AGENDA
ORANGE COUNTY POWER AUTHORITY
REGULAR MEETING OF THE BOARD OF DIRECTORS
Monday, November 10, 2025
4:30 p.m.
This meeting will proceed as an in-person meeting at 15310 Barranca Parkway, Suite 250, Irvine, CA 92618, and 303 W. Commonwealth Avenue, Fullerton, CA 92832. 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: 847 5813 9914
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. CLOSED SESSION
1. CONFERENCE WITH LEGAL COUNSEL - ANTICIPATED LITIGATION Initiation of litigation pursuant to Government Code Section 54956.9(d)(4):
One (1) case
8. 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 REGULAR BOARD MEETING OF OCTOBER 13, 2025 Recommended Action:
Approve as submitted.
2. MINUTES FOR THE SPECIAL BOARD MEETING OF OCTOBER 27, 2025 Recommended Action:
Approve as submitted.
3. COMMUNITY ADVISORY COMMITTEE REPORT
Recommended Action:
Receive and file.
4. LEGISLATIVE AND REGULATORY UPDATE
Recommended Action:
Receive and file.
5. STRATEGIC PLAN MONTHLY STATUS REPORT
Recommended Action:
Receive and file.
6. PUBLIC OUTREACH UPDATE FOR SEