peak load, and (2) whether distinguishing between nighttime off-peak and daytime off-peak periods would be a cost-effective way to align flexible load with periods of abundant renewable and zero-carbon energy.

Re-referred to Com. on
E., U & C.

Medium Priority
Bill # Author Title Category Summary Status Position
AB 13 Ransom Public Utilities
Commission:
membership: reports.

CPUC Reporting This bill would require that 4 members of the commission represent the geographic locations of the 4 State Board of Equalization districts, existing as of January 1, 2026, and one member be an at-large member with expertise in nongovernmental public advocacy or public interest law and with a nongovernmental background, as specified. The bill would prohibit an elected member of, or an employee of, the Legislature or an employee of the executive branch from serving as a member of the commission within one year after leaving the position as an elected member or employee.

Re-referred to Com. on
APPR.

AB 23 DeMaio The Cost of Living
Reduction Act of 2025.

Affordability This bill would require the Energy Commission to develop a rebate methodology to compensate Californians for the higher cost of gasoline, electricity, and natural gas compared to the national average, and, beginning with the 2026–27 fiscal year, in any year where the average prices for gasoline, electricity, or natural gas have exceeded the national average for those energy sources by more than 10% in the preceding 12 months, would require the Controller to provide rebates to households consistent with the methodology developed by the commission. The bill would establish the Cost of Living Reduction Fund and would require an amount necessary to fund the rebates, as specified, to be transferred from the Greenhouse Gas Reduction Fund to the Cost of Living Reduction Fund, the moneys in which would be continuously appropriated to the Controller for the purpose of making the rebate payments. By requiring the transfer of moneys into a continuously appropriated fund, the bill would make an appropriation.

Re-referred to Com. on
U. & E.

Medium Priority
AB 39 Zbur General plans: Local
Electrification Planning
Act.

Local Programs This bill, the Local Electrification Planning Act, would require a city, county, or city and county, on or after January 1, 2027, but no later than January 1, 2030, to prepare and adopt a specified plan, or integrate a plan in the next adoption or revision of the general plan, that includes locally based goals, objectives, policies, and feasible implementation measures that include, among other things, the identification of opportunities to expand electric vehicle charging, as specified, and includes policies and implementation measures that address the needs of disadvantaged communities, low-income households, and small businesses for equitable and prioritized investments in zero-emission technologies that directly benefit these groups. For these purposes, the bill would authorize a city, county, or city and county to incorporate by reference into the general plan a previously adopted similar plan that meets the above-described requirements, as specified. By increasing the duties of local public officials, the bill would establish a state-mandated local program.

Re-referred to Com. on
L. GOV.

AB 44 Schultz Energy: electrical
demand forecasts.

Demand Forecasts This bill would require the Energy Commission, on or before December 1, 2026, and in consultation with the Public Utilities Commission, Independent System Operator, load-serving entities, and resource aggregators, to adopt a set of upfront technical requirements and load modification protocols, as defined, to provide the option for a load-serving entity to reduce or modify its electrical demand forecast upon aggregated system operation, as specified. The bill would require the commission to evaluate new and existing mechanisms that can support or expand opportunities for load-serving entities to modify their hourly resource adequacy obligations through load management, and would authorize the Energy Commission to include its findings and recommendations in its integrated energy policy report.

Re-referred to Com. on
U. & E.

AB 61 Pacheco Electricity and natural
gas: legislation imposing
mandated program and
requirements: third-party
review.

Programs This bill would request the office to establish, by January 1, 2027, a program to, upon request of the Legislature, analyze legislation that would establish a mandated requirement or program or otherwise affect electrical or gas ratepayers, as specified. The bill would request the office to develop and implement conflict-of-interest provisions that would prohibit a person from participating in an analysis for which the person knows or has reasons to know that the person has a financial interest. The bill would establish the Energy Programs Benefit Fund in the State Treasury and continuously appropriate the moneys in the fund to the office to support the work of the office in providing analyses under the bill. The bill would repeal these provisions on January 1, 2031.

Read second time and
amended.

Medium Priority
AB 99 Ta Electrical corporations:
rates.

Affordability This bill would prohibit an electrical corporation from proposing a rate increase above the rate of inflation as defined, as a systemwide average for any general rate case cycle, except the bill would expressly authorize the commission to approve a rate increase above the rate of inflation if the commission determines that the costs underlying the rate increase are directly related to safety enhancements and modernization or to higher commodity or fuel costs.

Read second time and
amended.

AB 222 Bauer-Kahan Data centers: energy
usage reporting and
modeling.

Data Centers This bill would require the Energy Commission to require operators of data centers to annually report energy consumption and performance data, as specified. The bill would require the Energy Commission to include energy consumption trends for data centers in its integrated energy policy reports. The bill would require the Energy Commission to adopt energy efficiency performance standards, as described, for data centers. The bill would require the Energy Commission to adopt regulations to implement these requirements on or before January 1, 2027.

In committee: Set, first
hearing. Hearing
canceled at the
request of author.

AB 267 Macedo Greenhouse Gas
Reduction Fund: high-speed rail: water
infrastructure and wildfire
prevention
GGRF This bill would suspend the appropriation to the High-Speed Rail Authority for the 2026–27 and 2027–28 fiscal years and would instead require those amounts from moneys collected by the state board to be transferred to the General Fund. The bill would specify that the transferred amounts shall be available, upon appropriation by the Legislature, to augment funding for water infrastructure and wildfire prevention.

Referred to Coms. on
TRANS. and NAT. RES.

AB 273 Sanchez Greenhouse Gas
Reduction Fund: high-speed rail: infrastructure
improvements
GGRF This bill would eliminate the continuous appropriation of 25% of the annual proceeds of the Greenhouse Gas Reduction Fund to the High-Speed Rail Authority on June 30, 2026. The bill, beginning with the 2026–27 fiscal year, would instead require 25% of the annual proceeds of the Greenhouse Gas Reduction Fund to be transferred to the General Fund and for those moneys, upon appropriation, to be used to augment funding provided to local governments to improve infrastructure.

Referred to Coms. on
TRANS. and NAT. RES.

AB 275 Petrie-Norris Office of Emergency
Services: wildfire
response: SoCal Edison-funded helitanker
program.

Wildfires This bill would require the Office of Emergency Services to establish, on or before December 31, 2026, a working group to study the feasibility of making the SoCal Edison-funded Quick Reaction Force firefighting helitanker program permanent in statute. The bill would require the Director of Emergency Services to appoint members to the working group who are knowledgeable about the program. The bill would make related findings and declarations.

Re-referred to Com. on
E.M.

AB 286 Gallagher Electricity: mandatory
rate reduction.

Rates The commission shall reduce the kilowatt-per-hour rate for electricity charged to ratepayers by not less than 30 percent.

Re-referred to Com. on
U. & E.

AB 305 Arambula Energy: nuclear facilities Nuclear Power This bill would exempt small modular reactors, as defined, from those provisions. This bill would require the PUC, on or before January 1, 2028, to adopt a plan to increase the procurement of electricity generated from nuclear facilities and to phase out the procurement of electricity generated from natural gas facilities.

Referred to Coms. on
NAT. RES. and U. & E.

Medium Priority
AB 368 Ward Energy: building
standards: passive house
standards
Building Standards This bill would require the commission to evaluate the passive house energy efficiency standards, and, if appropriate, adopt those standards, or any elements that align with the state’s existing requirements, as an alternative compliance pathway for the building efficiency standards established by the Energy Commission.

Referred to Coms. on
NAT. RES. and U. & E.

AB 388 Rogers Electricity Electrical
Corporations
This bill would revise the definition of “electrical corporation” to exclude a corporation or person employing certain solar or wind generating technology if electricity is transmitted exclusively and directly through private electrical lines to a single facility owned by a different corporation or person that uses the electricity only for new load, not for departing load, and for an electrolytic hydrogen production facility, as defined, or a facility using the electricity to provide industrial process heat, or both.

Re-referred to Com. on
U. & E.

AB 420 Petrie-Norris Public Utilities
Commission:
proceedings
CPUC This bill would authorize an interested person to submit a written ex parte communication during a quiet period if the commission modifies, rather than materially modifies, a proposed decision.

Re-referred to Com. on
U. & E.

AB 434 DeMaio Construction and safety
standards: battery
storage facilities
Battery Storage This bill would prohibit, until January 1, 2028, a public agency from authorizing the construction of a battery energy storage facility, as defined. The bill would require the State Fire Marshal, on or before January 1, 2028, to adopt guidelines and minimum standards for the construction of a battery energy storage facility to prevent fires and protect nearby communities from any fire hazard posed by the facility. The bill would require a public agency, when authorizing the construction of a battery energy storage facility on or after January 1, 2028, to require the facility to meet the guidelines and minimum standards adopted by the State Fire Marshal or more stringent guidelines and minimum standards as determined appropriate by the public agency.

Re-referred to Com. on
U. & E.

AB 441 Hadwick Wildfire prevention:

Office of Wildfire
Technology Research and
Development: wildfire
Wildfires Would repeal provisions related to the Office of Wildifre Technology Research and Development. Referred to Com. on E.M.

AB 442 Hadwick California Environmental
Quality Act: exemption:
prescribed fire, thinning,
and fuel reduction
Wildfires This bill would exempt from CEQA prescribed fire, thinning, or fuel reduction projects undertaken within a community with a single ingress and egress evacuation route.

Referred to Com. on
NAT. RES.

Medium Priority
AB 443 Bennett Energy Commission:
integrated resource policy
report: curtailed solar and
wind generation:
hydrogen production
Hydrogen This bill would require the commission, as part of the 2027 edition of the integrated energy policy report, to include an assessment of the potential for using curtailed solar and wind generation to produce hydrogen, as provided. The bill would define curtailed solar and wind generation for this purpose and require the assessment to do specified things, including to provide an estimate of how much hydrogen could feasibly and reliably be produced using energy from curtailed solar and wind generation. The bill would repeal its provisions on January 1, 2029.

Referred to Coms. on
NAT. RES. and U. & E.

AB 472 Rogers and
Connolly
Energy: offshore wind
generation
Offshore Wind This bill would amend the definition of “infrastructure” described above to include port infrastructure for offshore wind energy development, and would require the 5-year infrastructure plan to include, beginning in the 2027–28 fiscal year, and contingent upon an appropriation for this purpose, an assessment of funding needs for port infrastructure for offshore wind energy development, as specified. The bill would require the Governor, in consultation with specified entities, to assess federal, state, and local funding opportunities, including general obligation bonds and funding from the private sector, that can help build port infrastructure for offshore wind energy development.

Referred to Coms. on
NAT. RES. and U. & E.

AB 615 Davies Power facilites:
emergency response and
action plan
Power Facilities This bill would require the application to also contain an emergency response and action plan that incorporates impacts to the surrounding areas in the event of an emergency and that would be conducted and coordinated with local emergency management agencies, unified program agencies, and local first response agencies. The bill would require that the plan include analysis and feedback from the local emergency management agencies as to whether the proposed facility requires supplemental first responder capabilities and meets National Fire Association 855 Standard as it relates to setbacks, as specified. The bill would require the plan to be paid for by the applicant.

Referred to Coms. on
E.M. and U. & E.

AB 705 Boerner Public Utilites Comission:

Independent Office of
Audits and Investigations
CPUC This bill would delete the provision providing for the appointment of the chief internal auditor and instead provide that, effective January 1, 2026, the internal audit unit of the commission and its staff are transferred to the Independent Office of Audits and Investigations, which the bill would establish within the commission, as specified. The bill would provide for the appointment and removal of the director of the office, who would have the title of Inspector General. The bill would require that the office have access and authority to examine all records, files, documents, accounts, reports, correspondence, or other property of the commission, public utilities, and other entities regulated by the commission, as specified. The bill would require the Inspector General to report to the Governor and the Legislature, as provided.

Re-referred to Com. on
U. & E.

Medium Priority
AB 716 Carillo Fire safety standards:
hydrogen facilities
Hydrogen This bill would require the State Fire Marshal to adopt the National Fire Protection Association Hydrogen Technologies Code (NFPA 2) as the statewide fire safety standards and guidelines for hydrogen production, storage, and distribution facilities. The bill would prohibit local governments from adopting more stringent fire safety standards than the statewide fire safety standards. The bill would require the State Fire Marshal to appoint a hydrogen fire expert, with specified duties. The bill would require the State Fire Marshal to provide ongoing training to local fire departments and building inspectors, as specified.

Re-referred to Com. on
E.M.

AB 729 Zbur Public utilities: climate
credits
Climate Credits This bill would require that the electric California Climate Credit be provided to residential and small business customers in the bills of those customers for the months of August and September of each year. The bill would require that the natural gas California Climate Credit be provided to residential customers in the bills of those customers for the month of December of each year.

From committee chair,
with author's
amendments: Amend,
and re-refer to Com. on
U. & E. Read second
time and amended.

AB 737 Qurik-Silva Energy: building
decarbonization: notice
and recordation of a
decarbonization charge
Decarbonization This bill would additionally add gas corporations to the definition of “energy supplier” for purposes of the above-described provisions.

Referred to Com. on U.
& E.

AB 738 Tangipa and
Patterson
Energy: building
standards: photovoltaic
requirements
Building Standards This bill would, until January 1, 2029, require residential construction intended to repair, restore, or replace a residential building damaged or destroyed as a result of a disaster in an area in which a state of emergency has been proclaimed by the Governor to comply only with the requirements regarding photovoltaic systems pursuant to those regulations, if any, that were in effect at the time the damaged or destroyed building was originally constructed and would prohibit that construction from being required to comply with any additional or conflicting photovoltaic system requirements in effect at the time of repair, restoration, or replacement. The bill would only apply to the construction of a building if certain conditions are met with respect to the building owner’s income and insurance coverage, and to the location and square footage of the construction.

Referred to Com. on
NAT. RES.

Medium Priority
AB 740 Harabedian Integrated energy policy
report: virtual power
plants
VPP This bill would require the Energy Commission, on or before November 1, 2026, to adopt a strategy to enable virtual power plants to be deployed at scale, as specified. The bill would require the Energy Commission, in developing the strategy, to take certain actions, and would require that the strategy meet specified requirements. The bill would require the strategy adopted pursuant to these provisions to be included in the above-described integrated energy policy report.

Re-referred to Com. on
U. & E.

AB 745 Irwin Electricity: transmission
projects: review and
approval
Transmission Projects This bill would, consistent with the commission’s authority to review and approve new transmission line projects undertaken pursuant to the Independent System Operator planning process, require the commission to review and approve transmission line projects, including the extension, expansion, upgrade, or other modification of existing transmission lines, initiated by an electrical corporation.

Re-referred to Com. on
U. & E.

AB 777 Rodriguez Electricy Oversight Board Electricy Oversight Board
This bill would add to the board 2 more nonvoting legislative members, a 2nd member of the Assembly, appointed by the Speaker of the Assembly, and a 2nd member of the Senate, appointed by the Senate Committee on Rules.

Referred to Com. on U.
& E.

AB 825 Petrie-Norris Energy: cost framework:
rseidential rates
Rates This bill would require the PUC to submit an update to that report to the Legislature every two years following the initial submission, providing an evaluation of the implementation and impact of the framework, and the usage of the framework, identifying the specific requests by an electrical corporation or gas corporation for which the framework was employed by the PUC in evaluating the requests.

Referred to Com. on U.
& E.

AB 841 Patel State Fire Marshal:
personal protective
equipment: fires
Battery Storage This bill would require the State Fire Marshal, in consultation with the Division of Occupational Safety and Health, to develop a working group with specified membership to make recommendations regarding personal protective equipment used in responding to lithium-ion battery fires. The bill would require, at a minimum, the working group to review, and for the purpose of making the recommendations to consider, the latest personal protective equipment to limit exposure to lithium and other heavy metals, technology to clean personal protective equipment, whether different types of personal protective equipment should be used for different types of lithium-ion battery fires, and current decontamination practices at the fire scene, as specified. The bill would require the recommendations to be submitted to the Legislature on or before September 1, 2026.

Re-referred to Com. on
E.M.

Medium Priority
AB 864 Ward Hazardous waste: solar
photovoltaic modules
Solar Panel Recycling This bill would exempt solar photovoltaic modules not identified as hazardous waste and treated as universal waste, as defined, from state hazardous waste regulations, if transferred to a designated recycler for legitimate recycling, as described, and if the facility meets specified criteria relating to registration permits, as provided.

Referred to Com. on
E.S & T.M.

AB 884 Essayli Campaign contributions:
investor-owned utilities
IOU This bill would prohibit an investor-owned utility from making a contribution to a candidate for elective state office and would prohibit a candidate for elective state office from accepting a contribution from an investor-owned utility.

Referred to Com. on
Elections.

AB 915 Petrie-Norris Clean Energy Reliability
Investment Plan
Clean Energy
Reliability Investment
Plan
This bill would appropriate $900,000,000 from the General Fund to the commission for the 2025–26 fiscal year to be allocated for the Clean Energy Reliability Investment Plan for local incentive grants to increase investment in clean energy infrastructure.

From printer. May be
heard in committee
March 22.

AB 942 Calderon Net energy metering:
eligible customer-generators: tariffs.

NEM This bill would provide that, on and after July 1, 2026, an eligible customer-generator that has taken service pursuant to NEM 1.0 or 2.0 for 10 or more years is no longer entitled to take service under that contract or tariff. The bill would require that eligible customer-generator to take service under the then-current applicable tariff adopted by the commission after December 1, 2022, disqualify that eligible customer-generator from eligibility for the avoided cost calculator plus glide path, as specified, and would require the eligible customer-generator to pay all nonbypassable charges that are applicable to customers that are not eligible customer-generators. This bill would, on and after January 1, 2026, for a customer that becomes a new eligible customer-generator by purchasing real property that contains a renewable electrical generation facility upon which a prior eligible customer-generator took service, require the new eligible customer-generator to take service under the then-current applicable tariff adopted by the commission after December 1, 2022, would disqualify the new eligible customer-generator from eligibility for the avoided cost calculator plus glide path, as specified, and would require the new eligible customer-generator to pay all nonbypassable charges that are applicable to customers that are not eligible customer-generators.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1016 Gonzalez Power facility and site
certifications: thermal
powerplants: geothermal
resources
Geothermal This bill would additionally require the commission to exempt from the certification requirement, only until January 1, 2030, a thermal powerplant that generates electricity using geothermal resources and meets specified criteria, including having a generating capacity of up to 150 megawatts, or making modifications to a thermal powerplant that generates electricity using geothermal resources that do not add capacity in excess of 150 megawatts. The bill would make the local governmental agency that has land use and related jurisdiction over the area of the proposed site and related facility the lead agency pursuant to CEQA for any project that the commission exempts from the certification requirement and that generates electricity using geothermal resources as provided.

Re-referred to Com. on
U. & E.

AB 1017 Boerner Public utilities: electrical
and gas corporations:
distribution capacity
Distribution Capacity This bill would require electrical or gas corporations, in a report required to be submitted annually to the commission, to include in the report the capacity of its electrical or gas distribution system, respectively.

Referred to Com. on U.
& E.

AB 1020 Schiavo Public utilities: energy:
nontraditional funding:
reporting
IOU This bill would require each utility, defined as an investor-owned electrical corporation or gas corporation, to report certain information for any nontraditional funding, as defined, that the utility has applied for or received. The bill would require the commission, for each application in which a utility is seeking ratepayer funding, to require the utility to report all relevant nontraditional funding the utility is pursuing or has secured, and, if the commission determines that a utility is not in compliance with that requirement, the bill would authorize the commission to impose a penalty against the utility, as specified. The bill would require the commission to require each utility to promptly deliver the financial benefits of nontraditional funding to ratepayers, as provided.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1104 Pellerin Smarll Business
Renewable Energy
Access and Protection
Act
Solar This bill would qualify a nonresidential photovoltaic renewable electrical generation facility to receive service pursuant to NEM 1.0, NEM 2.0, or the net billing tariff despite an enforcement of a willful violation as described above against a contractor for the construction of the facility, as provided. The bill would, for a technical or unintentional violation by the contractor, grant a cure period of 90 calendar days from the date of the notice of noncompliance to the contractor to cure the violation and make restitution to any affected workers. The bill would provide that if the contractor corrects the violation within the cure period and provides evidence of correction to the Department of Industrial Relations, the violation will be considered resolved, and no penalties will be imposed for that violation. The bill would provide that specified penalties for contractor noncompliance do not accrue to the entity that engaged the contractor, but to the contractor.

Re-referred to Coms.
on L. & E. and U. & E.
pursuant to Assembly
Rule 96.

AB 1117 Schultz Electricity rates: optional
dynamic rate tariffs
Rates This bill would require the commission, through a new or existing proceeding, to develop optional dynamic rate tariffs applicable to each large electrical corporation for the large electrical corporation’s commercial and industrial customers on or before July 1, 2028, and for its other customers, including residential customers, on or before July 1, 2030. The bill would require each optional dynamic rate tariff to include, at minimum, specified components, including dynamic transmission and distribution rates that reflect real-time grid conditions and certain nonbypassable charges, as specified.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1156 Wicks Solar-use easements:
suspension of Williamson
Act contracts: terms of
easement: termination.

Solar This bill would revise these provisions to authorize the Department of Conservation to determine that a parcel is eligible for suspension, as described above, upon the request of the landowner, instead of a request from a county or city, and would require the department to additionally make that determination in consultation with any applicable groundwater sustainability agency or services. The bill would revise the eligibility criteria for a parcel to be deemed eligible under these provisions by (1) additionally authorizing land for which there are or will be insufficient surface water or groundwater rights associated with the land to support commercially viable irrigated agricultural use; (2) deleting the requirement that the land not be located on lands designated as prime farmland, unique farmland, or farmland of statewide importance; and (3) additionally requiring that the land meet certain additional requirements relating to the land’s historical use as cropland and whether it is encumbered by a conservation easement or enrolled in a land conservation program, as specified. The bill would also require the Department of Conservation to issue its determination of eligibility within 120 days following submission of a completed application package, and would deem any application not rejected within this 120-day period to be approved.

Re-referred to Com. on
L. GOV.

AB 1167 Berman Electrical corporations
and gas corporations:
rate recovery: political
activities and promotional
advertising.

IOUs This bill would prohibit, except as provided, an electrical corporation or gas corporation from recording various expenses associated with political influence activities, as defined, or with promotional advertising, as defined, to accounts that contain expenses that the electrical corporation or gas corporation recovers from ratepayers. The bill would require electrical corporations and gas corporations to clearly and conspicuously disclose in all of its advertising whether the costs of the advertising are paid for by the corporation’s shareholders or ratepayers.

The bill would require an electrical corporation or gas corporation, on or before April 30, 2026, and annually thereafter, to provide the commission with a report of expenses from the previous calendar year and would require that, for each business unit of the corporation that performs work associated with political influence activities or promotional advertising, the report contain specified information. The bill would require the commission to make the report publicly available and would authorize the commission to redact information that the commission deems to be confidential in the report.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1173 Patterson Public Utilities
Commission:
organization
IOU/CPUC This bill would prohibit a staff member who moves from the Public Advocate’s Office of the Public Utilities Commission to the commission from working on any matter that the staff member participated in while employed at the office.

Re-referred to Com. on
U. & E.

AB 1174 Alanis Clean Transportation
Program: eligible
programs and projects:
electrical vehicle
charging stations:
vandalism deterrence
EVSE This bill would add to the categories of programs and projects eligible for funding under the Clean Transportation Program programs and projects to deter and combat vandalism of publicly available electric vehicle charging stations.

Referred to Com. on
TRANS.

AB 1176 Flora Energy: renewable energy
resources programs
Energy Spot Bill Referred to Coms. on
U. & E. and NAT. RES.

AB 1182 Irwin State Energy Resources
Conservation and
Development
Commission: report:
electrical grid
infrastructure
manufacturing
Transmission and
Distribution
Manufacturing
This bill would require the commission to prepare and submit a report, on or before July 1, 2026, to the Governor and the Legislature regarding the status of electrical transmission and distribution grid infrastructure manufacturing in this state.

Referred to Com. on U.
& E.

AB 1191 Tangipa California Renewables
Portfolio Standard
Program: hydroelectric
generation.

RPS/Hydro This bill would revise the definition of an eligible renewable energy resource for the purposes of the California Renewables Portfolio Standard Program to include all hydroelectric generating facilities and would make conforming changes.

Referred to Coms. on
U. & E. and NAT. RES.

AB 1207 Irwin Climate change: market-based compliance
mechanism: price ceiling
Cap-and-Trade This bill would require the state board to instead consider the full social cost associated with emitting a metric ton of greenhouse gases, as determined by the United States Environmental Protection Agency in November 2023.

Re-referred to Com. on
NAT. RES.

Medium Priority
AB 1222 Bauer-Kahan Public utilities: judicial
review
IOUs This bill would prohibit the commission from authorizing electrical corporations to recover from their ratepayers the costs associated with seeking judicial review of a commission’s decision from a federal agency, or a state or federal court. The bill would require the electrical corporation to track those costs.

Referred to Coms. on
U. & E. and JUD.

AB 1228 Essayli Electricity: expedited
utility distribution
infrastructure
undergrounding program
Infrastructure This bill would specify that the approval of a distribution infrastructure undergrounding plan is not a project for purposes of the California Environmental Quality Act, as specified.

Referred to Coms. on
U. & E. and NAT. RES.

AB 1238 DeMaio California Energy
Consumer Freedom Act
Electrification This bill, the California Energy Consumer Freedom Act, would prohibit state agencies and local governments from adopting or enforcing a rule, regulation, resolution, or ordinance that directly or indirectly results in prohibiting the use of gas appliances in residential or nonresidential buildings, and the buying, selling, or use of gasoline-powered vehicles or equipment.

Re-referred to Com. on
U. & E.

AB 1260 Ward Electricity: renewable
energy subscription
programs
Community
Renewables
The bill would require the PUC, on or before March 1, 2026, to modify the community renewable energy program to ensure the program meets the bill’s requirements or to adopt a new program and to adopt a final decision by September 1, 2026. The bill would require the State Energy Resources Conservation and Development Commission to evaluate community solar and storage projects as a load-modifying resource so that those projects may be counted as a load-modifying resource.

Referred to Com. on U.
& E.

AB 1273 Patterson Public utilities: electricity
rates
Rates This bill would prohibit the commission from placing the consideration of an application from an electrical corporation for a rate increase on its consent calendar.

Referred to Com. on U.
& E.

AB 1280 Garcia Energy Energy This bill would authorize the I-bank to provide financial assistance in connection with the financing or refinancing of a new category of climate catalyst projects, those that enable the decarbonization of industrial facilities’ use of heat and power, including, but not limited to, industrial heat pump and thermal energy storage projects, as specified, with the State Energy Resources Conservation and Development Commission and the State Air Resources Board as consulting agencies. This bill would establish and implement an Industrial Facilities Thermal Energy Storage Program within the Long-Duration Energy Storage Program to provide financial incentives for eligible projects to decarbonize industrial facilities’ use of heat and power, as specified.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1285 Committee on
Emergency
Management
State Fire Marshal:
lithium-ion battery
facilities: guidance
Battery Storage This bill would require the State Fire Marshal, in consultation with the Office of Emergency Services, to develop fire prevention, response, and recovery measures for utility grade lithium-ion battery storage facilities, as specified.

Referred to Com. on
E.M.

AB 1295 Patterson Public utilities: billing
statements: additional
costs attributable to state
requirements or programs
Billing This bill would require each public utility to provide to its customers information on the additional costs that are attributable to state requirements or programs, including those imposed by statute, regulation, the commission, or the State Energy Resources Conservation and Development Commission. The bill would require this information to be provided quarterly on the customer billing statement in a visible area and in a similar size and font as the billing information.

Referred to Com. on U.
& E.

AB 1301 Petrie-Norris Electricity: Power
Exchange
Power Exchange This bill would abolish the Power Exchange and would make various conforming changes. Referred to Com. on U. & E.

AB 1302 Wallis Electricity: customer
generators: departing
load charges.

Departing Load This bill would require the commission, until December 31, 2031, to study and design a new system for allowing electrical customers of electrical corporations, community choice aggregators, local publicly owned electric utilities, and electrical cooperatives to generate their own electricity on their commercial or residential sites. The bill would require the commission, in designing the new system, to ensure all electrical customers are treated fairly, increase transparency in the calculation and application of departing load charges, promote the development and integration of renewable energy sources, support the state’s clean energy goals, consider the benefits of customer-generated energy, and provide a mechanism for stakeholder input, as provided. The bill would require the commission, on or before December 31, 2027, to submit a report to the Legislature detailing the proposed new process for departing load charges and any recommendations for legislative action.

Re-referred to Com. on
U. & E.

AB 1334 Wallis Solar energy: official state
energy
Solar This bill would establish solar energy as the official state energy. Re-referred to Com. on U. & E.

Medium Priority
AB 1342 Soria Electrical corporations:
climate credits
Climate Credits This bill would require that the electric California Climate Credit be provided to residential customers in the months of June, July, August, and September. The bill would require the commission to ensure that a larger portion of those revenues be allocated as electric California Climate Credits to residential customers living in the hotter regions of the state, as provided.

From committee chair,
with author's
amendments: Amend,
and re-refer to Com. on
U. & E. Read second
time and amended.

AB 1347 Carrillo Electrical modernization
zones
Electrical
modernization zones
This bill would require the Governor’s Office of Business and Economic Development, in conjunction with the ISO, to identify six electrical infrastructure modernization zones, as provided.

The bill would require the PUC and the Energy Commission to recognize these zones as load growth priority areas. The bill would authorize an electrical corporation that serves a customer within an electrical infrastructure modernization zone to work with the local jurisdiction to update its electrical load projections. The bill would require the PUC to authorize an electrical corporation that serves a customer within an electrical infrastructure modernization zone to expedite cost recovery and to manage microgrids, as specified.

From committee chair,
with author's
amendments: Amend,
and re-refer to Com. on
U. & E. Read second
time and amended.

AB 1372 Papan Renewable electrical
generation facilities:
electrified commuter
railroads: regenerative
braking: net billing
Rates This bill would, upon an electrical corporation, electric service provider, or community choice aggregator and an operator of an electrified commuter railroad that produces electricity through the regenerative braking of electric trains, including the Peninsula Corridor Joint Powers Board, completing certain technical studies, require the electrical corporation, electric service provider, or community choice aggregator to adopt or modify a net billing contract or tariff that is approved by the commission or the appropriate rate approving entity, as provided. The bill would require that contract or tariff to, among other things, require the supplier or distributor to apply bill credits for the electricity exported to the electrical grid based on its value, as specified. The bill would require the load-serving entity responsible for the delivery of electricity to provide, or install at its cost, if necessary, metering that records and documents electricity imports and exports, as specified.

Re-referred to Com. on
U. & E.

Medium Priority
AB 1404 Ortega Electrical Corporations:
connections: affordable
housing projects
Rates This bill would require an electrical corporation to connect an affordable housing project, as defined, to the electrical distribution grid within 60 days, except as specified. The bill would require the commission to streamline any necessary review on an affordable housing project that is ready to connect but sitting vacant and that has not been connected by an electrical corporation within the required 60 days. The bill would delay the effective date of a rate increase approved by the commission for the greater of either the amount of time the electrical corporation took, beyond 90 days from receipt of the project building plans, to provide a final contract, or the amount of time the electrical corporation took, beyond the 60 days allowed, to connect the most recently completed affordable housing project within the electrical corporation’s service area.

Referred to Com. on U.
& E.

AB 1408 Irwin Electricity: rates Rates This bill would require that the customer be provided with no less than 2 years, instead of one year, of bill protection during which the total amount paid by the residential customer for electric service is prohibited from exceeding the amount that would have been payable by the residential customer under that customer’s previous rate schedule.

Referred to Com. on U.
& E.

AB 1410 Garcia Public utilities: service
outages and updates:
alerts
Outages This bill would require each public utility to automatically enroll customers in alerts for service outages and updates. The bill would require customers to be provided with the opportunity to opt-out of any alerts the customer does not wish to receive, except as provided. The bill would require each public utility to annually verify a customer’s preferred contact method.

Referred to Com. on U.
& E.

AB 1423 Irwin Transportation
electrification: charging
station uptime:
regulatiosn: violations
EVSE This bill would instead require the Energy Commission, in consultation with the Public Utilities Commission, to adopt tools to increase uptime for all charging stations and set standards for how all charging stations are required to notify customers about the availability and accessibility of publicly available charging infrastructure.

Referred to Coms. on
TRANS. and U. & E.

AB 1436 Avila Farias Biomethane procurement
targets
Biomethane This bill would instead require that biomethane delivered to California through a common carrier pipeline meet either of the specified requirements, rather than both. The bill would also additionally add the displacement of conventional natural gas that results in a reduction in greenhouse gas emissions as one of the specified environmental benefits.

Re-referred to Com. on
U. & E.

AB 1484 Bennett Energy reliability Spot Spot Bill Read first time.

Medium Priority
SB 24 McNerney Electrical and gas
corporations: rates:
political influence
activities and promotional
advertising: termination
of services.

IOU This bill would prohibit, except as provided, an electrical corporation or gas corporation from recording various expenses associated with political influence activities, as defined, promotional advertising, as defined, or opposing the municipalization of electrical or gas service, to accounts that contain expenses that the electrical corporation or gas corporation recovers from ratepayers.

The bill would require electrical corporations and gas corporations to clearly and conspicuously disclose in all of its advertising whether the costs of the advertising are paid for by the corporation’s shareholders or ratepayers. The bill would require an electrical corporation or gas corporation, on or before April 30, 2026, and annually thereafter, to provide the commission with a report of expenses from the previous calendar year and would require that, for each business unit of the corporation that performs work associated with political influence activities or promotional advertising, the report contain specified information. The bill would require the commission to make the report publicly available and would authorize the commission to redact information that the commission deems to be confidential in the report.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

SB 58 Padilla Sales and Use Tax Law:
exemptions: certified
data center facilities
Data Centers This bill would, on and after January 1, 2026, provide a partial exemption from those taxes with respect to the gross receipts from the sale, storage, use, installation, assembly, repair, maintenance, or other consumption of data center equipment, as defined, used at or for the benefit of a certified data center facility, as defined. The bill would require a data center facility to meet specified requirements in order to receive certification from the California Department of Tax and Fee Administration, including requirements relating to job creation, investment, and renewable energy procurement requirements. The bill would require the department to revoke certification where a data center facility obtains certification and subsequently fails to meet these requirements after reasonable opportunity for the data center facility to cure noncompliance, as provided.

Set for hearing May 14.

Medium Priority
SB 80 Caballero The Fusion Research and
Development Innovation
Hub Program.

Fusion This bill would create the Fusion Research and Development Innovation Hub Program within the commission to accelerate the development and growth of fusion energy by advancing fusion science and technology with the goal of delivering the world’s first fusion energy pilot plant in the state in the 2030s. The bill would require, among other things, the commission to designate fusion research and development innovation hubs representing regions of southern California, the central valley, adn the San Francisco Bay Area
Re-referred to Com. on
E., U & C.

SB 86 McNerney California Alternative
Energy and Advanced
Transportation Financing
Authority Act: sales and
use tax exclusion.

Fusion This bill would extend indefinitely the authorization to provide financial assistance in the form of a sales and use tax exclusion for projects approved by the authority. The bill would increase the maximum cumulative amount of the sales and use tax exclusions authorized under these provisions to $300,000,000 per calendar year. The bill would add electrical generation facilities using nuclear fusion technology to the types of projects qualifying for this sales and use tax exclusion. The bill would make other conforming changes.

Set for hearing April 7.

SB 88 Caballero Air resources: carbon
emissions: biomass.

Biomass This bill would require the state board, on or before January 1, 2027, to finalize the standardized system and historic baseline described above. The bill would require the state board, on or before January 1, 2028, to adopt a method of quantification or a lifecycle model for avoided carbon emissions, including, but not limited to, carbon dioxide, methane, and black carbon, from wildfire from the application of prescribed fire to forest biomass resources and agricultural biomass resources, and to develop a carbon credit or offset protocol for biochar and other beneficial carbon-removal products that result from the avoidance of megafires and prescribed fire using existing methodologies.

Read second time and
amended. Re-referred
to Com. on N.R. & W.

SB 252 Valladares CEQA: exemption:
undegrounding
powerlines
CEQA This bill would exempt from the provisions of CEQA a project to underground powerlines. April 2 set for second hearing canceled at
the request of author.

Medium Priority
SB 254 Becker Electricity: Family Electric
Rate Assistance program
FERA This bill would additionally require each electrical corporation’s report to provide a breakdown of the number of eligible households and FERA program enrollment by disadvantaged community, as defined by the commission. The bill would also require the above-described strategy and plan to include strategies to reach households in disadvantaged communities.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

SB 256 Perez Electricity: infrastructure:
wildfire mitigation:
undergrounding:
emergency operations.

Infrastructure This bill would, for the description in the wildfire mitigation plan of the preventive strategies and programs to minimize the risk of its electrical lines and equipment causing catastrophic wildfires, require electrical corporations, electrical cooperatives, and local publicly owned electric utilities to include consideration of low-risk areas. The bill would require a wildfire mitigation plan to include an identification of any lapses in communication coordination during recent past emergency response events with local governments, as specified, and a description of any opportunities to collaborate with local governments, and other steps that can be taken to establish more efficient communication coordination during future emergency responses, as provided. The bill would require electrical corporations, electrical cooperatives, and local publicly owned electric utilities to conduct annual wildfire preparedness workshops in collaboration with and open to any local fire departments in their service areas to provide updates on the latest adopted wildfire mitigation plans, discuss any lapses in, and opportunities to increase efficiency of, communication coordination during emergency responses, and gather input for inclusion in the development of the next annual submission of their wildfire mitigation plans, as provided.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

SB 282 Wiener Residential heat pump
systems: water heaters
and HVAC: installations
Heat Pumps This bill would require the commission, on or before January 1, 2027, to establish a statewide certification program for licensed contractors of residential heat pump water heaters and heat pump heating, ventilation, and air conditioning (HVAC) systems to obtain a heat pump installation certification, and would require the commission to create a state training program, as described, on residential heat pump water heaters and heat pump HVAC systems for purposes of the certification program, as specified.

Set for hearing April 7.

Medium Priority
SB 285 Becker Net zero greenhouse gas
emissions goal: carbon
dioxide removal:
regulations
GHG Emissions This bill would, for the purpose of meeting, or tracking progress against, any state requirement to achieve net zero emissions of greenhouse gases,authorize only qualified carbon dioxide removal, as defined, to be used to counterbalance the state’s or an entity’s greenhouse gas emissions and would require qualified carbon dioxide removal used for those purposes to meet certain requirements, as specified.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E.Q.

SB 298 Caballero State Energy Resources
Conservation and
Development
Commission: seaports:
plan: alternative fuels
Alternative Fuels This bill would require the State Energy Resources Conservation and Development Commission (Energy Commission), in coordination with the Transportation Agency and the state board, to develop a plan on or before December 31, 2030, for the use and deployment of alternative fuels at California’s public seaports, as provided. The bill would require the Energy Commission to convene a working group to advise the Energy Commission on the development of information required by the plan, as specified.

Set for hearing April 7.

SB 314 Padilla Weights and measures:
electric vehicle supply
equipment
EVSE This bill would authorize an EVSE that has been audited or tested by the manufacturer or supplier to be used commercially without further testing during the remainder of the inspection period adopted by the Secretary of Food and Agriculture, but not until it has been sealed by a sealer. The bill would, among other things, require the county sealer to ensure that certain EVSE installed before January 1, 2026, are initially placed in service and tested by a sealer on or before January 1, 2027, at no additional cost other than the registration fees paid by the EVSE owner or operator.

Set for hearing April 21.

SB 326 Becker and Laird Wildfire safety: The
California Wildfire
Mitigation Strategic
Planning Act
Wildfires This bill would require the deputy director, on or before January 1, 2027, and every 3 years thereafter, to prepare a Wildfire Risk Mitigation Planning Framework sufficient to quantitatively evaluate wildfire risk mitigation actions, as provided. The bill would require the framework to allow for geospatial evaluation and comparison of wildfire risk mitigation actions, as defined, sufficient to direct coordinated mitigation efforts and long-term collaborative mitigation planning. The bill would require the deputy director to, each year the framework is completed, submit a copy of the framework to the Legislature, the Office of Energy Infrastructure Safety, and the Public Utilities Commission for review and consideration.

From committee: Do
pass and re-refer to
Com. on N.R. & W. with
recommendation: To
consent calendar.
(Ayes 13. Noes 0.)
(March 25). Re-referred to Com. on
N.R. & W.

Medium Priority
SB 327 McNerney Fusion energy data
centers
Fusion energy This bill would require the commission to initiate an agreement with the United States Department of Energy for the establishment of a fusion energy data center, as specified.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

Medium Priority
SB 332 Wahab Investor-Owned Utilities
Accountability Act
IOU Oversight 1) This bill would require the Energy Commission, in coordination with the public advisor and the Public Utilities Commission (PUC), on or before March 31, 2026, to issue a request for proposals for a team to develop a study. The bill would require the study to (1) conduct a historical energy justice assessment of the investor-owned utility’s (IOU) operations and impacts, (2) complete a comparative analysis of the benefits and challenges of transitioning the IOUs to a successor entity in order to identify a recommended model, and, (3) if the study finds that it is in the best long-term interests of the people and ecologies of California to transition away from an investor-owned utility model, create a justice-centered implementation plan for managing the transition. 2) This bill would, among other things, prohibit a utility, including an electrical corporation, local publicly owned electric utility, gas corporation, and local publicly owned gas utility, from disconnecting a customer’s residential service for nonpayment if the customer has a household income at or below 200% of the federal poverty line. The bill would prohibit a utility from disconnecting a customer’s residential service for nonpayment if the customer’s household is the residence of certain persons, including, among other persons, a person who is pregnant or 0 to 12 weeks postpartum. 3) This bill would require each electrical corporation, on or before April 1, 2026, to submit a proposed executive compensation structure to the PUC that is structured to promote safety as a priority and to ensure public safety through performance metrics, as provided. 4) This bill would prohibit, for proposed rate increases subject to PUC approval and a finding that the new rate is just and reasonable, an electrical corporation from proposing a compounded annual rate increase on residential customers above the increase in the Consumer Price Index. 5) Beginning with the fiscal year commencing July 1, 2026, and ending with the fiscal year ending June 30, 2036, this bill would require the PUC to annually allocate $100,000,000 of the revenues received by the electrical corporations from that allocation of greenhouse gas allowances to the Transformative Climate Communities Program and to the Community Resilience Center Program, as specified. 6) This bill would require each electrical corporation to annually contract with an independent and reputable third party to audit all of the electrical corporation’s equipment and electrical lines and identify any equipment or electrical lines that have outlived their useful life.

Referred to Coms. on
E., U & C. and JUD.

Medium Priority
SB 348 Hurtado State Air Resources
Board: Low-Carbon Fuel
Standard
LCFS This bill would require the state board, beginning no later than January 31, 2026, to reconsider and revise the Low Carbon Fuel Standard to reduce the program’s financial burden on drivers in the state, including by taking specified actions.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

SB 377 Grayson Biomethane procurement
targets
Biomethane This bill would instead require that biomethane delivered to California through a common carrier pipeline meet either of the specified requirements, rather than both. The bill would also additionally add the displacement of conventional natural gas that results in a reduction in greenhouse gas emissions as one of the specified environmental benefits.

Set for hearing April 7.

SB 500 Stern Electrical corporations:
performance metrics and
incentives.

IOUs This bill would require the commission to evaluate performance metrics and financial performance-based incentives to identify mechanisms that may serve to better align electrical corporation operations, expenditures, and investments with delivering safe and reliable electrical service and achieving public policy goals, while minimizing costs for ratepayers. The bill would require the commission to prioritize performance metrics and financial performance-based incentives that can reduce electrical corporations’ preference for investments that can be added to their ratebase and instead encourage electrical corporations to propose the most cost-effective solutions for providing safe and reliable electrical service, as provided. The bill would require the commission, on or before January 1, 2028, to begin tracking one or more of the performance metrics identified, and to subsequently consider whether financial performance-based incentives linked to those performance metrics would be effective and beneficial for minimizing costs for ratepayers.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E., U & C.

SB 533 Richardson Electric vehicle charging
stations: internet based
applications
EVSE This bill would create an exception to the above-described provisions that authorizes an electric vehicle charging station to require that payment for charging services be made through the use of an internet-based application and require the use of that internet-based application for admission to the premises.

From committee: Do
pass as amended and
re-refer to Com. on
TRANS. (Ayes 16. Noes

0.) (March 24).

Medium Priority
SB 534 Padilla Green Empowerment
Zone for the Salton Sea
and Southeastern Desert
Valleys.

Green Empowerment
Zone
This bill, until January 1, 2035, would authorize establishment of a Green Empowerment Zone for the Salton Sea and Southeastern Desert Valleys (empowerment zone). The bill would authorize the empowerment zone to be composed of specified land and communities within the Imperial, Eastern Coachella, and Palo Verde Valleys, upon adoption of a resolution by the Imperial County Board of Supervisors, and would provide for the empowerment zone to be governed by a board of directors, as specified. The bill would task the empowerment zone with various duties, including, among other things, identification of projects and programs that will best utilize public dollars, distribute benefits to disinvested communities, and most quickly improve the economic vitality of California’s southeastern desert valleys, as specified, in a coordinated effort to support the development and equitable transition to a clean energy economy. The bill would require the board of directors, beginning on January 1, 2027, to submit an annual progress report to the Legislature and the Governor’s Office of Business and Economic Development, as specified. The bill would require the empowerment zone, commencing on January 1, 2027, as specified, to post the above-described report on its internet website and to submit a letter to the Legislature informing the Legislature that the report has been posted.

Set for hearing April 7.

SB 559 Stern Electricity: deenergization
events: communications
Deenergization events This bill would require, at the start of a deenergization event, an electrical corporation to immediately notify local emergency management organizations and local utility districts about the impacts of the deenergization, as specified. The bill would require detailed status information on restoration efforts to be made available to emergency management organizations, public safety officials, customers, and the public in real-time, with regular progress updates issued at intervals of no more than 12 hours, for all impacted circuits, as specified.

Set for hearing March

24. Medium Priority
SB 567 Limon Gravity-Based Energy
Storage Well Pilot
Program
Energy Storage This bill would, until January 1, 2035, establish the Gravity-Based Energy Storage Well Pilot Program and would authorize the supervisor to authorize the conversion of not more than 250 wells for use as gravity-based energy storage wells, as defined, to evaluate their use, including the establishment of appropriate operating conditions and physical parameters to safely generate energy. The bill would require idle wells that are authorized for use as gravity-based energy storage wells to be identified as gravity-based energy storage wells in a plan for the management and elimination of idle wells or updates to the plan required to be filed with the supervisor. The bill would require the mechanical integrity of gravity-based energy storage wells to be assessed by the Geologic Energy Management Division not less than annually. The bill would require an operator of a gravity-based energy storage well, in the event of a loss of mechanical integrity of the well or a leak to the environment, to notify the division, the State Air Resources Board, the appropriate regional water quality control board, and schools and community members within 3,200 feet of the well and to cease operation until the mechanical integrity is restored or to plug and abandon the well, as provided. The bill would require gravity-based energy storage wells to be continuously monitored for fluid leaks. The bill would specify that the authorization for wells to be used as gravity-based energy storage wells end at the termination of the pilot program. The bill would, by January 1, 2033, require the Secretary for Environmental Protection, in consultation with certain entities, to evaluate the pilot program and make recommendations to the Legislature for a framework to implement an ongoing Gravity-Based Energy Storage Well Program to regulate the operation of gravity-based energy storage wells, as provided.

Read second time and
amended. Re-referred
to Com. on E.Q.

Medium Priority
SB 593 Hurtado Power surges: ratepayer
notice
Notice This bill would require a utility, which includes a community choice aggregator, an electrical corporation, and a local publicly owned electric utility, to develop and implement a system to notify a ratepayer of a power surge, as defined. The bill would require the notification to be transmitted within 5 minutes of detecting a power surge and to include specified information. The bill would also require a preemptive warning of a power surge, as provided, under specified circumstances. The bill would require a utility to install and maintain equipment capable of detecting power surges and to submit quarterly reports to the commission regarding power surges, as provided. The bill would require a utility to compensate a ratepayer for damages to electrical systems, appliances, or devices caused by a power surge if the power surge resulted from utility equipment failure or negligence, to process claims for compensation within 30 days of receipt, and to offer financial incentives or rebates for the installation of whole-house surge protection systems by ratepayers.

Set for hearing April 7.

SB 620 Stern Public utilities: general
rate cases: electrical grid
infrastructure
General Rate Cases This bill would require the commission to prioritize the gathering, analysis, and independent verification of utility data used to justify general rate case proposals to ensure the cost-effective use of ratepayer funds for capital investments in electrical distribution and transmission grid infrastructure and the operation and maintenance of that infrastructure.

Referred to Com. on E.,
U & C.

SB 636 Menjivar Electrical or gas
corporations: deferment
of payments: hardship
Disconnections This bill would prohibit an electrical or gas corporation from disconnecting service of a customer who meets certain criteria, including making a hardship request based on certain circumstances, as provided. The bill would require the corporation to grant that customer a 6-month deferment for any and all payments due from the date that the deferment is granted. Upon the expiration of the deferment period, the bill would require the corporation to enroll the customer into its arrearage management program for any and all debts on the customer’s account. The bill would authorize the commission to adopt rules to implement these provisions.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E., U & C.

Medium Priority
SB 684 Menjivar Polluters Pay Climate
Superfund Act of 2025.

Climate This bill would enact the Polluters Pay Climate Superfund Act of 2025 and would establish the Polluters Pay Climate Superfund Program to be administered by the California Environmental Protection Agency to require fossil fuel polluters to pay their fair share of the damage caused by greenhouse gases released into the atmosphere during the covered period, which the bill would define as the time period between the 1990 and 2024 calendar years, inclusive, resulting from the extraction, production, refining, sale, or combustion of fossil fuels or petroleum products, to relieve a portion of the burden to address cost borne by current and future California taxpayers.

The bill would require the agency, within 90 days of the effective date of the act, to determine and publish a list of responsible parties, which the bill would define as an entity with a majority ownership interest in a business engaged in extracting or refining fossil fuels that, during the covered period, did business in the state or otherwise had sufficient contact with the state, and is determined by the agency to be responsible for more than 1,000,000,000 metric tons of covered fossil fuel emissions, as defined, in aggregate globally, during the covered period.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on E.Q.

SB 698 McNerney California Solar Initiative:
distributed energy
resource equipment lists
DER This bill would authorize the Energy Commission to establish distributed energy resource equipment lists with rating standards for equipment, components, and systems that further state energy and environmental goals, including, but not limited to, for solar energy systems, energy storage systems, bidirectional charging systems, and electric vehicle supply equipment. The bill would define various terms for these purposes. The bill would require the Energy Commission to adopt guidelines for the distributed energy resource equipment lists, as provided.

Set for hearing April 7.

Medium Priority
SB 707 Durazo Open meetings: meeting
and teleconference
requirements.

Brown Act This bill would, until January 1, 2030, require a city council or a county board of supervisors to comply with additional meeting requirements, including that all open and public meetings include an opportunity for members of the public to attend via a two-way telephonic option or a two-way audiovisual platform, as defined, that a system is in place for requesting and receiving interpretation services for public meetings, as specified, and that good faith efforts are made to encourage residents to participate in public meetings, as specified. By imposing additional meeting requirements on city councils and county boards of supervisors, this bill would impose a state-mandated local program. This bill would also require the agenda to be provided in English and in all other languages spoken jointly by 20% or more of the population in the county in which the local agency is located that, among other things, speaks English less than “very well,” as specified. By imposing additional agenda requirements on legislative bodies of local agencies, this bill would impose a state-mandated local program.

Set for hearing April 2.

SB 708 Alvarado-Gil Public Utilities
Commission: quorum for
the transaction of
business
CPUC Spot Bill Referred to Com. on
RLS.

SB 710 Blakespear Property taxation: active
solar energy systems:
extension
Solar Under existing property tax law, this exclusion remains in effect only until there is a subsequent change in ownership, but an active solar energy system that qualifies for the exclusion before January 1, 2027, will continue to receive the exclusion until there is a subsequent change in ownership. Existing law repeals these exclusion provisions on January 1, 2027. This bill would, beginning with the 2026–27 fiscal year, extend the exclusion indefinitely, and would limit the exclusion to customer-sited active solar energy systems, as defined.

Set for hearing May 14.

SB 714 Archuleta Zero-emission vehicles:
workforce development:

Clean Energy Workforce
Training Council
Workforce
Development
This bill would state the intent of the Legislature to enact legislation that would establish a zero-emission vehicle workforce development pilot project and a Clean Energy Workforce Training Council, as provided.

Referred to Com. on
RLS.

Medium Priority
SB 752 Richardson Sales and use taxes:
exemtions: California
Hybrid and Zero-Emission
Truck and Bus Voucher
Incentive Project: transit
buses
Tax on ZE Buses The Sales and Use Tax Law provides various exemptions from those taxes, including, until January 1, 2026, an exemption from those taxes with respect to the sale in this state of, and the storage, use, or other consumption in this state of, specified zero-emission technology transit buses sold to specified public agencies that are eligible for specified incentives from the State Air Resources Board. This bill would extend the exemption for specified zero-emission technology transit buses until January 1, 2028.

Set for hearing May 14.

SB 755 Blakespear California Procurement
Climate Information Act
California
Procurement Climate
Information Act
This bill, the California Procurement Climate Information Act, would require the department, beginning January 1, 2027, to require a large contractor and significant contractor, as defined, to report their greenhouse gas emissions and climate-related financial risk, as specified. The bill would require the report to include, for large contractors, an annual disclosure of scope 1 emissions, scope 2 emissions, scope 3 emissions, and climate-related financial risk, as specified, and for significant contractors, an annual disclosure of scope 1 emissions and scope 2 emissions, as specified.

Referred to Coms. on
G.O. and E.Q.

SB 782 Perez Enhanced infrastructure
financing district: climate
resilience districts.

Enhanced
infrastructure climate
district
This bill would authorize a city or county to adopt a resolution providing for the division of taxes of any participating entity without following specified procedures for the preparation and adoption of an infrastructure financing plan, if certain conditions are met. The bill would require the district to hold a public meeting to consider the resolution of intention to establish the district and a second public meeting to consider the adoption of the infrastructure financing plan, and would require the district to post specified notices prior to the meetings. The bill would require the resolution to include specified information, including that incremental property tax revenue from the city or county and all affected taxing entities within the district may be used to finance the district’s activities. The bill would require the district to make the infrastructure financing plan available for public inspection at least 10 days before the hearing to approve the formation of the district, and would require the designated official of the district to consult with each affected taxing entity prior to development of the infrastructure financing plan.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

Medium Priority
SB 787 McNerney Energy: Task Force on
Equitable Clean Energy
Supply Chains and
Industrial Policy in
California
Task Force on
Equitable Clean
Energy Supply Chains
This bill would require the commission, on or before March 1, 2026, to designate a person, within the commission, to serve as the Senior Counselor on Industrial Policy and Clean Energy Development and would specify the senior counselor’s duties. The bill would require the senior counselor, on or before March 1, 2026, to convene the Task Force on Equitable Clean Energy Supply Chains and Industrial Policy in California, as provided, and would specify the duties and responsibilities of the task force. The bill would require the task force, on or before June 1, 2027, to submit to the Legislature a report on, among other things, its recommendations on strategies that would maximize the impact of state funds on promoting certain clean energy industries. The bill would require the Senior Counselor on Infrastructure, upon the issuance of the report, but on or before January 1, 2028, to convene certain state agencies to develop a workplan to implement the recommendations made in the report.

Referred to Com. on E.,
U & C.

SB 803 Durazo California Conservation
Corps: Green Collar
Certification Program
California
Conservation Corps
This bill would require the Director of the California Conservation Corps to establish a Green Collar Certification Program that provides young persons participating in the corps with skills and education relating to reducing carbon emissions in residential and nonresidential buildings, preparing communities for environmental disasters, and developing conservation infrastructure projects that stabilize shorelines and restore ecological habitats, as provided.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on N.R. & W.

SB 804 Archuleta Hydrogen pipeline safety Hydrogen This bill would require the PUC to require that hydrogen pipelines meet specified requirements.

The bill would require the PUC to establish, on or before January 1, 2028, and, with the exception specified below, to enforce, standards that meet or exceed those requirements, as provided. The bill would require the Energy Commission to enforce the standards for private, intrastate hydrogen pipelines.

The bill would require a hydrogen pipeline owner to maintain accurate records of hydrogen concentration levels within its hydrogen pipeline and any leakage of hydrogen and, on or before December 31 of each year, to submit a report to the PUC detailing compliance with that requirement.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

Medium Priority
SB 810 Dahle Electricity: ratepayer-funded programs: reportsReporting Existing law requires the State Energy Resources Conservation and Development Commission (Energy Commission) to administer various programs, such as the Electric Program Investment Charge program, that are funded by a charge on electrical ratepayers. Existing law requires the Public Utilities Commission (PUC) to require electrical corporations to implement various programs, such as energy efficiency programs, that are funded by electrical ratepayers. Under its authority, the Governor has issued an executive order directing the Energy Commission and the PUC to examine electrical ratepayer-funded programs under their respective jurisdictions and to identify programs and regulations that may be unduly adding to electricity rates for which the benefits provided may not be justified by the costs imposed on electrical ratepayers. The executive order requires those 2 commissions to report back to the Governor by January 1, 2025. This bill would require the Energy Commission and the PUC, by July 1, 2025, to each submit to the Legislature a report containing certain information required by the executive order.

Referred to Com. on E.,
U & C.

SB 836 Rubio Electricity: transmission
planning and permitting
Transmission Existing law requires the Energy Commission and PUC, in coordination with the Independent System Operator, every 5 years, to review and update, as necessary, the memorandum of understanding and a related workplan to ensure the memorandum and workplan reflect the coordination that is needed to help meet the state’s energy goals. This bill would require those entities to review and update, as necessary, the memorandum every 3 years, rather than every 5 years.

Referred to Com. on E.,
U & C.

SB 840 Limon and McGuire Greenhouse gases: report Cap-and-Trade This bill would extend indefinitely the requirement for the Legislative Analyst’s Office to annually submit to the Legislature the report on the economic impacts and benefits of those greenhouse gas emissions targets. The bill would require the committee, at a public hearing, to review the annual report by the Legislative Analyst’s Office.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

Medium Priority
SB 842 Stern Energy: firm zero-carbon
resources
Zero-Carbon
Resources
This bill would require the Energy Commission, on or before July 1, 2026, through a new or ongoing proceeding, to identify programs it administers that provide, or could provide, financial support to deploy firm zero-carbon resources, mechanisms to use uncommitted or new authorized funds in a manner that maximizes system and local reliability benefits and affordability outcomes, as provided, and the expected scope of energy resources that could be deployed based on current and expected funding availability. The bill would require the PUC, on or before December 31, 2026, through a new or ongoing proceeding, to establish or identify a process by which each load-serving entity subject to its jurisdiction may solicit bids and propose projects for new firm zero-carbon resources to meet identified local reliability needs, as provided. The bill would require the PUC, on or before December 31, 2026, to produce a report identifying opportunities and needs to provide for local reliability with firm zero-carbon resources over the short term, midterm, and long term, as provided. The bill would require the PUC, beginning on or before December 31, 2026, to evaluate resources necessary to optimize local reliability at least cost. The bill would require the PUC, as part of the evaluation, to ensure that each load-serving entity’s integrated resource plan considers all reasonable new resource options that could be deployed to meet local reliability requirements at least cost and that each load-serving entity take reasonable actions to ensure that an appropriate proportion of new resource development occurs in local reliability areas.

From committee with
author's amendments.

Read second time and
amended. Re-referred
to Com. on RLS.

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 7.5
--------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Tiffany Law, Chief Financial Officer
Approved by: Joe Mosca, Chief Executive Officer
Subject: RATIFY RATES EFFECTIVE MARCH 24, 2025
Date: April 14, 2025
---------------------------------------------------------------------------------------------------------------------

RECOMMENDED ACTION
Ratify rates effective March 24, 2025.

BACKGROUND
On February 26, 2025, SCE requested permission to adjust various components of its revenue requirement and rates, effective March 1, 2025. The revenue requirement will decrease by approximately $161 million compared to January 1, 2025. The rate changes primarily affect the Transmission and Delivery (T&D) portion by removing the amortization of previously authorized operation and maintenance expenses from 2021 and incremental uncollectible expenses from 2020. Additionally, SCE is adjusting the time-of-use (TOU) differentials in the generation portion of residential default TOU rates. The T&D rate changes have a minimal impact on customers, with a typical residential customer seeing a monthly bill decrease of just over $1.

ANALYSIS AND DISCUSSION
Due to Calpine’s billing system requirements, OCPA’s new rates became effective on March 24, 2025. The attached OCPA rate schedules, effective March 24, 2025, have been published on the OCPA website. These rates have also been communicated to customers via their bills and implemented in the OCPA rates comparison tool, effective March 24, 2025, which is available on the OCPA website.

FISCAL IMPACT
The Board’s ratification of the OCPA rates for March 24, 2025, has no fiscal impact.

ATTACHMENTS
OCPA Rate Schedules Effective March 24, 2025 – Residential and Commercial Customers Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

DOMESTIC
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.12323 $ 0.13323 $ 0.13823 $ All electric usage TOU-D-4 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.24871 $ 0.25871 $ 0.26371 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.14074 $ 0.15074 $ 0.15574 $ 4pm - 9pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.08352 $ 0.09352 $ 0.09852 $ All other hours WINTER MID-PEAK 0.18158 $ 0.19158 $ 0.19658 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.10852 $ 0.11852 $ 0.12352 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.09104 $ 0.10104 $ 0.10604 $ 8am - 4pm, every day TOU-D-5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.38633 $ 0.39633 $ 0.40133 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.20625 $ 0.21625 $ 0.22125 $ 5pm - 8pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.07455 $ 0.08455 $ 0.08955 $ All other hours WINTER MID-PEAK 0.26331 $ 0.27331 $ 0.27831 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.10694 $ 0.11694 $ 0.12194 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.08148 $ 0.09148 $ 0.09648 $ 8am - 5pm, every day TOU-D-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.26354 $ 0.27354 $ 0.27854 $ 2pm - 8pm, Monday - Friday SUMMER OFF-PEAK 0.11952 $ 0.12952 $ 0.13452 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
SUMMER SUPER OFF-PEAK 0.08898 $ 0.09898 $ 0.10398 $ 10pm - 8am, every day WINTER ON-PEAK 0.16313 $ 0.17313 $ 0.17813 $ 2pm - 8pm, Monday - Friday WINTER OFF-PEAK 0.09488 $ 0.10488 $ 0.10988 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
WINTER SUPER OFF-PEAK 0.09066 $ 0.10066 $ 0.10566 $ 10pm - 8am, every day TOU-D-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.38707 $ 0.39707 $ 0.40207 $ 2pm - 8pm, Monday - Friday SUMMER OFF-PEAK 0.11948 $ 0.12948 $ 0.13448 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
SUMMER SUPER OFF-PEAK 0.05374 $ 0.06374 $ 0.06874 $ 10pm - 8am, every day WINTER ON-PEAK 0.15787 $ 0.16787 $ 0.17287 $ 2pm - 8pm, Monday - Friday WINTER OFF-PEAK 0.09489 $ 0.10489 $ 0.10989 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
WINTER SUPER OFF-PEAK 0.05460 $ 0.06460 $ 0.06960 $ 10pm - 8am, every day TOU-D-PRIME Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.28834 $ 0.29834 $ 0.30334 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11305 $ 0.12305 $ 0.12805 $ 4pm - 9pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.08087 $ 0.09087 $ 0.09587 $ All other hours WINTER MID-PEAK 0.25415 $ 0.26415 $ 0.26915 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07085 $ 0.08085 $ 0.08585 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.07085 $ 0.08085 $ 0.08585 $ 8am - 4pm, every day TOU-D-T Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.15191 $ 0.16191 $ 0.16691 $ 12pm - 6pm, Monday - Friday except holidays*
SUMMER OFF-PEAK 0.13957 $ 0.14957 $ 0.15457 $ All other hours WINTER ON-PEAK 0.11696 $ 0.12696 $ 0.13196 $ 12pm - 6pm, Monday - Friday except holidays*
WINTER OFF-PEAK 0.10779 $ 0.11779 $ 0.12279 $ All other hours

RESIDENTIAL CUSTOMERS
*Holidays are New Year's Day, Presidents’ Day, Memorial Day, Independence Day, Labor Day, Veterans Day, Thanksgiving Day, and Christmas.

OCPA Rate RIN - Basic Choice RIN - Smart Choice RIN - 100% Renewable TOU-D-4 USCA-XXOC-0017-0000 USCA-XXOC-0125-0000 USCA-XXOC-0124-0000 TOU-D-5 USCA-XXOC-0018-0000 USCA-XXOC-0127-0000 USCA-XXOC-0126-0000 TOU-D-A USCA-XXOC-0019-0000 USCA-XXOC-0129-0000 USCA-XXOC-0128-0000 TOU-D-B USCA-XXOC-0020-0000 USCA-XXOC-0131-0000 USCA-XXOC-0130-0000 TOU-D-PRIME USCA-XXOC-0021-0000 USCA-XXOC-0133-0000 USCA-XXOC-0132-0000 TOU-D-T USCA-XXOC-0022-0000 USCA-XXOC-0135-0000 USCA-XXOC-0134-0000 Orange County Power Authority Rate Identification Number (RIN) Key The tables below show the corresponding Rate Identification Number (RIN) to Orange County Power Authority (OCPA) rate.

OCPA rates that are not time-dependent or Time-of-Use (TOU) do not have a corresponding RIN and are therefore excluded from this key. Your RIN can also be found below the "Details of your new charges" section on the generation portion of your utility bill.

Residential Customers
Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
TOU-GS-1-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.11273 $ 0.12273 $ 0.12773 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10269 $ 0.11269 $ 0.11769 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07046 $ 0.08046 $ 0.08546 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10664 $ 0.11664 $ 0.12164 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07799 $ 0.08799 $ 0.09299 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.06067 $ 0.07067 $ 0.07567 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00042) (0.00042) $ (0.00042) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00080) (0.00080) $ (0.00080) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00083) (0.00083) $ (0.00083) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 14.59 $ 14.59 $ 14.59 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 4.48 $ 4.48 $ 4.48 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.19) (0.19) $ (0.19) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.45) (0.45) $ (0.45) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.45) (0.45) $ (0.45) $ 4pm - 9pm, Monday - Friday
TOU-GS-1-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.39535 $ 0.40535 $ 0.41035 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11200 $ 0.12200 $ 0.12700 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.08268 $ 0.09268 $ 0.09768 $ 9pm - 4pm, every day WINTER MID-PEAK 0.16522 $ 0.17522 $ 0.18022 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09586 $ 0.10586 $ 0.11086 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.05468 $ 0.06468 $ 0.06968 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00117) (0.00117) $ (0.00117) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00254) (0.00254) $ (0.00254) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00258) (0.00258) $ (0.00258) $ All electric usage TOU-GS-1-ES Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.42065 $ 0.43065 $ 0.43565 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.12177 $ 0.13177 $ 0.13677 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.08712 $ 0.09712 $ 0.10212 $ 9pm - 4pm, every day WINTER MID-PEAK 0.15865 $ 0.16865 $ 0.17365 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09011 $ 0.10011 $ 0.10511 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.05199 $ 0.06199 $ 0.06699 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00116) (0.00116) $ (0.00116) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00254) (0.00254) $ (0.00254) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00258) (0.00258) $ (0.00258) $ All electric usage TOU-GS-1-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.14775 $ 0.15775 $ 0.16275 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.13879 $ 0.14879 $ 0.15379 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.13390 $ 0.14390 $ 0.14890 $ All other hours WINTER MID-PEAK 0.10115 $ 0.11115 $ 0.11615 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.09195 $ 0.10195 $ 0.10695 $ All other hours TOU-GS-1-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08475 $ 0.09475 $ 0.09975 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07987 $ 0.08987 $ 0.09487 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07720 $ 0.08720 $ 0.09220 $ All other hours WINTER MID-PEAK 0.10115 $ 0.11115 $ 0.11615 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.09195 $ 0.10195 $ 0.10695 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 10.71 $ 10.71 $ 10.71 $ 12pm - 6pm, Monday - Friday

COMMERCIAL CUSTOMERS
Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 3.48 $ 3.48 $ 3.48 $ 8am - 12pm & 6pm - 11pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
TOU-GS-2-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10934 $ 0.11934 $ 0.12434 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10054 $ 0.11054 $ 0.11554 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06796 $ 0.07796 $ 0.08296 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07693 $ 0.08693 $ 0.09193 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07735 $ 0.08735 $ 0.09235 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04518 $ 0.05518 $ 0.06018 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00081) (0.00081) $ (0.00081) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00180) (0.00180) $ (0.00180) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00182) (0.00182) $ (0.00182) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 18.51 $ 18.51 $ 18.51 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 4.86 $ 4.86 $ 4.86 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.42) (0.42) $ (0.42) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (0.97) (0.97) $ (0.97) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.98) (0.98) $ (0.98) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.10) (0.10) $ (0.10) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.25) (0.25) $ (0.25) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.25) (0.25) $ (0.25) $ 4pm - 9pm, Monday - Friday
TOU-GS-2-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.34584 $ 0.35584 $ 0.36084 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10054 $ 0.11054 $ 0.11554 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06796 $ 0.07796 $ 0.08296 $ 9pm - 4pm, every day WINTER MID-PEAK 0.11460 $ 0.12460 $ 0.12960 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07735 $ 0.08735 $ 0.09235 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04518 $ 0.05518 $ 0.06018 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00122) (0.00122) $ (0.00122) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00273) (0.00273) $ (0.00273) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00275) (0.00275) $ (0.00275) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 5.13 $ 5.13 $ 5.13 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 1.99 $ 1.99 $ 1.99 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.17) (0.17) $ (0.17) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (0.39) (0.39) $ (0.39) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.40) (0.40) $ (0.40) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.04) (0.04) $ (0.04) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.11) (0.11) $ (0.11) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.11) (0.11) $ (0.11) $ 4pm - 9pm, Monday - Friday
TOU-GS-2-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08179 $ 0.09179 $ 0.09679 $ 12pm - 6pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 0.07713 $ 0.08713 $ 0.09213 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07458 $ 0.08458 $ 0.08958 $ All other hours WINTER MID-PEAK 0.09733 $ 0.10733 $ 0.11233 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06143 $ 0.07143 $ 0.07643 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.83 $ 12.83 $ 12.83 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.31 $ 4.31 $ 4.31 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-GS-2-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.25127 $ 0.26127 $ 0.26627 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.12445 $ 0.13445 $ 0.13945 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07458 $ 0.08458 $ 0.08958 $ All other hours WINTER MID-PEAK 0.09733 $ 0.10733 $ 0.11233 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06143 $ 0.07143 $ 0.07643 $ All other hours

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00208) (0.00208) $ (0.00208) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00470) (0.00470) $ (0.00470) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00475) (0.00475) $ (0.00475) $ All electric usage Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
TOU-GS-3-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10181 $ 0.11181 $ 0.11681 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09366 $ 0.10366 $ 0.10866 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06629 $ 0.07629 $ 0.08129 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07507 $ 0.08507 $ 0.09007 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07546 $ 0.08546 $ 0.09046 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04406 $ 0.05406 $ 0.05906 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00082) (0.00082) $ (0.00082) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00180) (0.00180) $ (0.00180) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00183) (0.00183) $ (0.00183) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 15.88 $ 15.88 $ 15.88 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.75 $ 5.75 $ 5.75 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.37) (0.37) $ (0.37) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (0.85) (0.85) $ (0.85) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.86) (0.86) $ (0.86) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.15) (0.15) $ (0.15) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.31) (0.31) $ (0.31) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.31) (0.31) $ (0.31) $ 4pm - 9pm, Monday - Friday
TOU-GS-3-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.28336 $ 0.29336 $ 0.29836 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09366 $ 0.10366 $ 0.10866 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06629 $ 0.07629 $ 0.08129 $ 9pm - 4pm, every day WINTER MID-PEAK 0.11550 $ 0.12550 $ 0.13050 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07546 $ 0.08546 $ 0.09046 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04406 $ 0.05406 $ 0.05906 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00151) (0.00151) $ (0.00151) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00337) (0.00337) $ (0.00337) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00342) (0.00342) $ (0.00342) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 4.40 $ 4.40 $ 4.40 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.34 $ 2.34 $ 2.34 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.15) (0.15) $ (0.15) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (0.34) (0.34) $ (0.34) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.35) (0.35) $ (0.35) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.05) (0.05) $ (0.05) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.12) (0.12) $ (0.12) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.12) (0.12) $ (0.12) $ 4pm - 9pm, Monday - Friday
TOU-GS-3-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.07814 $ 0.08814 $ 0.09314 $ 12pm - 6pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 0.07359 $ 0.08359 $ 0.08859 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07126 $ 0.08126 $ 0.08626 $ All other hours WINTER MID-PEAK 0.09667 $ 0.10667 $ 0.11167 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06022 $ 0.07022 $ 0.07522 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 10.64 $ 10.64 $ 10.64 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 3.56 $ 3.56 $ 3.56 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-GS-3-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.20911 $ 0.21911 $ 0.22411 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.10786 $ 0.11786 $ 0.12286 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07126 $ 0.08126 $ 0.08626 $ All other hours WINTER MID-PEAK 0.09667 $ 0.10667 $ 0.11167 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06022 $ 0.07022 $ 0.07522 $ All other hours

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00176) (0.00176) $ (0.00176) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00397) (0.00397) $ (0.00397) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00402) (0.00402) $ (0.00402) $ All electric usage Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
TOU-8-SEC-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10145 $ 0.11145 $ 0.11645 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09331 $ 0.10331 $ 0.10831 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06615 $ 0.07615 $ 0.08115 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07495 $ 0.08495 $ 0.08995 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07536 $ 0.08536 $ 0.09036 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04388 $ 0.05388 $ 0.05888 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 16.74 $ 16.74 $ 16.74 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.13 $ 5.13 $ 5.13 $ 4pm - 9pm, Monday - Friday TOU-8-PRI-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09617 $ 0.10617 $ 0.11117 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08865 $ 0.09865 $ 0.10365 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06283 $ 0.07283 $ 0.07783 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07127 $ 0.08127 $ 0.08627 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07178 $ 0.08178 $ 0.08678 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04190 $ 0.05190 $ 0.05690 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 15.90 $ 15.90 $ 15.90 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.95 $ 5.95 $ 5.95 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09028 $ 0.10028 $ 0.10528 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08344 $ 0.09344 $ 0.09844 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.05886 $ 0.06886 $ 0.07386 $ 9pm - 4pm, every day WINTER MID-PEAK 0.06680 $ 0.07680 $ 0.08180 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.06750 $ 0.07750 $ 0.08250 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.03940 $ 0.04940 $ 0.05440 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00053) (0.00053) $ (0.00053) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 17.56 $ 17.56 $ 17.56 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.67 $ 5.67 $ 5.67 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.17) (0.17) $ (0.17) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.05) (0.05) $ (0.05) $ 4pm - 9pm, Monday - Friday
TOU-8-SEC-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.27412 $ 0.28412 $ 0.28912 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09331 $ 0.10331 $ 0.10831 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06615 $ 0.07615 $ 0.08115 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10849 $ 0.11849 $ 0.12349 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07536 $ 0.08536 $ 0.09036 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04388 $ 0.05388 $ 0.05888 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 4.64 $ 4.64 $ 4.64 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.10 $ 2.10 $ 2.10 $ 4pm - 9pm, Monday - Friday TOU-8-PRI-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.25669 $ 0.26669 $ 0.27169 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08865 $ 0.09865 $ 0.10365 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06283 $ 0.07283 $ 0.07783 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12285 $ 0.13285 $ 0.13785 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07178 $ 0.08178 $ 0.08678 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04190 $ 0.05190 $ 0.05690 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 3.90 $ 3.90 $ 3.90 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 0.68 $ 0.68 $ 0.68 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.28096 $ 0.29096 $ 0.29596 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08344 $ 0.09344 $ 0.09844 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.05886 $ 0.06886 $ 0.07386 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10838 $ 0.11838 $ 0.12338 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.06750 $ 0.07750 $ 0.08250 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.03940 $ 0.04940 $ 0.05440 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00066) (0.00066) $ (0.00066) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 1.66 $ 1.66 $ 1.66 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 0.81 $ 0.81 $ 0.81 $ 4pm - 9pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.02) (0.02) $ (0.02) $ 4pm - 9pm, Monday - Friday

WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.01) (0.01) $ (0.01) $ 4pm - 9pm, Monday - Friday
Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
TOU-8-SEC-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.07793 $ 0.08793 $ 0.09293 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07315 $ 0.08315 $ 0.08815 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07105 $ 0.08105 $ 0.08605 $ All other hours WINTER MID-PEAK 0.09314 $ 0.10314 $ 0.10814 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06093 $ 0.07093 $ 0.07593 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 11.52 $ 11.52 $ 11.52 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 3.79 $ 3.79 $ 3.79 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-8-PRI-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.07416 $ 0.08416 $ 0.08916 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.06935 $ 0.07935 $ 0.08435 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06763 $ 0.07763 $ 0.08263 $ All other hours WINTER MID-PEAK 0.09508 $ 0.10508 $ 0.11008 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.05919 $ 0.06919 $ 0.07419 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 11.19 $ 11.19 $ 11.19 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 3.59 $ 3.59 $ 3.59 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-8-SUB-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.06951 $ 0.07951 $ 0.08451 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.06482 $ 0.07482 $ 0.07982 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06341 $ 0.07341 $ 0.07841 $ All other hours WINTER MID-PEAK 0.08796 $ 0.09796 $ 0.10296 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.05609 $ 0.06609 $ 0.07109 $ All other hours

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00053) (0.00053) $ (0.00053) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.79 $ 12.79 $ 12.79 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.14 $ 4.14 $ 4.14 $ 8am - 12pm & 6pm - 11pm, Monday - Friday

SUMMER ON-PEAK AND MID-PEAK
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.25) (0.25) $ (0.25) $ 8am - 11pm, Monday - Friday
TOU-8-SEC-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.21030 $ 0.22030 $ 0.22530 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.10537 $ 0.11537 $ 0.12037 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07105 $ 0.08105 $ 0.08605 $ All other hours WINTER MID-PEAK 0.09314 $ 0.10314 $ 0.10814 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06093 $ 0.07093 $ 0.07593 $ All other hours TOU-8-PRI-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.20075 $ 0.21075 $ 0.21575 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.09802 $ 0.10802 $ 0.11302 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06763 $ 0.07763 $ 0.08263 $ All other hours WINTER MID-PEAK 0.09508 $ 0.10508 $ 0.11008 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.05919 $ 0.06919 $ 0.07419 $ All other hours TOU-8-SUB-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.19883 $ 0.20883 $ 0.21383 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.09324 $ 0.10324 $ 0.10824 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06341 $ 0.07341 $ 0.07841 $ All other hours WINTER MID-PEAK 0.08796 $ 0.09796 $ 0.10296 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.05609 $ 0.06609 $ 0.07109 $ All other hours

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00083) (0.00083) $ (0.00083) $ All electric usage TOU-8-SEC-RBU Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10145 $ 0.11145 $ 0.11645 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09331 $ 0.10331 $ 0.10831 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06615 $ 0.07615 $ 0.08115 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07495 $ 0.08495 $ 0.08995 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07536 $ 0.08536 $ 0.09036 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04388 $ 0.05388 $ 0.05888 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 16.74 $ 16.74 $ 16.74 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.13 $ 5.13 $ 5.13 $ 4pm - 9pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

COMMERCIAL CUSTOMERS
TOU-8-PRI-RBU Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09617 $ 0.10617 $ 0.11117 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08865 $ 0.09865 $ 0.10365 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06283 $ 0.07283 $ 0.07783 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07127 $ 0.08127 $ 0.08627 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07178 $ 0.08178 $ 0.08678 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04190 $ 0.05190 $ 0.05690 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 15.90 $ 15.90 $ 15.90 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.95 $ 5.95 $ 5.95 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-RBU Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09028 $ 0.10028 $ 0.10528 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08344 $ 0.09344 $ 0.09844 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.05886 $ 0.06886 $ 0.07386 $ 9pm - 4pm, every day WINTER MID-PEAK 0.06680 $ 0.07680 $ 0.08180 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.06750 $ 0.07750 $ 0.08250 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.03940 $ 0.04940 $ 0.05440 $ 8am - 4pm, every day

SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.17) (0.17) $ (0.17) $ 4pm - 9pm, Monday - Friday

WINTER WEEKDAYS VOLTAGE
DISCOUNT - DEMAND 220kV ($/kW) $ (0.05) (0.05) $ (0.05) $ 4pm - 9pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
TOU-EV-7 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.29881 $ 0.30881 $ 0.31381 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11200 $ 0.12200 $ 0.12700 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.09367 $ 0.10367 $ 0.10867 $ 9pm - 4pm, every day WINTER MID-PEAK 0.16522 $ 0.17522 $ 0.18022 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.10857 $ 0.11857 $ 0.12357 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.05468 $ 0.06468 $ 0.06968 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00117) (0.00117) $ (0.00117) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00254) (0.00254) $ (0.00254) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00258) (0.00258) $ (0.00258) $ All electric usage TOU-EV-8 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.32984 $ 0.33984 $ 0.34484 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10054 $ 0.11054 $ 0.11554 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07996 $ 0.08996 $ 0.09496 $ 9pm - 4pm, every day WINTER MID-PEAK 0.14065 $ 0.15065 $ 0.15565 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09229 $ 0.10229 $ 0.10729 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04518 $ 0.05518 $ 0.06018 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00208) (0.00208) $ (0.00208) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00470) (0.00470) $ (0.00470) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00475) (0.00475) $ (0.00475) $ All electric usage TOU-EV-9-SEC Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.25755 $ 0.26755 $ 0.27255 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09331 $ 0.10331 $ 0.10831 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07450 $ 0.08450 $ 0.08950 $ 9pm - 4pm, every day WINTER MID-PEAK 0.13167 $ 0.14167 $ 0.14667 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08417 $ 0.09417 $ 0.09917 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04388 $ 0.05388 $ 0.05888 $ 8am - 4pm, every day TOU-EV-9-PRI Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.23389 $ 0.24389 $ 0.24889 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08865 $ 0.09865 $ 0.10365 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06995 $ 0.07995 $ 0.08495 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12948 $ 0.13948 $ 0.14448 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07875 $ 0.08875 $ 0.09375 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04190 $ 0.05190 $ 0.05690 $ 8am - 4pm, every day TOU-EV-9-SUB Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.22778 $ 0.23778 $ 0.24278 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08344 $ 0.09344 $ 0.09844 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06531 $ 0.07531 $ 0.08031 $ 9pm - 4pm, every day WINTER MID-PEAK 0.11529 $ 0.12529 $ 0.13029 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07318 $ 0.08318 $ 0.08818 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.03940 $ 0.04940 $ 0.05440 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00083) (0.00083) $ (0.00083) $ All electric usage

BUSINESS ELECTRIC VEHICLE CUSTOMERS
Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
TOU-PA-2-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10982 $ 0.11982 $ 0.12482 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10096 $ 0.11096 $ 0.11596 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07000 $ 0.08000 $ 0.08500 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08804 $ 0.09804 $ 0.10304 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07198 $ 0.08198 $ 0.08698 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.06286 $ 0.07286 $ 0.07786 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00084) (0.00084) $ (0.00084) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00186) (0.00186) $ (0.00186) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00186) (0.00186) $ (0.00186) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 10.17 $ 10.17 $ 10.17 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.30 $ 2.30 $ 2.30 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.15) (0.15) $ (0.15) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.31) (0.31) $ (0.31) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.31) (0.31) $ (0.31) $ 4pm - 9pm, Monday - Friday
WINTER WIND MACHINE CREDIT ($/kW) (9.76) $ (9.76) $ (9.76) $ All electric usage TOU-PA-2-D5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.20939 $ 0.21939 $ 0.22439 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.19804 $ 0.20804 $ 0.21304 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06620 $ 0.07620 $ 0.08120 $ 8pm - 5pm, every day WINTER MID-PEAK 0.08988 $ 0.09988 $ 0.10488 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.07346 $ 0.08346 $ 0.08846 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.06410 $ 0.07410 $ 0.07910 $ 8am - 5pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00087) (0.00087) $ (0.00087) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00191) (0.00191) $ (0.00191) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00192) (0.00192) $ (0.00192) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 9.74 $ 9.74 $ 9.74 $ 5pm - 8pm, Monday - Friday WINTER MID-PEAK 2.14 $ 2.14 $ 2.14 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.13) (0.13) $ (0.13) $ 5pm - 8pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.29) (0.29) $ (0.29) $ 5pm - 8pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.29) (0.29) $ (0.29) $ 5pm - 8pm, Monday - Friday
WINTER WIND MACHINE CREDIT ($/kW) (9.76) $ (9.76) $ (9.76) $ All electric usage

AGRICULTURE CUSTOMERS
Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

AGRICULTURE CUSTOMERS
TOU-PA-2-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.34732 $ 0.35732 $ 0.36232 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10096 $ 0.11096 $ 0.11596 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07000 $ 0.08000 $ 0.08500 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10044 $ 0.11044 $ 0.11544 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08185 $ 0.09185 $ 0.09685 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.07127 $ 0.08127 $ 0.08627 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00139) (0.00139) $ (0.00139) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00302) (0.00302) $ (0.00302) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00139) (0.00139) $ (0.00139) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00302) (0.00302) $ (0.00302) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00303) (0.00303) $ (0.00303) $ All electric usage DEMAND CHARGE ($/KW) YEAR ROUND WIND MACHINE CREDIT
($/kW) $ (9.76) (9.76) $ (9.76) $ All electric usage
TOU-PA-2-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.22244 $ 0.23244 $ 0.23744 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.10676 $ 0.11676 $ 0.12176 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07538 $ 0.08538 $ 0.09038 $ All other hours WINTER MID-PEAK 0.09961 $ 0.10961 $ 0.11461 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06904 $ 0.07904 $ 0.08404 $ All other hours DEMAND CHARGE ($/KW) YEAR ROUND WIND MACHINE CREDIT
($/kW) $ (9.76) (9.76) $ (9.76) $ All electric usage
TOU-PA-2-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08271 $ 0.09271 $ 0.09771 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07715 $ 0.08715 $ 0.09215 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07538 $ 0.08538 $ 0.09038 $ All other hours WINTER MID-PEAK 0.09961 $ 0.10961 $ 0.11461 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06904 $ 0.07904 $ 0.08404 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 7.21 $ 7.21 $ 7.21 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 2.21 $ 2.21 $ 2.21 $ 8am - 12pm & 6pm - 11pm, Monday - Friday WINTER WIND MACHINE CREDIT ($/kW) (9.76) $ (9.76) $ (9.76) $ All electric usage Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

AGRICULTURE CUSTOMERS
TOU-PA-3-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09653 $ 0.10653 $ 0.11153 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08888 $ 0.09888 $ 0.10388 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06203 $ 0.07203 $ 0.07703 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07678 $ 0.08678 $ 0.09178 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07721 $ 0.08721 $ 0.09221 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04502 $ 0.05502 $ 0.06002 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00082) (0.00082) $ (0.00082) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00182) (0.00182) $ (0.00182) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00185) (0.00185) $ (0.00185) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 10.85 $ 10.85 $ 10.85 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.34 $ 2.34 $ 2.34 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.16) (0.16) $ (0.16) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.38) (0.38) $ (0.38) $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.38) (0.38) $ (0.38) $ 4pm - 9pm, Monday - Friday
TOU-PA-3-D5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.17932 $ 0.18932 $ 0.19432 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.16968 $ 0.17968 $ 0.18468 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.05891 $ 0.06891 $ 0.07391 $ 8pm - 5pm, every day WINTER MID-PEAK 0.07617 $ 0.08617 $ 0.09117 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.07660 $ 0.08660 $ 0.09160 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.04463 $ 0.05463 $ 0.05963 $ 8am - 5pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00083) (0.00083) $ (0.00083) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00182) (0.00182) $ (0.00182) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00185) (0.00185) $ (0.00185) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 10.40 $ 10.40 $ 10.40 $ 5pm - 8pm, Monday - Friday WINTER MID-PEAK 2.86 $ 2.86 $ 2.86 $ 4pm - 9pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.17) (0.17) $ (0.17) $ 5pm - 8pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.39) (0.39) $ (0.39) $ 5pm - 8pm, Monday - Friday

SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.38) (0.38) $ (0.38) $ 5pm - 8pm, Monday - Friday
TOU-PA-3-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.29845 $ 0.30845 $ 0.31345 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.08888 $ 0.09888 $ 0.10388 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06203 $ 0.07203 $ 0.07703 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10563 $ 0.11563 $ 0.12063 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08605 $ 0.09605 $ 0.10105 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.03725 $ 0.04725 $ 0.05225 $ 8am - 4pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00127) (0.00127) $ (0.00127) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00289) (0.00289) $ (0.00289) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00292) (0.00292) $ (0.00292) $ All electric usage Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions

AGRICULTURE CUSTOMERS
TOU-PA-3-E5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.48359 $ 0.49359 $ 0.49859 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.16968 $ 0.17968 $ 0.18468 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.05891 $ 0.06891 $ 0.07391 $ 8pm - 5pm, every day WINTER MID-PEAK 0.11007 $ 0.12007 $ 0.12507 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.08959 $ 0.09959 $ 0.10459 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.03854 $ 0.04854 $ 0.05354 $ 8am - 5pm, every day

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00128) (0.00128) $ (0.00128) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00290) (0.00290) $ (0.00290) $ All electric usage

YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00292) (0.00292) $ (0.00292) $ All electric usage TOU-PA-3-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.19450 $ 0.20450 $ 0.20950 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.09285 $ 0.10285 $ 0.10785 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06663 $ 0.07663 $ 0.08163 $ All other hours WINTER MID-PEAK 0.08698 $ 0.09698 $ 0.10198 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06344 $ 0.07344 $ 0.07844 $ All other hours TOU-PA-3-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.07300 $ 0.08300 $ 0.08800 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.06809 $ 0.07809 $ 0.08309 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.06663 $ 0.07663 $ 0.08163 $ All other hours WINTER MID-PEAK 0.08698 $ 0.09698 $ 0.10198 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06344 $ 0.07344 $ 0.07844 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 7.64 $ 7.64 $ 7.64 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 2.24 $ 2.24 $ 2.24 $ 8am - 12pm & 6pm - 11pm, Monday - Friday Effective: Mar 24, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
Streetlighting
(LS-1, LS-2, DWL, and OL-1)
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.06846 $ 0.07846 $ 0.08346 $ All electric usage LS-3
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.06854 $ 0.07854 $ 0.08354 $ All electric usage AL-2-F
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.06854 $ 0.07854 $ 0.08354 $ All electric usage AL-2-GF Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.14775 $ 0.15775 $ 0.16275 $ 8am - 4pm, every day SUMMER OFF-PEAK 0.06854 $ 0.07854 $ 0.08354 $ All other hours WINTER ON-PEAK 0.10115 $ 0.11115 $ 0.11615 $ 8am - 4pm, every day WINTER OFF-PEAK 0.06854 $ 0.07854 $ 0.08354 $ All other hours TC-1
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.09268 $ 0.10268 $ 0.10768 $ All electric usage WTR
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.10647 $ 0.11647 $ 0.12147 $ All electric usage *Applicable holidays for rate time periods are as follows: New Year's Day, Presidents’ Day, Memorial Day, Independence Day, Labor Day, Veterans Day, Thanksgiving Day, and Christmas Day. When any holiday listed above falls on Sunday, the following Monday will be recognized as a holiday. No change will be made for holidays falling on Saturday.

STREETLIGHT CUSTOMERS
Effective: Mar 24, 2025
Wildfire Fund Non-Bypassable Charge
Competition Transition Charge
Rate Group WFC (All Vintages) CTC (All Vintages) GMS Factor (All Vintages) Domestic1 $ (0.00058) 0.00595 $ 0.009261
GS-12 $ (0.00041) 0.00595 $ 0.009261
TC-13 $ (0.00044) 0.00595 $ 0.009261
GS-24 $ (0.00043) 0.00595 $ 0.009261
TOU-GS-35 $ (0.00042) 0.00595 $ 0.009261
TOU-8-Sec6 $ (0.00041) 0.00595 $ 0.009261
TOU-8-Pri6 $ (0.00040) 0.00595 $ 0.009261
TOU-8-Sub6 $ (0.00038) 0.00595 $ 0.009261
Small AG7 $ (0.00042) 0.00595 $ 0.009261
Large AG8 $ (0.00042) 0.00595 $ 0.009261
St. Lighting
9 $ (0.00053) 0.00595 $ 0.009261
2 Includes Schedules GS-1, TOU-GS-1, TOU-GS-1-RTP, AL-2 (On-Peak), LS-3 Option B (On- Peak), and TOU-EV-7. 3 Includes Schedules TC-1, Wi-Fi-1, and WTR.
4 Includes Schedules GS-2, TOU-EV-8, TOU-GS-2, and TOU-GS-2-RTP. 5 Includes Schedules TOU-GS-3 and TOU-GS-3-RTP.
6 Includes Schedules TOU-EV-9, TOU-8, TOU-8-RBU, and TOU-8-RTP. 7 Includes Schedules PA-1, PA-2, TOU-PA-2, and TOU-PA-2-RTP. 8 Includes Schedules TOU-PA-3 and TOU-PA-3-RTP.
9 Includes Schedules AL-2-(Off-Peak), DWL, LS-1, LS-2, LS-3, LS-3 Option B (Off-Peak), and OL-1.

The ongoing Competition Transition Charge (CTC) recovers the CPUC-approved market price limit for legacy electricity contracts (signed prior to 1998), as well as statutorily authorized costs that are related to restructuring of California’s electric industry prior to the energy crisis. These charges are assessed to all customers, including SCE-only customers, but are collected separately for CCA customers and go directly to SCE.

The Wildfire Fund Non-Bypassable Charge (WFC) supports the California Wildfire Fund. This charge is assessed to all customers, including SCE-only customers, but is collected separately for CCA customers. The funds go to the State of California for potential disbursement to IOUs, such as SCE, if a catastrophic event occurs. Customers on CARE and Medical Baseline Programs are currently exempt from these charges.

OCPA Rates in SCE Territory
Surcharge
The Generation Municipal Surcharge (GMS) Factor recovers franchise fees paid by SCE to operate within certain municipal jurisdictions within California. This charge is assessed to all customers, including SCE-only customers, but is collected separately for CCA customers. The charge equals the product of the GMS factor and the SCE rates or charges that have been removed from the bill of a customer receiving CCA service. An exemption applies to CA political subdivision and certain cogeneration or nonutility generation facilities. It is the responsibility of the customer to self-identify for exemption.

Effective: Mar 24, 2025
Power Charge Indifference Adjustment
Rate Group PCIA Vintage
Domestic1 $ 2022 (0.01613)
GS-12 $ 2021 (0.00906)
TC-13 $ 2021 (0.00962)
GS-24 $ 2021 (0.00949)
TOU-GS-35 $ 2021 (0.00922)
TOU-8-Sec6 $ 2021 (0.00899)
TOU-8-Pri6 $ 2021 (0.00879)
TOU-8-Sub6 $ 2021 (0.00831)
Small AG7 $ 2021 (0.00930)
Large AG8 $ 2021 (0.00919)
St. Lighting9 $ 2021 (0.01160)
The Power Charge Indifference Adjustment (PCIA) is a fee collected by SCE and assessed to customers who receive their electric generation services from another provider. The PCIA is considered an "exit fee" assessed by SCE to cover costs for departing customers; resources acquired prior to a customer's change in service providers, and to ensure their current customers are “indifferent” to costs associated with the departed customers. SCE assigns customers a "PCIA Vintage" based on the date a customer’s respective community enrolled in alternative service; this date is reset upon reenrollment if a customer opts-out and later re-enrolls in OCPA service. The PCIA is charged on a per kWh basis based on net monthly usage, and is unaffected by time of use.

OCPA Rates in SCE Territory
OCPA Rate RIN - Basic Choice RIN - Smart Choice RIN - 100% Renewable TOU-GS-1-SEC-D USCA-XXOC-0038-0000 USCA-XXOC-0167-0000 USCA-XXOC-0166-0000 TOU-GS-1-PRI-D USCA-XXOC-0035-0000 USCA-XXOC-0161-0000 USCA-XXOC-0160-0000 TOU-GS-1-SUB-D USCA-XXOC-0041-0000 USCA-XXOC-0173-0000 USCA-XXOC-0172-0000 TOU-GS-1-SEC-E USCA-XXOC-0039-0000 USCA-XXOC-0169-0000 USCA-XXOC-0168-0000 TOU-GS-1-PRI-E USCA-XXOC-0036-0000 USCA-XXOC-0163-0000 USCA-XXOC-0162-0000 TOU-GS-1-SUB-E USCA-XXOC-0042-0000 USCA-XXOC-0175-0000 USCA-XXOC-0174-0000 TOU-GS-1-SEC-ES USCA-XXOC-0040-0000 USCA-XXOC-0171-0000 USCA-XXOC-0170-0000 TOU-GS-1-PRI-ES USCA-XXOC-0037-0000 USCA-XXOC-0165-0000 USCA-XXOC-0164-0000 TOU-GS-1-SUB-ES USCA-XXOC-0043-0000 USCA-XXOC-0177-0000 USCA-XXOC-0176-0000 TOU-GS-1-A USCA-XXOC-0033-0000 USCA-XXOC-0157-0000 USCA-XXOC-0156-0000 TOU-GS-1-B USCA-XXOC-0034-0000 USCA-XXOC-0159-0000 USCA-XXOC-0158-0000 TOU-GS-2-SEC-D USCA-XXOC-0048-0000 USCA-XXOC-0187-0000 USCA-XXOC-0186-0000 TOU-GS-2-PRI-D USCA-XXOC-0045-0000 USCA-XXOC-0181-0000 USCA-XXOC-0180-0000 TOU-GS-2-SUB-D USCA-XXOC-0051-0000 USCA-XXOC-0193-0000 USCA-XXOC-0192-0000 TOU-GS-2-SEC-E USCA-XXOC-0049-0000 USCA-XXOC-0189-0000 USCA-XXOC-0188-0000 TOU-GS-2-PRI-E USCA-XXOC-0046-0000 USCA-XXOC-0183-0000 USCA-XXOC-0182-0000 TOU-GS-2-SUB-E USCA-XXOC-0052-0000 USCA-XXOC-0195-0000 USCA-XXOC-0194-0000 TOU-GS-2-B USCA-XXOC-0044-0000 USCA-XXOC-0179-0000 USCA-XXOC-0178-0000 TOU-GS-2-SEC-R USCA-XXOC-0050-0000 USCA-XXOC-0191-0000 USCA-XXOC-0190-0000 TOU-GS-2-PRI-R USCA-XXOC-0047-0000 USCA-XXOC-0185-0000 USCA-XXOC-0184-0000 TOU-GS-2-SUB-R USCA-XXOC-0053-0000 USCA-XXOC-0197-0000 USCA-XXOC-0196-0000 TOU-GS-3-SEC-D USCA-XXOC-0058-0000 USCA-XXOC-0207-0000 USCA-XXOC-0206-0000 TOU-GS-3-PRI-D USCA-XXOC-0055-0000 USCA-XXOC-0201-0000 USCA-XXOC-0200-0000 TOU-GS-3-SUB-D USCA-XXOC-0061-0000 USCA-XXOC-0213-0000 USCA-XXOC-0212-0000 TOU-GS-3-SEC-E USCA-XXOC-0059-0000 USCA-XXOC-0209-0000 USCA-XXOC-0208-0000 TOU-GS-3-PRI-E USCA-XXOC-0056-0000 USCA-XXOC-0203-0000 USCA-XXOC-0202-0000 TOU-GS-3-SUB-E USCA-XXOC-0062-0000 USCA-XXOC-0215-0000 USCA-XXOC-0214-0000 TOU-GS-3-B USCA-XXOC-0054-0000 USCA-XXOC-0199-0000 USCA-XXOC-0198-0000 TOU-GS-3-SEC-R USCA-XXOC-0060-0000 USCA-XXOC-0211-0000 USCA-XXOC-0210-0000 TOU-GS-3-PRI-R USCA-XXOC-0057-0000 USCA-XXOC-0205-0000 USCA-XXOC-0204-0000 TOU-GS-3-SUB-R USCA-XXOC-0063-0000 USCA-XXOC-0217-0000 USCA-XXOC-0216-0000 TOU-8-SEC-D USCA-XXOC-0008-0000 USCA-XXOC-0107-0000 USCA-XXOC-0106-0000 TOU-8-PRI-D USCA-XXOC-0003-0000 USCA-XXOC-0097-0000 USCA-XXOC-0096-0000 TOU-8-SUB-D USCA-XXOC-0013-0000 USCA-XXOC-0117-0000 USCA-XXOC-0116-0000 TOU-8-SEC-E USCA-XXOC-0009-0000 USCA-XXOC-0109-0000 USCA-XXOC-0108-0000 TOU-8-PRI-E USCA-XXOC-0004-0000 USCA-XXOC-0099-0000 USCA-XXOC-0098-0000 TOU-8-SUB-E USCA-XXOC-0014-0000 USCA-XXOC-0119-0000 USCA-XXOC-0118-0000 TOU-8-SEC-B USCA-XXOC-0007-0000 USCA-XXOC-0105-0000 USCA-XXOC-0104-0000 Orange County Power Authority Rate Identification Number (RIN) Key The tables below show the corresponding Rate Identification Number (RIN) to Orange County Power Authority (OCPA) rate.

Commercial Customers
TOU-8-PRI-B USCA-XXOC-0002-0000 USCA-XXOC-0095-0000 USCA-XXOC-0094-0000 TOU-8-SUB-B USCA-XXOC-0012-0000 USCA-XXOC-0115-0000 USCA-XXOC-0114-0000 TOU-8-SEC-R USCA-XXOC-0010-0000 USCA-XXOC-0111-0000 USCA-XXOC-0110-0000 TOU-8-PRI-R USCA-XXOC-0005-0000 USCA-XXOC-0101-0000 USCA-XXOC-0100-0000 TOU-8-SUB-R USCA-XXOC-0015-0000 USCA-XXOC-0121-0000 USCA-XXOC-0120-0000 TOU-8-SEC-RBU USCA-XXOC-0011-0000 USCA-XXOC-0113-0000 USCA-XXOC-0112-0000 TOU-8-PRI-RBU USCA-XXOC-0006-0000 USCA-XXOC-0103-0000 USCA-XXOC-0102-0000 TOU-8-SUB-RBU USCA-XXOC-0016-0000 USCA-XXOC-0123-0000 USCA-XXOC-0122-0000 TOU-EV-7-SEC USCA-XXOC-0025-0000 USCA-XXOC-0141-0000 USCA-XXOC-0140-0000 TOU-EV-7-PRI USCA-XXOC-0024-0000 USCA-XXOC-0139-0000 USCA-XXOC-0138-0000 TOU-EV-7-SUB USCA-XXOC-0026-0000 USCA-XXOC-0143-0000 USCA-XXOC-0142-0000 TOU-EV-8-SEC USCA-XXOC-0028-0000 USCA-XXOC-0147-0000 USCA-XXOC-0146-0000 TOU-EV-8-PRI USCA-XXOC-0027-0000 USCA-XXOC-0145-0000 USCA-XXOC-0144-0000 TOU-EV-8-SUB USCA-XXOC-0029-0000 USCA-XXOC-0149-0000 USCA-XXOC-0148-0000 TOU-EV-9-SEC USCA-XXOC-0031-0000 USCA-XXOC-0153-0000 USCA-XXOC-0152-0000 TOU-EV-9-PRI USCA-XXOC-0030-0000 USCA-XXOC-0151-0000 USCA-XXOC-0150-0000 TOU-EV-9-SUB USCA-XXOC-0032-0000 USCA-XXOC-0155-0000 USCA-XXOC-0154-0000 TOU-PA-2-SEC-D USCA-XXOC-0070-0000 USCA-XXOC-0231-0000 USCA-XXOC-0230-0000 TOU-PA-2-PRI-D USCA-XXOC-0066-0000 USCA-XXOC-0223-0000 USCA-XXOC-0222-0000 TOU-PA-2-SUB-D USCA-XXOC-0074-0000 USCA-XXOC-0239-0000 USCA-XXOC-0238-0000 TOU-PA-2-SEC-D5 USCA-XXOC-0071-0000 USCA-XXOC-0233-0000 USCA-XXOC-0232-0000 TOU-PA-2-PRI-D5 USCA-XXOC-0067-0000 USCA-XXOC-0225-0000 USCA-XXOC-0224-0000 TOU-PA-2-SUB-D5 USCA-XXOC-0075-0000 USCA-XXOC-0241-0000 USCA-XXOC-0240-0000 TOU-PA-2-SEC-E USCA-XXOC-0072-0000 USCA-XXOC-0235-0000 USCA-XXOC-0234-0000 TOU-PA-2-PRI-E USCA-XXOC-0068-0000 USCA-XXOC-0227-0000 USCA-XXOC-0226-0000 TOU-PA-2-SUB-E USCA-XXOC-0076-0000 USCA-XXOC-0243-0000 USCA-XXOC-0242-0000 TOU-PA-2-SEC-E5 USCA-XXOC-0073-0000 USCA-XXOC-0237-0000 USCA-XXOC-0236-0000 TOU-PA-2-PRI-E5 USCA-XXOC-0069-0000 USCA-XXOC-0229-0000 USCA-XXOC-0228-0000 TOU-PA-2-SUB-E5 USCA-XXOC-0077-0000 USCA-XXOC-0245-0000 USCA-XXOC-0244-0000 TOU-PA-2-A USCA-XXOC-0064-0000 USCA-XXOC-0219-0000 USCA-XXOC-0218-0000 TOU-PA-2-B USCA-XXOC-0065-0000 USCA-XXOC-0221-0000 USCA-XXOC-0220-0000 TOU-PA-3-SEC-D USCA-XXOC-0084-0000 USCA-XXOC-0259-0000 USCA-XXOC-0258-0000 TOU-PA-3-PRI-D USCA-XXOC-0080-0000 USCA-XXOC-0251-0000 USCA-XXOC-0250-0000 TOU-PA-3-SUB-D USCA-XXOC-0088-0000 USCA-XXOC-0267-0000 USCA-XXOC-0266-0000 TOU-PA-3-SEC-D5 USCA-XXOC-0085-0000 USCA-XXOC-0261-0000 USCA-XXOC-0260-0000 TOU-PA-3-PRI-D5 USCA-XXOC-0081-0000 USCA-XXOC-0253-0000 USCA-XXOC-0252-0000 TOU-PA-3-SUB-D5 USCA-XXOC-0089-0000 USCA-XXOC-0269-0000 USCA-XXOC-0268-0000 TOU-PA-3-SEC-E USCA-XXOC-0086-0000 USCA-XXOC-0263-0000 USCA-XXOC-0262-0000 TOU-PA-3-PRI-E USCA-XXOC-0082-0000 USCA-XXOC-0255-0000 USCA-XXOC-0254-0000 TOU-PA-3-SUB-E USCA-XXOC-0090-0000 USCA-XXOC-0271-0000 USCA-XXOC-0270-0000 TOU-PA-3-SEC-E5 USCA-XXOC-0087-0000 USCA-XXOC-0265-0000 USCA-XXOC-0264-0000 TOU-PA-3-PRI-E5 USCA-XXOC-0083-0000 USCA-XXOC-0257-0000 USCA-XXOC-0256-0000 TOU-PA-3-SUB-E5 USCA-XXOC-0091-0000 USCA-XXOC-0273-0000 USCA-XXOC-0272-0000 TOU-PA-3-A USCA-XXOC-0078-0000 USCA-XXOC-0247-0000 USCA-XXOC-0246-0000 TOU-PA-3-B USCA-XXOC-0079-0000 USCA-XXOC-0249-0000 USCA-XXOC-0248-0000 AL-2-GF USCA-XXOC-0001-0000 USCA-XXOC-0093-0000 USCA-XXOC-0092-0000

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.1
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Jacquie Henderson, Director of Communications & External Affairs Saul Viramontes, Management Analyst
Approved by: Joe Mosca, Chief Executive Officer
Subject: COMMUNITY POWER PLAN AND OTHER OUTREACH SERVICES RFQ

ANALYSIS AND RECOMMENDATION
Date: April 14, 2025
--------------------------------------------------------------------------------------------------------------------

RECOMMENDED ACTIONS

1. Receive panel recommendations for Request for Qualifications for Community Power Plan Outreach & Other Services solicitation.

2. Direct staff to negotiate and establish an agreement for Community Power Plan Outreach Services with the Asian Business Association of Orange County.

BACKGROUND
Orange County Power Authority (OCPA) Staff issued a Request for Qualifications (RFQ) for Community Power Plan Support Services and Other Outreach Services on January 13, 2025. This invitation to submit proposals was extensively distributed to 1,437 potential bidders on BidNet Direct, in addition to OCPA’s solicitation marketing efforts, ensuring broad reach and fairness.

The RFQ was publicly available on the OCPA website, promoting transparency and equal opportunity for all interested parties. OCPA posted our responses to ten (10) inquiries from potential vendors, demonstrating our commitment to clear communication. By the RFQ's closing date, 58 potential vendors had downloaded the solicitation document. By February 27, 2025, OCPA received six (6) qualified proposals in response to the RFQ.

The six (6) proposals were submitted to the evaluation panel, which consisted of one (1) internal OCPA staff; one (1) external staff member from OCPA’s contracted partner for the development of the Community Power Plan, The Energy Coalition; and one (1) external staff member from another CCA. The panel qualifications were as follows:

Evaluator 1 – OCPA staff member responsible for energy program implementation Evaluator 2 – External contractor with a deep understanding of OCPA communities and the outreach services needed to support OCPA’s Community Power Plan Evaluator 3 – External CCA staff member serving in a customer programs equity and distribution role

ANALYSIS
The RFQ solicited six (6) potential areas of support. Potential bidders were asked to submit general organizational information and category-specific information for evaluation by the panel.

The evaluation criteria below were utilized when scoring proposals, including additional scoring for each service being proposed. Services solicited through this RFQ included:

1. Community Needs Assessment: Engage with communities via pop-up events, surveys, workshops, social media, and other outreach methods to conduct needs assessments that identify community priorities and barriers to participation.

2. Listening Sessions and Informational Meetings: Co-host an OCPA-focused listening session, series of listening sessions, or informational meetings that are not tied to existing meetings.

3. Utilizing Existing Meetings or Events: Use existing meetings and/or events to host OCPA-focused input-gathering sessions such as focus groups.

4. Program Promotion and Marketing: Promote and market a specific program/project (e.g., expand outreach to increase participation).

5. Program Implementation Support: Serve as an implementer for a specific program/project (e.g., process applications, run the program/project, reporting).

6. Other: Proposers were allowed to submit their own outreach proposals.

Evaluation Criteria Weight
Minimum Qualifications Pass/Fail
• Completeness of application.
• The organization is independent and properly licensed to practice and authorized to do business in the State of California.
• The organization has no conflict of interest regarding any other work performed by the firm for OCPA.
20%
• Clarity and conformance to RFQ
• Community impact & populations served 45%
• Organizational background, experience, capacity, and references. 35% Total 100%
Based on the evaluation panel's recommendation, the following qualified proposers have been recommended for potential awards in each category:

Community Needs
Assessment
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 4.10 4.00 3.75 3.95
Climate Action Campaign 3.60 4.00 3.95 3.85
OC Goes Solar 3.95 3.80 3.60 3.78
Tripepi Smith & Associates 3.25 3.10 3.95 3.43
Listening Sessions
and Informational
Meetings
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 4.35 3.65 4.45 4.15
Climate Action Campaign 3.60 4.35 4.30 4.08
Tripepi Smith & Associates 2.90 3.80 4.30 3.67
Utilizing Existing
Meetings or
Events
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 3.90 3.55 4.00 3.82
Climate Action Campaign 3.05 3.30 3.95 3.43
Tripepi Smith & Associates 2.20 2.75 4.65 3.20
Program Promotion
and Marketing
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 3.20 4.00 4.00 3.73
Climate Action Campaign 2.50 4.00 3.95 3.48
OC Goes Solar 4.30 3.25 4.65 4.07
Orange County United Way 4.30 3.60 4.30 4.07
Program
Implementation
Support
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 2.05 2.40 2.85 2.43
Clean Peaks Energy Services 1.80 1.90 2.70 2.13
Other
Recommended Proposers
Evaluation
Points
(Evaluator 1)
Evaluation
Points
(Evaluator 2)
Evaluation
Points
(Evaluator 3)
Evaluation
Points
(Average)
Asian Business Association 1.60 4.00 0.80 2.13
Clean Peaks Energy Services 1.80 2.00 2.90 2.23
Staff intend to initiate agreements with the qualified proposers, as needed, to meet OCPA outreach needs related to the Community Power Plan and other outreach efforts such as energy program outreach. While OCPA’s Procurement Policy No. 1, allows for the Chief Executive Officer to establish agreements within the expected not-to-exceed range of the agreements resulting from this RFQ, staff wanted to present the planned approach for increased visibility into the contracting and augmenting of outreach services over the next one to two years.

Based on the panel’s recommendations and current OCPA needs for the Community Power Plan, staff are recommending an agreement with the Asian Business Association Collaborative of Orange County (ABAOC). ABAOC demonstrated the most wide-reaching and community-oriented proposal as evaluated by the panel. Their efforts demonstrate concerted outreach to diverse and multicultural communities, within which they have established deep, trusted relationships. The nonprofit organizations included in ABAOC have experience facilitating outreach consistent with OCPA’s current needs. ABAOC is also adept at promoting projects in multiple languages through a variety of platforms to foster inclusion. Lastly, working with four (4) organizations through one contract will provide reach unachievable by any of the other vendors.

ABAOC has a history of empowering diverse communities and is a collaboration of three (3) nonprofit organizations—Cool OC, Southern California Youth Engagement Association (SoCalYEA), and Asian American Senior Citizens Service Center (AASCSC) to enhance equitable outreach and assist OCPA. AASCSC, founded in 1989, is committed to serving vulnerable elders, millennials and youth, and families and fosters a stronger community through advocacy, direct services, and capacity building. SoCalYEA empowers youth from middle school through college, encouraging them to lead initiatives that positively impact their communities.

Cool OC educates residents about climate change, promotes eco-friendly practices and includes advocating for the most affected communities, ensuring that sustainability is both equitable and inclusive.

ABAOC’s relevant experience includes:

1. Serving OCPA member cities for the following number of years of time:
• Fountain Valley: ABAOC (33), AASCSC (35), SoCalYEA (5), Cool OC (2) • Fullerton: ABAOC (33), AASCSC (35), SoCalYEA (1), Cool OC (2) • Irvine: ABAOC (33), AASCSC (35), SoCalYEA (3), Cool OC (2) • Buena Park: ABAOC (33), AASCSC (35), SoCalYEA (10), Cool OC (2)

2. ABAOC: 30 years of experience in conducting community and business surveys, focus groups, interviews, and assessments with a database of 8,000 contacts. Their newsletter open rate is 78% and the click-through rate is 26%.

3. AASCSC: Actively engages with communities through listening sessions and targeted outreach, including the End Poverty In California (EPIC) initiative with Supervisor Sarmiento and Governor Newsom.

4. SoCalYEA: Students in SoCalYEA regularly engage with elected officials, and many have interned or served as staff or board members in various government agencies and elected officials’ offices.

5. Cool OC: In 2024, Cool OC engaged 1,156 participants in workshops, and recently worked in partnership with the City of Irvine and Waste Management to educate and spread awareness of SB 1383 (organic food waste recycling mandate).

The proposed contracted services are engagement and outreach, with an emphasis on disadvantaged and under-resourced communities, to assist OCPA in advancing the receipt of input from member city community members and businesses to inform its Community Power Plan. The proposed contract will be effective May 1, 2025, through August 31, 2025, for a not-to-exceed amount of $20,000. Contracted services will commence following contract execution. All Community Power Plan-related activities are expected to conclude on August 31, 2025.

FISCAL IMPACT
The not-to-exceed amount for Community Power Plan outreach services is set at $20,000. This amount has been incorporated into the FY2024/25 Energy Programs budget, with a portion of the funding allocated from July and August 2025 of the FY2025/26 budget.

ATTACHMENTS
Attachment A – RFQ Community Power Plan Support Services and Other Outreach Services Attachment B – RFQ Summary Scoring Sheet
1 REQUEST FOR QUALIFICATIONS
For
Orange County Power Authority
Community Power Plan Support Services and
Other Outreach Services
Solicitation Number: 25-001

RESPONSE DUE
by
5:00 p.m. Pacific Standard Time
on
[Feb 13, 2025]
For complete information regarding this project, see RFQ posted at www.ocpower.org or contact OCPA at the email address listed below.

Thank you for your interest!
[[email protected]]
2 A. BACKGROUND AND INTRODUCTION
Orange County Power Authority (OCPA) is seeking responses from nonprofit entities or other organizations, which may include but not be limited to Civil Society Organizations (CSOs), Non-Governmental Organization (NGOs), and Community-Based Organizations (CBOs), and as well as qualified individuals and firms to assist OCPA in advancing its Community Power Plan (CPP) by supporting community needs assessment, engagement and outreach, technical assistance within OCPA’s service area, with an emphasis on serving disadvantaged and under-resourced communities. These partners may also serve as outreach partners to support OCPA’s outreach efforts for the Equitable Building Decarbonization Direct Install Program (EBD-DI) administered by the County of Los Angeles.

This RFQ is a solicitation for qualifications only and is not intended as an offer to enter into a contract or as a promise to engage in any formal competitive bidding or negotiations.

This RFQ outlines the requirements and the scope of work to be performed. OCPA seeks to develop partnerships that support the CPP’s goals, which include:
• Addressing the needs, concerns, and priorities of communities in OCPA’s member jurisdictions.
• Building relationships with community leaders and organizations to inform and equip them to support OCPA’s role in the region.
• Establishing an ecosystem of organizations to support OCPA’s equitable outreach and program administration efforts.

1. BACKGROUND
OCPA is a California joint powers authority created by a Joint Powers Agreement (JPA) on November 20, 2020, as a Community Choice Aggregator (CCA) in Orange County. OCPA provides several benefits to its participating customers including:
• Providing electric power at competitive costs with reduced carbon emissions. • Procuring energy with a priority on the use and development of local renewable resources.
• Stimulating local job creation through various program development. • Promoting personal and community ownership of renewable resources. • Stabilizing long-term electricity rates for residents and businesses.

OCPA is governed by a board of directors (Board) consisting of elected representatives from each participating jurisdiction. The JPA authorizes OCPA with the rights and powers to set rates for the services it furnishes, incur indebtedness, and issue bonds or other obligations.

OCPA was established for the acquisition of electric power for its service area as well as to provide other benefits to the residential, commercial, industrial, and agricultural customers in communities located within the cities of Buena Park, Fountain Valley, Fullerton, and Irvine.

In April 2022, OCPA began providing service to approximately 32,000 commercial, industrial, and agricultural customer accounts and in October 2022, OCPA initiated the second enrollment phase, enrolling all residential customers accounts. As of December 31, 2024, OCPA has over 3 177,000 residential and commercial customers.

2. TERM OF AGREEMENT
Potential agreements awarded following this RFQ are expected to have a term ranging from four (4) months to two (2) years depending on the program and task assigned. OCPA is not required to state a reason if it elects not to extend an agreement.

3. MINIMUM QUALIFICATIONS AND GENERAL EXPECTATIONS OF THE

CONSULTANT
• All proposers should have a valid business license for the City in which they operate. • All Consultants must have strong ties to the communities OCPA serves and availability to support OCPA’s energy and customer program needs.
• The firm proposing services must be able to demonstrate experience working with California based public agencies or municipalities.
• Due to the nature of OCPA’s operations, a non-disclosure agreement may be required in relation to any information the Consultant may be privy to regarding OCPA customer information, if applicable to the work.

B. SERVICES REQUESTED
The Services sought under this RFQ are set forth in more detail in Exhibit A, attached hereto and incorporated herein by this reference. Notwithstanding the inclusion of such Services in Exhibit A, the final scope of Services negotiated between OCPA and the successful Proposer(s) shall be set forth in a Professional Services Agreement or Short-Form Services Agreement (“Agreement”) executed by and between OCPA and the successful Proposer(s). A copy of the Agreement is attached hereto as Exhibit B and incorporated herein by this reference.

C. PROPOSAL SUBMISSION REQUIREMENTS
OCPA will establish a Consultant Selection Panel (“Panel”). This Panel will evaluate the proposals based solely on the information provided, in accordance with the proposal evaluation criteria outlined below.

OCPA reserves the right to invite short-listed Proposers for a pre-selection interview if deemed necessary.

Following the assessment of proposals and/or interviews, the Panel will rank the proposals. The Panel will then recommend the best fit Proposer(s) to the Board of Directors or Chief Executive Officer for potential contracting. The Board of Directors or Chief Executive Officer retain the final authority to approve and enter into a contract with the selected Proposer(s). OCPA reserves the right to not select any respondents from this RFQ, to select a single respondent, or to select multiple respondents.
4 Only digital submissions will be accepted. Please submit all proposals via www.bidnetdirect.com, which is a free platform to applicants. If bidnetdirect.com creates a hardship, please email submissions in PDF format to [email protected] by the established deadline.

Submissions in other digital formats will not be accepted.

Through this RFQ, OCPA is seeking submittals from organizations, located or operating within Orange County and will consider submissions from organizations located or operating outside of outside of its Member Agencies, that provide services to individuals within Orange County (“Respondents”). Individuals or Organizations that respond to this solicitation will have the opportunity to participate in one or more of the activities listed below and be compensated in accordance with the terms outlined in the resulting contract. Organizations will partner with OCPA to meet the outcomes above and will be referred to as “Strategic Partners” (“Partners”). Partners selected may carry out one or more of the following activities shown below, which include but are not limited to:
• Receive communications and gather input from community members (e.g., interviews, focus groups, surveys, newsletters).
• Co-host a one-off or series of OCPA-focused listening sessions or informational meetings (not part of an existing meeting).
• Utilize existing meetings and/or events to host OCPA-focused input gathering sessions.
• Promote and market a specific program/project (e.g., expand outreach to increase participation, provide translation services).
• Serve as an implementer for a specific program/project (e.g., process applications, run a program/project, reporting).
• Other duties, as negotiated between the Partner and OCPA.

OCPA expects the work to commence on or about March 2025. Respondents may be invited to participate in subsequent project-based solicitations and a qualified submittal to this RFQ does not constitute a commitment or promise by OCPA to guarantee any work.

OCPA seeks to engage multiple Partners to perform the following key tasks to support the development and implementation of the CPP. Through the CPP, OCPA seeks to implement energy programs that invest back into OCPA member cities and enhance energy efficiency in the Orange County region.

The first step is assessing the needs of OCPA’s diverse customer base through a Community Needs Assessment. This will focus on identifying the energy needs and priorities of OCPA communities and will be performed via multi-platform and multi-lingual outreach and events. The outcome of the assessment will inform the selection and design of programs over the next five years.

OCPA is working with The Energy Coalition (TEC) as a contracted consultant for the development and implementation of the CPP. Where overlap exists with tasks assigned to TEC under their 5 agreement with OCPA, the selected Partners will be expected to coordinate with TEC to ensure alignment and avoid duplication of efforts.

OCPA requests proposals in the format provided below:

1. CONTENT AND FORMAT OF PROPOSAL
GENERAL INFORMATION (limit: 500 words)
• Legal name of your organization
• Organization’s tax ID
• Name of proposed representative for the submittal
• Title of the representative
• Telephone number of the representative
• Email of the representative
• Organization's physical and website address
• Federal tax status of your organization:
 501(c)3
 501(c)4
 501(c)6
 My organization is not tax exempt, but we have a fiscal sponsor that is tax exempt
 Other _
 If “Other”, what is the federal tax status of your organization? • How many staff are within your organization?
 Full-time:
 Part-time:
 Volunteer:
• Does your organization have a Board of Directors?
 Yes
 No
 If “Yes”, how many Board members does your organization have? • What is your organization’s primary focus area(s)? Select all that apply.  Arts and culture
 Community and economic development
 Education
 Energy/Environment
 Food security
 Health
 Housing
 Human rights
 Policy
 Religious activities
 Other
 If “Other”, or if more detail is required, please elaborate. 6 IMPACT AND COMMUNITIES SERVED (limit: 750 words)
• What is your organization’s mission?
• How many people does your organization serve?
• Which communities does your organization primarily serve, and how do you engage with them?
• Do you regularly organize or host meetings, workshops, or events? If yes, please populate the table below (add rows as appropriate):

Frequency
(e.g., monthly,
quarterly,
annually)
Format (e.g. virtual
webinars, in-person
workshops,
community forums,
or hybrid events)
Average
Attendance
Scheduled or
Approximate
2025 dates
#1
#2
#3
• Please give two examples (or links) of the way you have seen your organization’s work make a difference in the communities you serve.
• Have you collaborated with other organizations in the past? If so, please provide details about the nature of these partnerships, including your organization’s role and contribution.
• Please select which OCPA member city/cities your organization has served and specify the number of years of operation in that city.
 City of Buena Park: ___ years
 City of Fountain Valley: ___ years
 City of Fullerton: ___ years
 City of Irvine: ___ years
• Please check which OCPA member cities your organization will serve in 2025.  City of Buena Park
 City of Fountain Valley
 City of Fullerton
 City of Irvine

PARTNERSHIP AND CAPACITY
The provision of professional services will require that the Respondent has successfully negotiated an Agreement with OCPA.
• What kind of professional services is your organization interested in providing to OCPA? Please select from the list below or fill in the “other” category.

1. Community Needs Assessment: Engage with communities via pop-up events, surveys, workshops, social media and other outreach methods to conduct 7 needs assessments that identify community priorities and barriers to participation. (limit: 500 words)
• Describe your organization's experience conducting community surveys and/or receiving community feedback.
• How many subscribers receive your organization’s emails or newsletters?
• What are your open rates and/or click-through rates?
• Refer to the Budget Table for Option 1 in Exhibit C , which outlines the budget cap for this task to allow you to confirm your ability to deliver these services. A budget proposal submittal is not required. Please provide one professional reference for Option 1, including their name, title, organization, contact information, and a brief description of the project or engagement.

2. Listening Sessions and Informational Meetings: Co-host an OCPA-focused listening session, series of listening sessions, or informational meetings, not tied to existing meetings. (limit: 500 words)
• Describe your experience co-hosting a one-off or series of focused listening sessions or informational meetings.
• Describe how a complex topic was communicated to the
communities of focus. Highlight the objectives, methods used, challenges encountered, and outcomes achieved.
• Refer to the Budget table for Option 2 in Exhibit C, which outlines the budget cap for this task to allow you to confirm your ability to deliver these services. A budget proposal submittal is not required.
• Please provide one professional reference for Option 2, including their name, title, organization, contact information, and a brief description of the project or engagement.

3. Utilizing Existing Meetings or Events: Utilize existing meetings and/or events to host OCPA-focused input gathering sessions such as focus groups. (limit: 500 words)
• What key events does your organization host?
• Describe your organization’s experience hosting input gathering sessions.
• Refer to the Budget table for Option 3 in Exhibit C, which outlines the budget cap for this task to allow you to confirm your ability to deliver these services. A budget proposal submittal is not required..
• Please provide one professional reference for Option 3, including their name, title, organization, contact information, and a brief description of the project or engagement.

4. Program Promotion and Marketing: Promote and market a specific program/project (e.g., expand outreach to increase participation) (limit: 500 8 words)
• Describe your experience, approach and outcomes for promoting and marketing a specific program.
• Please provide one professional reference for Option 4, including their name, title, organization, contact information, and a brief description of the project or engagement.

5. Program Implementation Support: Serve as an implementer for a specific program/project (e.g., process applications, run the program/project, reporting) (limit: 500 words)
• Describe your experience serving as an implementer for a specific program/project.
• Please provide one professional reference for Option 5, including their name, title, organization, contact information, and a brief description of the project or engagement.

6. Other (limit: 500 words)
• Provide details on the professional services your organization is interested in providing OCPA.
• Describe your organization’s current and future capacity. Are you able to support the tasks with current staff and resources?

EVALUATION CRITERIA
The proposals submitted in response to this RFQ shall be evaluated for award based on the criteria set forth below. Partners should submit information sufficient for OCPA to easily evaluate proposals with respect to the selection criteria. The absence of required information may cause the proposal to be deemed non-responsive and may be cause for rejection.

The Panel will select the proposal(s) that offer the greatest value to OCPA based on an analysis of the following criteria:
a.

Criteria Weight
Minimum Qualifications Pass/Fail
• Complete application.
• The organization is independent and properly licensed to practice and authorized to do business in the State of California. • The organization has no conflict of interest regarding any other work performed by the firm for OCPA.
20%
• Clarity and conformance to RFQ
• Community impact & populations served
45%
• Organizational background, experience, capacity, and
references. 35%
9 Total 100%
It is OCPA’s intent to select organization(s) evidencing demonstrated competence and professional qualification sufficient to perform the Services. As outlined in the Evaluation Criteria, the decision to award the contract will consider multiple factors, prioritizing what's best for OCPA. It is important to note that OCPA will not necessarily award a contract to the lowest bidder.

OCPA reserves the right to reject all proposals, select by proposal review only or interview as needed. Certain organization(s) may be selected to interview after which a final selection will be made. The successful proposer(s) will be selected on the basis of information provided in the RFQ, oral interview, and the results of OCPA’s research and investigation.

Upon selection of a organization (or organizations), OCPA will endeavor to negotiate a mutually agreeable services agreement with the selected firm. In the event that OCPA is unable to reach agreement, OCPA may proceed, at its sole discretion, to negotiate with the next organization(s) selected by OCPA. OCPA reserves the right to contract for services in the manner that most benefits OCPA including awarding more than one contract if desired.

2. RFQ SCHEDULE
The tentative schedule is as follows:

Release of RFQ Monday, January 13th, 2025
Virtual Q&A Session Tuesday, January 21st, 2025
Deadline for Question Submittal Friday, January 24th, 2025 Posting of Responses to Questions Friday, January 30th, 2025 RFQ Qualifications Due Thursday, February 13th, 2025
Board Approval based on OCPA evaluations March 2025
Notification of Board decision March 2025
Project-based Contract Begins March 2025
The above scheduled dates are tentative and OCPA retains the sole discretion to adjust the above schedule. Nothing set forth herein shall be deemed to bind OCPA to award a contract for the above-described professional Services, and OCPA retains the sole discretion to cancel or modify any part of or all of this RFQ at any time.

D. TERMS AND CONDITIONS

1. GENERAL PROVISIONS
a. Incurring Cost
This RFQ does not commit OCPA to award or pay any cost incurred in the submission of the proposal, or in making necessary studies or designs for the preparation thereof, nor procure or contract for services or supplies. Further, OCPA will not reimburse the proposer for any costs incurred in responding to this RFQ.
10 b. Claims Against OCPA
Neither your organization nor any of your representatives shall have any claims whatsoever against OCPA or any of its respective officials, agents, or employees arising out of or relating to this RFQ or these RFQ procedures, except as set forth in the terms of a definitive agreement between OCPA and your organization.
c. Guarantee of Proposal
Responses to this RFQ, including proposal prices, will be considered firm and irrevocable for ninety (90) days after the due date for receipt of proposals. d. Basis for Proposal
Only information supplied by OCPA in writing by OCPA in connection with this RFQ should be used as the basis for the preparation of Proposer’s proposal. e. Form of Proposals
Proposals must be submitted electronically and must be received by OCPA prior to the deadline.
f. Amended Proposals
Proposers may submit amended proposals before the Deadline to Submit Proposals. Such amended proposals must be complete replacements for previously submitted proposals and must be clearly identified in a written format.
g. Withdrawal of Proposal
Proposers may withdraw their proposals at any time prior to the Deadline to Submit Proposals.

The Proposer must submit a written withdrawal request signed by the Proposer’s duly authorized representative addressed to and submitted to the Contact. h. No Late Responses
To be considered, proposals must be received electronically via bidnetdirect.com (or via email to [email protected] by the date and time reflected on the cover page. i. California Public Records Act (CPRA)
Pursuant to Michaelis, Montanari, & Johnson v. Superior Court (2006) 38 Cal.4th 1065, proposals submitted in response to this RFQ may be held as confidential by OCPA and shall not be subject to disclosure under the California Public Records Act (Cal. Government Code § 7920.000 et seq.) until after either OCPA and the successful proposer(s) have completed negotiations and entered into an Agreement or OCPA has rejected all proposals. All correspondence with OCPA including responses to this RFQ will become the exclusive property of OCPA and will become public records under the California Public Records Act.

Furthermore, and notwithstanding any other provision of this RFQ, OCPA will have no liability to the proposer or other party as a result of any public disclosure of any proposal or the Agreement.

If a proposer believes that a portion of its proposal would be exempt from disclosure under the California Public Records Act, the proposer must mark it as such and state the specific provision in the California Public Records Act which provides the exemption as well as the 11 factual basis for claiming the exemption. For example, if a proposer submits trade secret information, the proposer must plainly mark the information as “Trade Secret” and refer to the appropriate section of the California Public Records Act which provides the exemption as well as the factual basis for claiming the exemption. Although the California Public Records Act recognizes that certain confidential trade secret information may be protected from disclosure, OCPA may not be in a position to establish that the information that a Proposer submits is a trade secret. If a request is made for information marked “Confidential”, “Trade Secret” or “Proprietary”, OCPA will endeavor to provide proposers who submitted the information with reasonable notice to seek protection from disclosure by a court of competent jurisdiction at the proposer’s sole expense.
j. Confidentiality
All data and information obtained from or on behalf of OCPA by the Proposer and its agents in this RFQ process, including reports, recommendations, specifications, and data, shall be treated by the Proposer and its agents as confidential. The Proposer and its agents shall not disclose or communicate this information to a third party or use it in advertising, publicity, propaganda, or in another job or jobs, unless written consent is obtained from OCPA.

Generally, each proposal and all documentation, including financial information, submitted by a consultant to OCPA is confidential until a contract is awarded, when such documents become public record under State and local law, unless exempted under CPRA. k. Electronic Mail Address
Most of the communication regarding this procurement will be conducted by electronic mail (e-mail). Potential Proposers agree to provide the contact with a valid e-mail address to receive this communication.
l. OCPA Rights
OCPA reserves the right to do any of the following at any time:
• Reject any or all proposal(s), without indicating any reason for such rejection; • Waive or correct any minor or inadvertent defect, irregularity, or technical error in a proposal or the RFQ process, or as part of any subsequent contract negotiation;
• Request that Proposers supplement or modify all or certain aspects of their proposals or other documents or materials submitted;
• Cancel the RFQ, and at its option, issue a new RFQ;
• Procure any services specified in this RFQ by other means; • Modify the selection process, the specifications or requirements for materials or services, or the contents or format of the proposals; • Extend a deadline specified in this RFQ, including deadlines for accepting proposals;
• Negotiate with any or none of the Proposers;
• Modify any terms and/or conditions described in this RFQ in the final agreement;
• Terminate failed negotiations with any Proposer without liability, and negotiate with other Proposer(s);
• Disqualify any Proposer on the basis of a real or apparent conflict of interest, or evidence of collusion that is disclosed by the proposal or other data available to OCPA;
12 • Eliminate, reject, or disqualify a proposal of any Proposer who is not a responsible Proposer or fails to submit a responsive offer as determined solely by OCPA or its representative; and/or
• Accept all or a portion of a Proposer’s proposal.
m. Protests
A Proposer may protest a contract award if the Proposer believes that the award was inconsistent with OCPA policy or this RFQ is not in compliance with law. A protest must be filed in writing with OCPA (email is not acceptable) within five (5) business days after receipt of notification of the contract award. Any protest submitted after 5:00 p.m. of the fifth business day after notification of the contract award will be rejected by OCPA as invalid and the Proposer’s failure to timely file a protest will waive the Proposer’s right to protest the contract award. The Proposer’s protest must include supporting documentation, legal authorities in support of the grounds for the protest and the name, address and telephone number of the person representing the Proposer for purposes of the protest. Any matters not set forth in the protest shall be deemed waived.

OCPA will review and evaluate the basis of the protest provided the protest is filed in strict conformity with the foregoing. OCPA shall provide the Proposer submitting the protest with a written statement concurring with or denying the protest. Action by OCPA relative to the protest will be final and not subject to appeal or reconsideration. The procedure and time limits set forth in this Section are mandatory and are the Proposer’s sole and exclusive remedy in the event of protest. Failure to comply with these procedures will constitute a waiver of any right to further pursue the protest, including filing a Government Code claim or legal proceedings. n. Independent Contractor
Services provided by the successful Proposer(s) (“Consultant”) shall be performed as an independent contractor. All persons employed by Consultant in connection with this agreement shall not be agents or employees of OCPA. Consultant shall be solely and exclusively in charge of determining the means by which the professional services called for herein are performed, and shall be responsible for all costs incurred in connection therewith, unless OCPA agrees otherwise in a duly executed writing delivered to consultant prior to the incurring of such expense. Consultant may also retain or subcontract for the services of other necessary consultants with the approval of OCPA. Payment for such services shall be the responsibility of consultant.
o. Non-Discrimination for Employment with Consultant
During the performance of this agreement, the successful Proposer will not discriminate against any employee or applicant for employment because of race, gender, gender expression, gender identity, religion, national origin, ethnicity, sexual orientation, age, or disability. Such action shall include, but not be limited to the following: employment, upgrading, demotion, or transfer; recruitment or recruitment advertising; layoff or termination; rates of pay or other forms of compensation; and selecting for training, including apprenticeship. The Consultant will ensure that all qualified applicants for employment with Consultant will receive consideration for employment without regard to race, gender, gender expression, gender identity, religion, national origin, ethnicity, sexual orientation, age, or disability. Consultant will take affirmative action to ensure that employees are treated during employment, without regard to their race, gender, gender expression, gender identity, religion, national origin, 13 ethnicity, sexual orientation, age, or disability. Likewise, the Consultant will insure that all qualified applicants for OCPA Chief Executive Officer will receive consideration for employment without regard to race, gender, gender expression, gender identity, religion, national origin, ethnicity, sexual orientation, age, or disability. p. Conflict of Interest
The selected Proposer shall employ no OCPA official or employee in the work performed pursuant to this agreement. No officer or employee in OCPA shall have any financial interest in this agreement in violation of California Government Code Sections 1090 and following, or Sections 87100 and following; nor shall OCPA violate any provision of its Conflict of Interest Code adopted pursuant to the provisions of California Government Code Section 87300 and following.
q. Agreement for Services
The selected Proposer will be required to execute a Professional Services Agreement or Short Form Service Agreement with OCPA (an example of which is attached hereto) and to provide the insurance certificates and all other required documentation within seven (7) calendar days of notification of selection.
r. Exceptions Certification to this RFQ
In submitting a proposal in response to this RFQ, Proposer is certifying that it takes no exceptions to this RFQ including, but not limited to, the attached Agreement. If any exceptions are taken, such exceptions must be clearly noted in the proposal and may be reason for rejection of the proposal. As such, Proposer is directed to carefully review the attached Agreement and, in particular, the insurance and indemnification provisions therein. s. Disclosure Provision/ Conflict of Interest
OCPA complies with all California statutes and regulations related to conflicts of interest.

Under the applicable conflict of interest requirements, the selected proposer may be required to complete and file Form 700 with OCPA before starting or at a future point during the engagement if such requirements become applicable to the selected proposer. t. Reporting of Supplier Diversity Information
Public Utilities Code Section 366.2(m) requires certain community choice aggregators, including OCPA, to annually submit to the California Public Utility Commission (CPUC) a report regarding its procurement from women business enterprises (WBEs), minority business enterprises (MBEs), disabled veteran business enterprises (DVBEs), and LGBT business enterprises (LGBTBEs). Businesses may become certified WBEs, MBEs, DVBEs, and LGBTBEs through the CPUC Clearinghouse, which can be found here:
www.thesupplierclearinghouse.com. Proposers that are awarded the contract will be asked to voluntarily disclose their certification status with the CPUC Clearinghouse, as well as their efforts to work with diverse business enterprises, including WBEs, MBEs, DVBEs, and LGBTBEs. OCPA will use that information solely for compliance with its reporting obligations under Public Utilities Code Section 366.2(m) and evaluation of OCPA’s outreach and other activities consistent with applicable law. Pursuant to Article I, Section 31 of the California Constitution, OCPA shall not discriminate against or give preferential treatment to any individual or group based on race, sex, color, ethnicity, or national origin, except as otherwise permitted thereunder.
14 u. Prevailing Wage
Proposers shall take cognizance of the requirements of California Labor Code Sections 1720 et seq. and 1770 et seq., as well as California Code of Regulations, Title 8, Section 16000 et seq. (“Prevailing Wage Laws”), which require the payment of prevailing wage rates and the performance of other requirements on certain “public work” and “maintenance” projects. The Proposer must agree to fully comply with and to require its subcontractors/subconsultants to fully comply with such Prevailing Wage Laws to the extent applicable.

2. OCPA CONTACT
All questions regarding these specifications, terms and conditions are to be submitted via www.bidnetdirect.com or to [email protected], no later than 5:00 p.m. January 24th, 2025. Bidnetdirect.com will be the official notification posting place of all Requests for Interest, Proposals, Quotes and Addenda.

Go to https://www.bidnetdirect.com/california/orangecountypowerauthority to view current contracting opportunities.

3. ATTACHMENTS
Exhibit “A”: Scope of Services
Exhibit “B”: Standard Professional Services Agreement
Exhibit “C”: Budget for Facilitating Engagements
15 EXHIBIT “A”

SCOPE OF SERVICES
Purpose
The purpose of this Scope of Services is to outline the roles, responsibilities, and deliverables expected from organizations selected to support the Orange County Power Authority (OCPA) in implementing its Community Power Plan (CPP) and/or other Programs. Selected organizations will play a key role in conducting needs assessments, facilitating engagement, and implementing energy programs that prioritize equity and access for OCPA’s diverse communities.

Scope of Work
Selected organizations are expected to work collaboratively with OCPA and other partners, including The Energy Coalition (TEC), to align efforts, avoid duplication, and ensure cohesive program delivery. Coordination activities include:
• Attend weekly/bi-weekly meetings to discuss progress and align strategies. • Share data, feedback, and reports to inform ongoing program development.

All selected organizations will be required to collaborate and coordinate with OCPA and TEC while performing any of the activities listed below.

The scope of services for each activity will vary slightly by type of activity, the final details will be finalized in formal agreements with selected organizations.

1. Community Needs Assessment
Objective: To identify community priorities, barriers to participation, and opportunities for program development.

Key activities:
• Engage with communities via pop-up events, surveys, workshops, social media, and other outreach methods to collect qualitative and quantitative data. • Share quantitative data with OCPA
• Develop a report summarizing the qualitative information received.

Deliverables:
• Report with quantitative data with a mandatory debrief meeting • Community Needs Assessment Qualitative Report.

2. Listening Sessions and Informational Meetings
Objective: To gather community input and provide information about OCPA programs.

Key activities:
• Co-host OCPA-focused listening sessions, a series of listening sessions, or 16 informational meetings that are not tied to existing meetings. • Facilitate interactive discussions to understand community concerns and priorities. • Document and share feedback collected during these sessions with OCPA.

Deliverables:
• Session summaries including attendance, key topics, and community input with a required debrief meeting.

3. Utilizing Existing Meetings or Events
Objective: To maximize outreach and gather input by leveraging existing community gatherings.

Key activities:
• Identify and utilize existing meetings and events to host OCPA-focused input gathering sessions.
• Collaborate with event organizers to integrate OCPA engagement activities seamlessly.
• Provide materials and resources tailored to the event’s audience.

Deliverables:
• Reports summarizing engagement activities and outcomes from existing events with a mandatory debrief meeting.

4. Program Promotion and Marketing
Objective: To increase community awareness and participation in OCPA programs or OCPA partner programs.

Key activities:
• Promote and market specific OCPA programs or projects, such as energy efficiency initiatives or clean energy campaigns.
• Expand outreach to underrepresented groups to ensure equitable participation. • Create and distribute multilingual marketing materials through social media, email, and in-person channels.

Deliverables:
• Marketing and outreach reports, detailing strategies, materials used, and engagement metrics with a required debrief meeting.

5. Program Implementation Support
Objective: To serve as a direct implementor of OCPA programs or OCPA partner programs.

Key activities:
17 • Process applications, run programs or projects, and manage participant interactions.
• Provide reporting on program progress, outcomes, and participant feedback. • Collaborate with OCPA to refine program design and implementation strategies.

Deliverables:
• Monthly implementation reports including metrics on applications processed, participant demographics, and project outcomes with a required debrief meeting.

Performance Metrics
The success of the selected organizations will be measured by:
• Number and diversity of community members engaged.
• Quality and relevance of feedback collected during needs assessments and listening sessions.
• Effectiveness of program promotion efforts, including participation rates. • Timeliness and accuracy of program implementation and reporting. 18 EXHIBIT “B”

ORANGE COUNTY POWER AUTHORITY

SHORT-FORM SERVICES AGREEMENT

1. Parties and Date. This Agreement is made and entered into on __________, 20____, by and between ORANGE COUNTY POWER AUTHORITY, a California joint powers authority (“OCPA”) and [***INSERT NAME OF COMPANY***], a [***INSERT TYPE OF BUSINESS; I.E., CORPORATION (INCLUDE STATE OF INCORPORATION), LIMITED LIABILITY COMPANY, SOLE PROPRIETORSHIP, ETC.***] (“Vendor”). OCPA and Vendor are sometimes individually referred to herein as “Party” and collectively as “Parties.”

2. Terms and Conditions. The Parties shall comply with the Terms and Conditions attached hereto as Exhibit A.

3. Scope of Services; Schedule. The Vendor shall be solely responsible for providing all materials, labor, tools, equipment, water, light, power, transportation, and superintendence of every nature and all other services and all facilities necessary to execute, complete, and deliver the services as particularly described in the Scope of Services (“Services”) attached hereto as Exhibit B. The Services shall be completed timely and in accordance with the Schedule of Services set forth in Exhibit B.

4. Term. The term of this Agreement shall be from [***INSERT DATE***] to [***INSERT DATE***], unless earlier terminated as provided herein.

5. Compensation. Vendor shall receive compensation for Services rendered under this Agreement at the rates set forth in Exhibit C attached hereto. The total compensation shall not exceed [INSERT CAP] without written approval of Authority’s Board of Directors. The total compensation shall not exceed [***INSERT AMOUNT WRITTEN OUT***] ($[***INSERT NUMBER***]) (“Not-To-Exceed Amount”) without written approval of the Authority’s Chief Executive Officer. Vendor’s invoices shall include a detailed description of the Services performed. Invoices shall be submitted to OCPA on a monthly basis. OCPA shall review and pay all non-disputed and approved charges on such invoices in a timely manner. Vendor shall submit its final invoice to OCPA within thirty (30) days from the last date of Services performed and failure to do so shall result in a waiver of payment from OCPA.

6. Insurance. In accordance with Section 3 of the Terms and Conditions, Vendor shall, at its expense, procure and maintain for the duration of the Agreement such insurance policies as checked below and provide proof of such insurance policies in a form satisfactory to OCPA.

Commercial General Liability Insurance:
$1,000,000 per occurrence/$2,000,000 aggregate for bodily injury, personal injury, and property damage
19 Automobile Liability:
$1,000,000 per occurrence for bodily injury and property damage.

Workers’ Compensation:

Statutory Limits / Employer’s Liability $1,000,000 per occurrence Professional Liability (Errors and Omissions):

Errors & Omissions liability insurance $1,000,000 per claim and in the aggregate.

Privacy/Network Security (Cyber) Liability
$1,000,000 per occurrence

7. Electronic Signature. Each Party acknowledges and agrees that this Agreement may be executed by electronic or digital signature, which shall be considered as an original signature for all purposes and shall have the same force and effect as an original signature.

SIGNATURES ON FOLLOWING PAGE(S)

20 IN WITNESS WHEREOF, the Parties hereto have executed this Short Form Services Agreement as of the date first written above.

ORANGE COUNTY POWER AUTHORITY
a California joint powers authority
APPROVED BY:

[***INSERT NAME***]
[***INSERT TITLE***]

APPROVED AS TO FORM:

Best Best & Krieger LLP
General Counsel

[***INSERT NAME OF VENDOR***]
[***INSERT NAME OF LEGAL
ENTITY***]
[***If CORPORATION, TWO

SIGNATURES, PRESIDENT OR VICE

PRESIDENT AND SECRETARY OR
TREASURER REQUIRED***]
Signature
Name

Title

[DELETE THE FOLLOWING SIGNATURE

LINE IF SECOND SIGNATURE NOT
REQUIRED]
Signature
Name

Title

21 EXHIBIT A TO SHORT FORM SERVICES AGREEMENT

TERMS AND CONDITIONS FOR SERVICES

1. Compliance with Law. Vendor shall comply with all applicable laws and regulations of the federal, state and local government. Vendor certifies that it fully complies with all requirements and restrictions of state and federal law respecting the employment of undocumented aliens, including, but not limited to, the Immigration Reform and Control Act of 1986, as may be amended from time to time. By its signature hereunder, Vendor certifies that it is aware of the provisions of Section 3700 of the California Labor Code which require every employer to be insured against liability for Workers’ Compensation or to undertake self-insurance in accordance with the provisions of that Code, and agrees to comply with such provisions before commencing the performance of the Services. Vendor represents that it is an equal opportunity employer and it shall not discriminate against any subcontractor, employee or applicant for employment in violation of state or federal law. Vendor is aware of the requirements of California Labor Code Sections 1720 et seq. and 1770 et seq. (“Prevailing Wage Laws”), which require the payment of prevailing wage rates and the performance of other requirements on certain “public works” and “maintenance” projects. If the work is being performed as part of an applicable “public works” or “maintenance” project, as defined by the Prevailing Wage Laws, and if the total compensation is $15,000 or more for maintenance or $25,000 or more for construction, alteration, demolition, installation, or repair, Vendor agrees to fully comply with such Prevailing Wage Laws, including, along with subcontractors, being registered with the Department of Industrial Relations (Labor Code §§ 1725.1; 1771.1). It shall be mandatory upon the Vendor and all subcontractors to comply with all California Labor Code provisions, which include but are not limited to prevailing wages (Labor Code §§ 1771; 1774; 1775), employment of apprentices (Labor Code § 1777.5), certified payroll records (Labor Code §§ 1771.4; 1776), hours of labor (Labor Code §§ 1813; 1815) and debarment of contractors and subcontractors (Labor Code § 1777.1). This Agreement may be subject to compliance monitoring and enforcement.

2. Standard of Care. The Vendor shall perform the Services in accordance with generally accepted professional practices and principles and in a manner consistent with the level of care and skill ordinarily exercised by members of the profession practicing under similar conditions.

3. Insurance. If required by Section 6 of this Agreement, the Vendor shall take out and maintain during this Agreement: A. Commercial General Liability Insurance for bodily injury, personal injury and property damage, at least as broad as Insurance Services Office Commercial General Liability coverage (Occurrence Form CG 0001); B. Automobile Liability Insurance for bodily injury and property damage including coverage for owned, non-owned and hired vehicles, at least as broad as Insurance Services Office Form Number CA 0001 (ed. 10/13) covering automobile liability, Code 1 (any auto); C. Workers’ Compensation; D. Professional Liability (Errors and Omissions) coverage for a term acceptable to OCPA; and E. Privacy/Network Security (Cyber) Liability for privacy breaches, system breaches, denial or loss of service, and he introduction, implantation or spread of malicious software code. Insurance carriers shall be licensed and authorized to do business in California. Such insurance carrier shall have not less than an “A:VII” rating according to the latest Best Key Rating unless otherwise approved by OCPA. Vendor shall add OCPA, its officers, officials, employees, agents, and volunteers as additional insureds on Vendor’s Commercial General Liability and Automobile Liability. Coverage provided by Vendor shall be primary and any insurance or self-insurance procured or maintained by OCPA shall not be required to contribute with it. All required insurance coverages, except for the professional liability coverage, shall contain or be endorsed to waiver of subrogation in favor of OCPA, its officials, officers, employees, agents, and volunteers or shall specifically allow Vendor or others providing insurance evidence in compliance with these specifications to waive their right of recovery prior to a loss. Vendor hereby waives its own right of recovery against OCPA, and shall require similar written express waivers and insurance clauses from each of its subconsultants.

4. Indemnification. To the fullest extent permitted by law, Vendor shall defend (with counsel of OCPA’s choosing), indemnify and hold OCPA, its officials, officers, employees, volunteers, and agents free and harmless 22 from any and all claims, demands, causes of action, costs, expenses, liability, loss, damage or injury of any kind, in law or equity, to property or persons, including wrongful death (collectively, “Claims”), in any manner arising out of, pertaining to, or incident to any acts, errors or omissions, or willful misconduct of Vendor, its officials, officers, employees, subcontractors, consultants or agents in connection with the performance of the Vendor’s Services, the project, or this Agreement, including without limitation the payment of all expert witness fees, attorney’s fees and other related costs and expenses except such loss or damage which is caused by the sole negligence or willful misconduct of OCPA. Vendor’s obligation to indemnify shall survive expiration or termination of this Agreement and shall not be restricted to insurance proceeds, if any, received by Vendor or OCPA, its officials, officers, employees, agents, or volunteers. If Vendor’s obligation to defend, indemnify, and/or hold harmless arises out of Vendor’s performance as a “design professional” (as that term is defined under Civil Code § 2782.8), then, and only to the extent required by Civil Code § 2782.8, which is fully incorporated herein, Vendor’s indemnification obligation shall be limited to claims that arise out of, pertain to, or relate to the negligence, recklessness, or willful misconduct of the Vendor, and, upon Vendor obtaining a final adjudication by a court of competent jurisdiction, Vendor’s liability for such claim, including the cost to defend, shall not exceed the Vendor’s proportionate percentage of fault.

5. Laws; Venue. This Agreement shall be interpreted in accordance with the laws of the State of California. If any action is brought to interpret or enforce any term of this Agreement, the action shall be brought in a state or federal court situated in the County of Orange, State of California.

6. Termination. OCPA may terminate the whole or any part of this Agreement for any or no reason by giving three (3) calendar days written notice to Vendor. In such event, OCPA shall be immediately given title and possession to all original field notes, drawings and specifications, written reports and other documents produced or developed for the work. OCPA shall pay Vendor the reasonable value as determined by OCPA of any portion of the Services completed prior to termination. OCPA shall not be liable for any costs other than the charges or portions thereof which are specified herein. Vendor shall not be entitled to payment for unperformed Services and shall not be entitled to damages or compensation for termination of the Services. Vendor may terminate its obligation to provide further work under this Agreement upon thirty (30) calendar days written notice to OCPA only in the event of OCPA’s failure to perform in accordance with the terms of this Agreement through no fault of Vendor.

7. Changes. By written notice, OCPA may from time to time, make changes to the Services furnished to OCPA by Vendor. If such change is anticipated to cause an increase in the Not-to-Exceed Amount or in the time required for performance, Vendor shall promptly notify OCPA and obtain OCPA’s written approval of the increased amount.

8. Force Majeure. The respective duties and obligations of the Parties hereunder shall be suspended while and so long as performance hereto is prevented or impeded by a Force Majeure Event. The Vendor will not receive an adjustment to the contract price or any other compensation. A Force Majeure Event shall mean an event that materially affects a party’s performance and is one or more of the following: (1) Acts of God or other natural disasters occurring at the project site; (2) terrorism or other acts of a public enemy; (3) orders of governmental authorities (including, without limitation, unreasonable and unforeseeable delay in the issuance of permits or approvals by governmental authorities that are required for the work); (4) pandemics, epidemics or quarantine restrictions; and (5) strikes and other organized labor action occurring at the project site and the effects thereof on the work, only to the extent such strikes and other organized labor action are beyond the control of Vendor and its subcontractors, of every tier, and to the extent the effects thereof cannot be avoided by use of replacement workers.

For purposes of this section, “orders of governmental authorities,” includes ordinances, emergency proclamations and orders, rules to protect the public health, welfare and safety, and other actions of OCPA in its capacity as a municipal authority. Notwithstanding the foregoing, OCPA may still terminate this Agreement in accordance with Section 6.

9. Equal Opportunity Employment and Subcontracting. Vendor represents that it is an equal opportunity employer and it shall not discriminate on the basis of race, gender, gender expression, gender identity, religion, national origin, ethnicity, sexual orientation, age, or disability in the solicitation, selection, hiring, or treatment of 23 applicants, employees, subcontractors, vendors, or suppliers. Such non-discrimination shall include, but not be limited to, all activities related to initial employment, upgrading, demotion, transfer, recruitment or recruitment advertising, layoff or termination. Further, Vendor shall provide equal opportunity for subcontractors to participate in subcontracting opportunities.

10. Miscellaneous Terms. Vendor shall not assign, sublet, or transfer this Agreement or any rights under or interest in this Agreement without the written consent of OCPA. This Agreement may not be modified or altered except in writing signed by the Parties. There are no intended third party beneficiaries of any right or obligation of the Parties.

This is an integrated Agreement representing the entire understanding of the Parties as to those matters contained herein, and supersedes and cancels any prior oral or written understanding or representations with respect to matters covered hereunder. Since the Parties or their agents have participated fully in the preparation of this Agreement, the language of this Agreement shall be construed simply, according to its fair meaning, and not strictly for or against any Party. The captions of the various paragraphs are for convenience and ease of reference only, and do not define, limit, augment, or describe the scope, content or intent of this Agreement. The unenforceability, invalidity or illegality of any provision(s) of this Agreement shall not render the other provisions unenforceable, invalid or illegal. Notice may be given or delivered by depositing the same in any United States Post Office, certified mail, return receipt requested, postage prepaid, addressed to the Parties to the addresses set forth in this Agreement. Vendor is retained as an independent contractor and is not an employee of OCPA. No employee or agent of Vendor shall become an employee of OCPA. Vendor warrants that the individual who has signed this Agreement has the legal power, right and authority to make this Agreement and bind the Vendor hereto.

24 EXHIBIT “C”

BUDGET FOR FACILITATING ENGAGEMENTS
Costs outlined below represent the maximum caps. Each activity will require an itemized cost sheet.

Option 1. Community Needs Assessment
Engagement Type: Roundtable
OCPA will compensate not-to-exceed $4,000 for a roundtable of a minimum of five (5) participants; this cost includes:
• Planning time
• Event staffing
• $25 incentives per participant
• Venue costs, including food and beverage
Engagement Type: Event Tabling
OCPA will compensate not-to-exceed $2,000 for tabling an event; this cost includes:
• Planning time
• Event staffing
• Venue costs
.

Engagement Type: Surveys
OCPA will compensate not-to-exceed $8,500 for 1,000 survey responses (approximately 500 paper and 500 electronic); this cost includes:
• Time to collect survey data
• Digital survey platform hosting
• Total incentive of $500 for participants
Option 2. Listening Sessions and Informational Meetings Engagement Type: Listening Sessions
OCPA will compensate not-to-exceed $3,500 for a roundtable of a minimum of ten (10) participants; this cost includes:
• Planning time
• Event staffing
• $25 incentives per participant
• Venue costs, including food and beverage
Option 3. Utilizing Existing Meetings or Events
Engagement Type: Existing Meetings:

OCPA will compensate not-to-exceed $2,000 to co-host an existing meeting; this cost includes:
• Planning time
• Event staffing
• Venue costs
Orange County Power Authority
Request for Proposal (RFP) Summary
RFP For: RFQ Community Power Plan Support Services and Other Outreach Services RFP No: 25-001
Type of Procurement (Informal Bidding or Formal Biddin Formal Bidding Event Date
Release Request for Qualifications Monday, January 13, 2025 Questions Submitted to OCPA Friday, January 24, 2025
OCPA Posts Response to Questions Thursday, January 30, 2025 RFQ Deadline Thursday, February 27, 2025
Board Approval based on OCPA evaluations Monday, April 14, 2025 Notification of Board decision Monday, April 14, 2025
Project-based Contract Begins Thursday, May 1, 2025
Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 4.10 4.00 3.75 3.95 Vendor 2 - Clean Peaks Energy Services 1.80 1.90 1.55 1.75 Vendor 3 - Climate Action Campaign 3.60 4.00 3.95 3.85
Vendor 4 - OC Goes Solar 3.95 3.80 3.60 3.78
Vendor 5 - Orange County United Way 2.70 1.00 1.00 1.57 Vendor 6 - Tripepi Smith & Associates 3.25 3.10 3.95 3.43 Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 4.35 3.65 4.45 4.15 Vendor 2 - Clean Peaks Energy Services 1.80 1.90 2.00 1.90 Vendor 3 - Climate Action Campaign 3.60 4.35 4.30 4.08
Vendor 4 - OC Goes Solar 1.80 2.90 2.35 2.35
Vendor 5 - Orange County United Way 3.05 1.00 1.00 1.68 Vendor 6 - Tripepi Smith & Associates 2.90 3.80 4.30 3.67 Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 3.90 3.55 4.00 3.82 Vendor 2 - Clean Peaks Energy Services 1.80 1.20 2.35 1.78 Vendor 3 - Climate Action Campaign 3.05 3.30 3.95 3.43
Vendor 4 - OC Goes Solar 1.80 3.25 3.05 2.70
Vendor 5 - Orange County United Way 3.40 1.00 1.00 1.80 Vendor 6 - Tripepi Smith & Associates 2.20 2.75 4.65 3.20 Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 3.20 4.00 4.00 3.73 Vendor 2 - Clean Peaks Energy Services 1.80 1.90 2.35 2.02 Vendor 3 - Climate Action Campaign 2.50 4.00 3.95 3.48
Vendor 4 - OC Goes Solar 4.30 3.25 4.65 4.07
Vendor 5 - Orange County United Way 3.60 4.30 4.30 4.07 Vendor 6 - Tripepi Smith & Associates 2.20 2.75 3.50 2.82 Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 2.05 2.40 2.85 2.43 Vendor 2 - Clean Peaks Energy Services 1.80 1.90 2.70 2.13 Vendor 3 - Climate Action Campaign 1.00 0.80 1.00 0.93
Vendor 4 - OC Goes Solar 1.00 0.60 1.00 0.87
Vendor 5 - Orange County United Way 0.40 1.00 1.00 0.80 Vendor 6 - Tripepi Smith & Associates 1.00 2.05 1.00 1.35 Proposers
Evaluation Points
(Evaluator 1)
Evaluation Points
(Evaluator 2)
Evaluation Points
(Evaluator 3)
Evaluation Points
(Average)
Vendor 1 - Asian Business Association 1.60 4.00 0.80 2.13 Vendor 2 - Clean Peaks Energy Services 1.80 2.00 2.90 2.23 Vendor 3 - Climate Action Campaign 1.00 0.80 1.00 0.93
Vendor 4 - OC Goes Solar 1.00 0.60 1.00 0.87
Vendor 5 - Orange County United Way 0.40 1.00 1.00 0.80 Vendor 6 - Tripepi Smith & Associates 1.00 1.00 3.85 1.95 Community Needs
Assessment
Listening Sessions
and Informational
Meetings
Utilizing Existing
Meetings or Events
Program Promotion and
Marketing
Program
Implementation Support Other

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.2
--------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Pranesh Venugopal, Energy Programs Manager
Jacquie Henderson, Director of Communications and External Affairs Approved by: Joe Mosca, Chief Executive Officer
Subject: APPROVAL OF SOLAR REBATE AND EV CHARGER REBATE PROGRAMS Date: April 14, 2025
-------------------------------------------------------------------------------------------------------------------- - RECOMMENDED ACTIONS

BACKGROUND
As a not-for-profit community choice aggregation (CCA) agency, Orange County Power Authority (OCPA) reinvests revenue into its member communities through energy efficiency programs and grants that benefit customers and support a healthier, more sustainable Orange County.

As OCPA develops its Community Power Plan to determine new near- and long-term energy programs, the agency is looking for opportunities to support the renewable energy initiatives that are conclusively needed across California, including within OCPA member cities. These initiatives are electric vehicle (EV) chargers and solar plus battery storage.

ANALYSIS
California policymakers have prioritized the transition to solar power and other clean, renewable energy to grow the state's production and storage capacity. California generated 68,816 gigawatt-hours (GWh) of electricity from solar power in 2023, up 9% from 2022, per an analysis from the research nonprofit Climate Central*
. From 2018 to 2024, battery storage capacity in California increased from 500 megawatts (MW) to more than 13,300 MW, with an additional 3,000 MW planned to come online by the end of 2024. The state projects 52,000 MW of battery storage will be needed by 2045**.

Additionally, California continues to lead the transition to electric mobility in the United States.

The state now has 48 percent more charging stations for electric vehicles (EVs) than gas pumps, underscoring the desire to electrify vehicles. Notably, home charging is by far the preferred charging method for the majority of EV owners***.

To support these important, ongoing, and statewide renewable energy initiatives, OCPA staff from multiple departments explored a range of options with the goal of launching more turnkey programs in FY2024/25, and continuing to research and develop more complex opportunities for FY2025/26 and beyond.

OCPA explored a range of solar programs, including zero-interest loan options and Community Choice Aggregator (CCA) models featuring Power Purchase Agreements (PPAs). Research included conversations with member cities Irvine and Fullerton - a discussion with Buena Park is planned - as well as consultations with sister CCAs San Diego Community Power (SDCP) and Peninsula Clean Energy (PCE). OCPA also engaged with solar plus battery and virtual power plant vendors, as well as vendors involved in EV Charging in multifamily dwellings with plans to speak with companies involved in curbside charging.

The City of Irvine reported great success with a zero-percent home improvement loan program that was highly popular for rooftop solar installations. A discussion with PCE provided better understanding of the implementation complexity and bandwidth requirements for a zero-percent loan program based on their experience.

OCPA also received positive feedback from SDCP that implemented a highly popular solar and battery rebate program that provides two financial incentives for participating customers: an upfront incentive to minimize the initial cost of the battery system, and a performance incentive for a daily dispatch of the battery to maximize benefits for the customer and the grid. The performance incentive is based on the percentage of battery capacity that a participant dispatches to their home and/or to the grid during a preset window that aligns with the on-peak periods.

For EV charging infrastructure, OCPA consulted with member cities to identify technical and funding challenges affecting public, city-owned charging stations to see where gaps exist. The City of Irvine reported that residential charger rebates available from other sources have largely vanished despite ongoing demand. OCPA also engaged with Los Angeles County and their multifamily EV charging program implementer to explore potential program integration opportunities. Additional insight was sought from Peninsula Clean Energy about their experience implementing multifamily EV charging initiatives.

Recommendation
After examining the various approaches, it is the recommendation of staff that OCPA initiate support of EV chargers and solar plus battery storage by implementing a rebate program for each initiative. Rebate programs offer several key advantages, particularly in their simplicity and customer acceptance. Unlike loan or PPA models, rebates do not tie customers to long-term obligations, thereby offering greater flexibility. Furthermore, rebate programs can be managed largely in-house with current staff support, aligning with OCPA's current capacity and operational status.

Program Overview
The Solar Rebate Program will offer a rebate of $1,000 for solar installations that include solar panels paired with battery storage or battery storage alone. This program is designed to encourage customers to adopt energy storage solutions, which will help them store energy for later use, particularly during peak demand periods or power outages. The rebate will be available to residential customers across OCPA member cities, with participation capped at a total budget of $250,000.

The EV Charger Rebate Program will provide a not-to-exceed $1,000 rebate for a hard-wired Level 2 EV charger for all eligible residential customers through the OCPA Marketplace. This charger ranges from $500 to $600 on the OCPA Marketplace, making the charger no-cost to the customer.

In addition to these OCPA-specific rebate programs, there are existing programs, subsidies and tax credits that residents may leverage:
• Solarize Irvine provides solar education and group discounts for solar panels, battery storage, and EV chargers.
• The Solar on Multifamily Affordable Housing (SOMAH) Program provides financial incentives based on system size and energy allocation between common area and tenant loads for the installation of solar energy photovoltaic systems on multifamily affordable housing properties.
• The Federal Inflation Reduction Act’s 30 percent tax credit is available on solar installations for homeowners who purchase and install solar panels on their primary or secondary residence.
• Property Assessment Clean Energy (PACE) loans offer another option for financing solar and energy efficiency upgrades. These loans are repaid through property tax assessments and offer the advantage of being attached to the property rather than the individual. While these loans typically come with higher interest rates ranging from 7-10%, the interest paid on these loans is tax-deductible, which may help some residents reduce overall cost. • California Public Utilities Commission (CPUC) funded Charge Ready programs that offer rebates and technical assistance for the installation of public EV chargers and for fleet electrification.

OCPA will develop a landing page on its website that highlights the rebate programs and these additional opportunities for increased funds.

Current OCPA Program Benefits
• Solar customers in OCPA's programs receive a 10% higher net surplus compensation rate as compared to SCE.
• By maintaining NEM 2.0 benefits instead of transitioning to SCE's more restrictive Net Billing Tariff, OCPA provides fuller retail credit for excess generation up to annual usage, maximizing solar investment value and shortening payback periods. • OCPA also offers various payment and bill assistance programs to help ensure that energy costs remain manageable for low-income households.

Future Programs
• OCPA is working with the California Public Utilities Commission (CPUC) to incorporate the Community Solar Green Tariff Program into its offerings. The program provides local solar energy at a 20% bill discount for income-qualified residential customers in Disadvantaged Communities (DACs) who may be unable to install solar on their roof. • OCPA plans to seek funding opportunities for new build EV chargers, including the next round of funding from the Fast Charge California Project, which will be open from July 8 to September 30. The first round of funding provided $65 million to four CCAs in Northern California.
• OCPA has also been assigned the outreach and education for the Electrification Decarbonization Program-Direct Install (EBD-DI), a program funded by the California Energy Commission (CEC) and administered by The County of Los Angeles. This program will focus on free installation of all-electric appliances, energy efficiency, weatherization measures, and related building upgrades in communities of concern, specifically in Buena Park and Fullerton. The program is scheduled to launch in the second quarter of 2025 and will provide valuable support for low-income and underserved communities, helping to transition them to clean energy solutions.

Next Steps
Upon approval, OCPA will finalize the terms and conditions for both the Solar and Battery Rebate Program and EV Charger Rebate Program. This will include defining eligibility requirements, qualifying equipment standards, and ensuring that the overall program guidelines are clear and accessible. Following this, outreach efforts will begin to inform OCPA customers of these programs. The EV Charger Rebate Program will be launched in the remaining months of FY2024/25, followed by the Solar and Battery Rebate Program in FY2025/26. The EV Charger Rebate Program will operate through the OCPA Marketplace for ease of initial implementation, with future expansion to be explored.

OCPA will continue to monitor demand for both programs and adjust the available funding as necessary to meet customer needs. Additionally, OCPA will begin exploring long-term program options, including a solar loan program, a PPA program with a fixed monthly fee model, public EV charging for multi-unit dwellings, public curbside EV charging, EV charger maintenance, and EV workforce training.

FISCAL IMPACT
The combined budget for the Solar and Battery Rebate Program and the EV Charger Rebate Program is capped at $250,000. For FY2024/25, the EV Charger Rebate Program is allocated $99,000, expected to support approximately 165 Level 2 chargers. For FY2025/26, the Solar and Battery Rebate Program is estimated at $151,000, based on current projections of customer participation. Staff will evaluate the budget as the programs progress, and Board approval will be sought for the FY25/26 budget in June 2025.

ATTACHMENTS
None.
*
California Energy Commission: California Energy Storage System Survey **Axios San Diego: California is a solar superpower **Auto123.com: California Now Has 48 Percent More Charging Stations Than Gas Pumps * Data sources: DOE Global Energy Storage Database and U.S. battery capacity increased 66% in 2024 - U.S. Energy Information Administration (EIA)

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.3
--------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Steven Halligan, Regulatory & Legislative Manager Louis Ting, Director of Power Resources
Approved By: Joe Mosca, Chief Executive Officer
Subject: ENERGY STORAGE SYSTEMS UPDATE
Date: April 14, 2025
---------------------------------------------------------------------------------------------------------------------

RECOMMENDED ACTION
Receive and file.

BACKGROUND
Energy storage systems (ESS) provide a multitude of benefits for electric utilities and grid operators. ESS has been the de facto technology application that supplies the necessary power and energy to follow demand or augment other generation technologies to ensure reliability and grid stability. Since the advent of cleaner and more sustainable generation technologies from the 1950s with nuclear power plants to the globally adopted renewable energy technologies in recent decades, ESS has played a pivotal role in supporting load growth with reliability. Moreover, ESS will continue to support clean energy transformation, modernization, resilience, and sustainability.

Based on the technology adoption perspective, two prominent ESS types emerged globally as the preferred applications – pumped-storage hydro (PSH) and battery ESS (BESS). This adoption rate holds true for the United States, with PSH and BESS account for over 90 percent* of all ESS based on energy capacity. PSH installations for the U.S. utilities peaked in the 1970s, with a residual surge in 2014. BESS installations have grown exponentially since the advent of the industry’s commercialization between 2017 and 2018. BESS in U.S. utility applications grew from 5.75 GW in 2023 to 46 GW in 2025, a projected increase of 700%*.

With the rapid advancement in BESS technology and commercialization, design standards, codes, and regulations that govern complete safety seem to have paralleled efforts. With the increase in ESS failure incidents that resulted in hazards that still have no immediate plausible mitigation policies or procedures, the industry is acutely aware and constantly advancing battery technology to prevent past failures while increasing mitigation efforts should such incidents occur. From the early lithium chemistry with more costly and less sustainable rare earth materials that OEMs are shunting away to the safer and more sustainable lithium-iron-phosphate chemistry that has increased production by the OEMs. National Fire Protection Association (NFPA), International Fire Code, and Underwriter Laboratory standards evolved to ensure safety starts with design and * BESS Failure Incident Database - EPRI Storage Wiki and Insights from EPRI’s Battery Energy Storage Systems (BESS) Failure Incident Database: Analysis of Failure Root Cause is rigorously tested before application. NFPA has holistically revised codes for battery applications to cover safety areas from personnel, facility, design, testing, operations, protection, detection, and firefighting materials. With all the efforts to support a sustainable and resilient grid and to gain the public’s trust, prudent efforts in setting amenable policies and regulations will be required.

Lessons learned from the OEMs must be made transparent and shared amongst all the stakeholders, and the state of New York attempted one such regulation* but stopped short of requiring disclosure of root-cause analysis by the OEM. The efforts by the Electric Power Research Institute to track all BESS failure incidents globally through its database* are made publicly and accessible everywhere; their efforts can only bring significant benefits to all BESS stakeholders if transparency on lessons learned is well documented and shared.

ESS technology will continue to advance as the grid transforms into a cleaner, more resilient, and sustainable pathway. With the increased adoption of renewable energy, ESS technologies are becoming the foundation for sustaining load growth while providing necessary services for a dependable grid.

From California’s perspective, legislation has been proposed at the state level and actions taken locally in Orange County, and regulations from the California Public Utilities Commission (CPUC) have been adopted to strengthen the safety of BESS.

As a result of a fire at Vistra Energy's Moss Landing battery storage facility on January 16, 2025, in Monterey County, California several regulatory, legislative, and local actions have occurred.

This battery storage facility is one of the oldest in the state and utilizes technologies and practices that are no longer standard for these types of facilities. For example, this facility is in building as opposed to containers and utilizes lithium nickel manganese cobalt oxide batteries which are not common in today’s projects.

On March 13, the CPUC adopted General Order (GO) 167-C Enforcement of Maintenance and Operations Standards, which establishes standards for BESS Emergency Response and Emergency Action Plans, Logbook Standards, Maintenance and Operation Standards, and provisions to enhance safety. The CPUC has already begun scheduling inspection at BESS facilities across the state.

In the California legislature, several bills have been introduced to address safety standards at BESS facilities. Two have gained the most traction, AB 303 by Assemblymember Addis and SB 283 by Senator Laird. AB 303 would prohibit the authorization of a development project that includes a battery energy storage system capable of storing 200-megawatt hours or more of energy if the development project is located within 3,200 feet of a sensitive receptor or on an environmentally sensitive site, as specified. CalCCA took an oppose position on March 13, 2025. Under SB 283, developers are required to consult with local fire authorities prior to submitting a BESS application through either the local approval process or the California Energy Commission (CEC) AB 205 process. This consultation must address facility design, assess potential risks, and integrate emergency response plans, such as those required under SB 38 (Laird, 2023).

CalCCA is working on proposed amendments.
* Data sources: DOE Global Energy Storage Database and U.S. battery capacity increased 66% in 2024 - U.S. Energy Information Administration (EIA)
On Tuesday, March 11, the Orange County Board of Supervisors enacted an urgency ordinance extending a moratorium on issuing permits for Battery Energy Storage System (BESS) facilities in Orange County unincorporated areas for 10 months and 15 days. The extension allows for further study on regulating BESS facilities due to safety concerns, including fire risks in high-fire-hazard areas. Certain residential and non-residential BESS associated with EV charging and solar energy systems remain subject to state regulations. Nothing in this Urgency Ordinance shall be interpreted to conflict with the Opt-In Certification Process for BESS established by and under the authority of the California Energy Commission, including new facilities that qualify for the Opt-In Certification Process. Ten days before this extension of the interim urgency ordinance expires, OC Planning/Development Services shall issue a written report describing the measures taken or recommending measures to alleviate the condition that led to its adoption. OCPA continues to monitor the situation and has offered our assistance to the County of Orange in developing any ordinances, rules, or regulations related to BESS facilities. OCPA is committed to ensuring the safety of our local communities while ensuring access to local renewable energy generation.

FISCAL IMPACT
None.

ATTACHMENT

1. Presentation: Energy Storage Systems Update
| ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
SEPTEMBER 9, 2024 2
• Unearthed in Khujut Rabu, just
outside of Baghdad in 1936
• Wilhelm Konig, German
archaeologist concluded as a battery
• Replicas were built – generated
small amounts of electricity
• Archaeologists believe that it had
no electrical purposes
• Why did this battery exist?
Energy Storage Systems

HISTORICAL CONTEXT
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
The Baghdad Battery
Circa 200 B.C.

SEPTEMBER 9, 2024 3
Energy Storage Systems

FOR ELECTRICITY GENERATION
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
Energy Storage System:

An electrical equipment or system capable
of charging and storing electricity at a
rated capacity and capable of discharging
or generating electricity at desired levels,
quality, schedule, and duration.

SEPTEMBER 9, 2024 4
Energy Storage Systems

FOR ELECTRICITY GENERATION
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
Pumped Storage Hydro
• Built primarily between 1960 to 2015 to augment
baseload nuclear to follow variable demand
Battery Energy Storage
• Lithium-based commercialized in 2009 to augment
increasing variable renewable energy to follow variable demand and generation
United States Installations* 1965 2015 ↑ Years
Pumped-hydro (MWh) 2,700 359,700 132x 50
*Source: U.S. Department Of Energy Global Energy Storage Database United States Installations* 2009 2025 ↑ Years
Lithium-ion (MWh) 250 168,000 671x 16
SEPTEMBER 9, 2024 5
Hydroelectric Generation
and Pumped Storage
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
SEPTEMBER 9, 2024 6
California’s Pumped Storage Legacy
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
Castaic Power Plant
Los Angeles Dept of Water and Power
Helms Pumped-Storage
Plant
Pacific Gas and Electric
SEPTEMBER 9, 2024 7
Battery Energy Storage Systems
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
SEPTEMBER 9, 2024 8
Battery Energy Storage Systems
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE

SAFETY RECORDS
Source: EPRI Failure Incident Database
SEPTEMBER 9, 2024 9
Battery Energy Storage Systems
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE

SAFETY RECORDS
Source: EPRI Failure Incident Database
SEPTEMBER 9, 2024 10
Battery Energy Storage Systems
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE

SAFETY RECORDS
Source: EPRI Failure Incident Database
SEPTEMBER 9, 2024 11
Battery Energy Storage Systems
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE

RECOMMENDATIONS
Source: EPRI Failure Incident Database
SEPTEMBER 9, 2024 12
California Public Utilities Commission
On March 13, the CPUC adopted GO 167-C Enforcement of Maintenance and Operations Standards, which establishes standards for BESS Emergency Response and Emergency Action Plans, Logbook Standards, Maintenance and Operation Standards, and provisions to enhance safety. The CPUC has already began scheduling inspection at BESS facilities across the state.

AB 303 (Addis)
This bill would prohibit the authorization of a development project that includes a battery energy storage system capable of storing 200-megawatt hours or more of energy if the development project is located within 3,200 feet of a sensitive receptor or on an environmentally sensitive site, as specified.

CalCCA took an oppose position on March 13, 2025.

SB 283 (Laird)
Under SB 283, developers are required to consult with local fire authorities prior to submitting a BESS application through either the local approval process or the California Energy Commission (CEC) AB 205 process. This consultation must address facility design, assess potential risks, and integrate emergency response plans, such as those required under SB 38 (Laird, 2023).

CalCCA is working on proposed amendments.

Energy Storage Systems

LEGISLATIVE AND REGULATORY UPDATES
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
SEPTEMBER 9, 2024 13
County of Orange
• On Tuesday, March 11, the Orange County Board of Supervisors enacted an urgency ordinance extending a moratorium on issuing permits for Battery Energy Storage System (BESS) facilities in Orange County unincorporated areas for 10 months and 15 days.
• The extension allows for further study on regulating BESS facilities due to safety concerns, including fire risks in high-fire-hazard areas. Certain residential and non-residential BESS associated with EV charging and solar energy systems remain subject to state regulations. Nothing in this Urgency Ordinance shall be interpreted to conflict with the Opt-In Certification Process for BESS established by and under the authority of the California Energy Commission, including new facilities that qualify for the Opt-In Certification Process.
• Ten days before this extension of the interim urgency ordinance expires, OC Planning/Development Services shall issue a written report describing the measures taken or recommending measures to alleviate the condition that led to its adoption. • OCPA continues to monitor the situation and has offered our assistance to the County of Orange in developing any ordinances, rules, or regulations related to BESS facilities. OCPA is committed to ensuring the safety of our local communities while ensuring access to local renewable energy generation.

Energy Storage Systems

LEGISLATIVE AND REGULATORY UPDATES
ITEM 8.3 ENERGY STORAGE SYSTEMS UPDATE
Q&A

ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 9
--------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Joe Mosca, Chief Executive Officer
Subject: CHIEF EXECUTIVE OFFICER’S REPORT
Date: April 14, 2025
--------------------------------------------------------------------------------------------------------------------- Buena Park Smart Choice Notification Mailer #2 (Change in Default Product) A second notice was mailed to Buena Park default product customers who seamlessly transitioned to Smart Choice on their March meter read date. The second direct mail piece for all Buena Park default product customers was mailed out in two (2) batches on April 7 and April 9. Batching the notices optimizes staff availability for prompt support. The team was available to talk to representatives and ensure customer goals were met. This communication is intentionally smaller, postcard-sized, with less text than the first 8½” x 11” mailer from February. The mailer is attached for your reference.
2025 Strategic Plan Update – Coming in May
Following last month’s March 21st Strategic Planning Workshop, the staff are organizing various priorities and themes captured in the detailed discussions to update our current strategic plan. To ensure this proactive and essential process receives the time and attention needed, the goal is to return with proposed updates to the Strategic Plan for the Board of Directors' consideration at the May meeting. This timeline will allow OCPA to consider our objectives for the year as we establish a budget for the upcoming fiscal year.

FY2025/26 Budget Development Progress
In mid-April 2025, staff will meet with the Ad-hoc Budget and Finance Committee to discuss developing the FY2025/26 Budget and 5-Year Projection. Staff will present the FY2025/26 Budget Framework to the Board on May 12, 2025, to gather feedback.

Revenue Deferral Transfer
As planned, OCPA will transfer the FY23/24 revenue deferral of $45 million in FY24/25 to offset the anticipated revenue shortfall resulting from maintaining the 2024 rate design in 2025. From January through June 2025, OCPA will allocate $7.5 million per month from the deferred revenue as operating revenue. This deferral aligns with the Board-approved Rate Stabilization Policy, serving as a key financial tool to ensure stability and affordability for customers. By proactively reallocating these funds, OCPA strengthens its ability to mitigate financial risks while maintaining the 2024 rate design in 2025, despite significant declines in SCE’s 2025 generation rates and rising costs for renewable energy (PCC1) and Resource Adequacy. This approach ensures continued rate stability and protects customers from volatility.

Communications & External Affairs Updates
Communications
 With the direction we received at the Strategic Planning Workshop, we are putting together a trifold brochure to share with prospective member cities and community members who want to express interest in OCPA to their respective city councils. We look forward to receiving this shortly.

Community Engagement
 On March 25, OCPA staff hosted a pop-up event at the Buena Park Community Center.

The interactions were incredibly productive, with the entire City Council stopping by to express appreciation for our efforts. We also had a meaningful conversation with a local small business owner who expressed interest in how OCPA’s programs could lower their energy costs.
 On March 22, OCPA tabled at the Cool Irvine, Woodbridge Community Block Party, a three-hour event focused on sustainable living at the Lakeview Senior Center. OCPA joined other eco-friendly educators, artists, and community-based organizations. The event was busy, and we received a lot of engagement for the community needs assessment survey.
 We also attended Cottie Petrie-Norris’ Women of the Year Celebration for Costa Mesa, Irvine, and Tustin Women leaders.

External Affairs
 In mid-March, we presented to the Santa Ana Chamber of Commerce Ambassador Group, providing a detailed walkthrough of OCPA’s operations and highlighting our value proposition for local businesses. The presentation was well received, and the Chamber's Chief of Staff supports exploring OCPA for Santa Ana.
 We have connected with several Stanton City Council members to answer questions before OCPA’s feasibility study presentation in April. Inquiries center around the community's benefits of OCPA and the programs we currently provide and are planning for the future.  Additionally, OCPA has helped to facilitate the April business mixer hosted by the North Orange County Chamber of Commerce in the City of Stanton. This effort is to help Stanton, a prospective OCPA city, receive feedback on bringing new and long-standing businesses to the City. OCPA will be a spotlight sponsor, giving the agency prominent placement in event marketing materials and during the mixer. This event will provide the opportunity for brand positioning, community awareness, and potential business development conversations with Stanton’s commercial stakeholders.
 Staff attended the Orange County Council of Governments (OCCOG) Annual Conference in Yorba Linda. The conference focused on critical regional topics such as transportation, infrastructure planning, housing development, and intergovernmental collaboration. Staff connected with representatives from La Palma, Lake Forest, Westminster, and the Orange County Board of Supervisors members.
 Staff also attended the "Good Morning Irvine" event hosted by the Irvine Chamber of Commerce, a monthly networking breakfast connecting local businesses, civic leaders, and community organizations. They spoke with several business owners and organizational representatives unfamiliar with OCPA’s offerings. They are now included in the digital newsletter mailing list to receive regular information and updates on OCPA.  On March 20, I met with Placentia city staff to share an introduction to OCPA and answer initial questions. The meeting went well, and we will keep in touch to continue the conversation.
 OCPA staff and I have a meeting with the City Manager of Garden Grove to share an introduction to OCPA and discuss the process of becoming a member. This follows a meeting with the Mayor and conversations with City Council members interested in exploring the concept.
 OCPA has been approached to host the next meeting of the Santa Ana Chamber of Commerce Government Affairs Committee in May. We are excited for the opportunity to welcome Santa Ana business leaders to our office and, in turn, share more about the benefits of having community choice energy.

Customer Programs
 The Customer Programs team is planning for the third annual Bright Futures Grant that will be open soon. This grant will award $60,000 to local nonprofits, schools, and educators to support their renewable energy and Community Choice Aggregation (CCA) educational efforts. More details will be shared with the Board as they are solidified.  The Customer Programs team visited the Pathways of Hope food distribution center on March 27 to engage with community members and promote participation in the community needs assessment. We also coordinated with staff to promote the needs assessment on the Pathways of Hope website.
 While we await results from the Community Power Plan, we are researching EV charging programs with the goal of launching one before the end of the fiscal year. As a program is selected for execution, more details will follow.
 The Customer Programs team is also reviewing all residential solar + battery storage incentive programs offered to customers. The aim is to develop and deliver a program that will fill any gaps and encourage even more widespread adoption of residential solar + battery storage in our communities. Stay tuned for more information which will be announced soon.
 The Customer Programs team is securing Energy Efficiency Kits on the OCPA Marketplace, which will cost $50 for energy-saving supplies: a weatherstrip, wi-fi Bluetooth plug, two lightbulbs, and a power strip. We will make 500 kits at a discounted rate of $25 for all customers and 1,000 kits for free to CARE/FERA customers. We are working on promotional materials, including a mailer for CARE/FERA customers, to increase participation. We will keep the Board updated on the latest developments so you can share this opportunity with your constituents.

Human Resources Updates
Recruitments
OCPA recently launched recruitment for the Origination and Trading Manager, the next member of the Power Resources Team. Updates will be communicated along the way.

We are currently recruiting for two (2) interns. One (1) will support Regulatory and legislative Affairs, and the second will support the Communications and External Affairs team.

Training & Development
On April 3, 2025, Irvine Police Officer, Rick Gramer provided a very engaging Violent Intruder Training for OCPA staff. Officer Gramer did an excellent job highlighting the potential warning signs that may occur before an event happens and taught OCPA staff to be more aware. He also offered to continue engaging with us as we build out more protocols for various situations.

I have directed staff to keep working with Officer Gramer to ensure safety is top of mind for OCPA staff and our Board members.

Events & Stakeholder Outreach
The OCPA team has attended the following events and community meetings since our last Board meeting.

City Event & Meetings Date Time
Fullerton Fullerton Collaborative Monday, March 10,
2025 2:00 PM - 3:30 PM
Irvine Irvine State of the City Tuesday, March 11,
2025 4:30 PM - 6:30 PM
Fountain Valley Fountain Valley Rotary -
OCPA Presentation
Tuesday, March 11,
2025 5:30 PM -6:00 PM
Fountain Valley FV Government Affairs Thursday, March 13, 2025 8:00 AM -8:30 AM
Buena Park Buena Park Collaborative Thursday, March 13, 2025 10:00 AM - 12:00 PM
Anaheim OC Cal Cities Meeting Thursday, March 13,
2025 5:30 PM - 6:30 PM
Santa Ana Santa Ana Visionmakers -
Alvaro Nunez Friday, March 14, 2025 7:30 AM - 8:30 AM
Irvine Irvine Small Business
Diversity Network Friday, March 14, 2025 11:00 AM -12:00 PM Buena Park BP Community Academy Monday, March 17,
2025 6:00 PM - 7:00 PM
North Orange
County
North OC Chamber
Anniversary Celebration
Tuesday, March 18,
2025 10:00 AM - 10:30 AM
Irvine Woodbridge Block Party Saturday, March 22,
2025 9:30 AM - 12:30 PM
Buena Park Pop-Up Event Buena Park Tuesday, March 25,
2025 N/A
Irvine OCPA Staffers Luncheon Tuesday, March 25,
2025 11:30 AM - 1:00 PM
Regional Green Valley Community
Association Presentation
Tuesday, March 25,
2025 6:30 PM - 7:30 PM
Irvine Irvine Chamber - Good
Morning Irvine
Wednesday, March 26,
2025 8:15 AM - 9:30 AM
Regional Catalyst Convening Wednesday, March 26,
2025 8:30 AM - 5:00 PM
Regional
Pathways of Hope
Community Power Plan
Tabling
Thursday, March 27,
2025 N/A
Regional OCCOG 2025 Annual
Conference
Thursday, March 27,
2025 9:00 AM - 1:30 PM
Costa Mesa
Women of the Year
Celebration || Cottie Petrie-Norris
Thursday, March 27,
2025 5:30 PM - 7:00 PM
Costa Mesa ACCOC Women In
Leadership Awards Friday, March 28, 2025 11:00 AM -1:00 PM Regional Women In Green Breakfast Wednesday, April 2,
2025 8:00 AM - 10:00 AM
Buena Park Buena Park Korean Fair Saturday, April 5, 2025 All day Stanton Stanton Feasibility
Presentation Tuesday, April 8, 2025 5:00 PM - 8:00 PM
Irvine/Virtual
City of Irvine Sustainable
Rebates - What's New For
2025
Tuesday, April 8, 2025 6:00 PM - 7:00 PM
Buena Park City Councilmember Franco
Townhall
Saturday, April 12,
2025 10:00 AM - 12:00 PM
Irvine OCPA Pop-Up (Irvine) Saturday, April 12,
2025 12:00 PM - 3:00 PM
Anaheim OC Hispanic Chamber of
Commerce || Estrella Awards
Saturday, April 12,
2025 5:00 PM - 8:00 PM
We are looking forward to many opportunities to engage with the community and key stakeholders, including:

City Event & Meetings Date Time
Fullerton OCPA Pop-Up (Fullerton) Tuesday, April 15, 2025 4:00 PM - 7:00 PM Regional OCPA Presentation to Climate
Reality OC
Thursday, April 17,
2025 7:00 PM - 7:30 PM
Fountain Valley OCPA Presentation to FV
Community Foundation
Thursday, April 17,
2025 7:30 PM - 8:00 PM
Buena Park City of Buena Park Earth Day
and Spring Eggstravaganza Saturday, April 19, 2025 7:00 AM - 3:00 PM Irvine City of Irvine Earth Day Event Saturday, April 19, 2025 11:00 AM - 2:00 PM Fullerton Fullerton College Earth Week
2025 Monday, April 21, 2025 10:00 AM 1:00 PM
Irvine Irvine Rotary Presentation Wednesday, April 23,
2025 N/A
North Orange
County
North OC Chamber Business
Mixer in Stanton
Wednesday, April 23,
2025 12:00 PM - 2:00 PM
Irvine Good Morning, Irvine Saturday, April 26, 2025 8:00 AM - 8:30 AM Irvine Induction Cooking Workshop
and Demonstration
Wednesday, April 30,
2025 6:00 PM - 7:30 PM
Fullerton Fullerton Mayor's Prayer
Breakfast Friday, May 2, 2025 N/A
Irvine CicloIrvine Saturday, May 3, 2025 All day
Regional Radio Interview Tuesday, May 6, 2025 n/a
Attachments:

A) Non-Power Supply Contracts In Excess of $50,000 to Under $100,000 B) Buena Park Smart Choice Notification Mailer #2 (Change in Default Product) Orange County Power Authority
Non Power Supply Contracts In Excess of $50,000 to Under $100,000 Item No Vendor Term Contract Amount Brief Service Description Remark None
P.O. Box 54283
Irvine, CA 92619-4283
The Orange County Power Authority (OCPA) is developing a long-term plan for new energy and cost-saving programs – and it starts with learning what our communities need.

The Community Power Plan will:
• Identify community energy needs and priorities, like affordable ways to cool homes during heat waves
• Develop an action plan to address these priorities through new program offerings and partnerships with locally run programs We want your input.

Take the survey today and be entered into a
drawing for a chance to win a $250 gift card!
Scan the QR code or visit ocpower.org/future-programs/.

Thank you for supporting the renewable energy movement.

OCPA is proud to be your renewable energy provider.

Help Shape the Future
of Energy Programs.

Take the Survey Today!
Your renewable energy plan changed
in March 2025
If you were previously enrolled in OCPA’s 100% Renewable Choice energy plan, your plan was changed to Smart
Choice beginning in March 2025 on your regular meter read date. The Smart Choice plan provides 55% renewable plus 40% carbon-free energy. This shift allows OCPA to keep
rates consistent, ensuring renewable energy access and
affordability, while continuing to help achieve climate goals.

How this change affects former Buena Park
100% Renewable Choice customers
• In March 2025, Buena Park customers enrolled in
the 100% Renewable Choice plan were seamlessly
transitioned to the Smart Choice plan on their regular
meter read date.
• Customers already enrolled in the Basic Choice or Smart Choice plan did not experience a change, and remained
with their current renewable energy plan.
• Throughout this transition, customers remained on
their current rate schedule, subject to the rates and
terms of OCPA.

Buena Park is leading the clean energy movement by partnering with Irvine, Fullerton, and Fountain Valley to support renewable energy Basic Choice Plan
2025 Energy Mix
Costs 3% less than SCE's
equivalent generation rate
47%

RENEWABLE
ENERGY
Smart Choice Plan
2025 Energy Mix
+1 cent /kWh
more than Basic Choice
100% Renewable Choice Plan
+1.5 cents /kWh
more than Basic Choice
100%

RENEWABLE
ENERGY
55%

RENEWABLE
ENERGY
40% CARBON-FREE
ENERGY
Want to stay at 100% renewable energy?
Great news! Customers can stay enrolled in the 100% Renewable Choice plan by contacting OCPA’s customer support team– at (866) 262-7693 or [email protected].

Orange County Power Authority Board of DirectorsApril 14, 2025

Orange County Power Authority Board of Directors
April 14, 2025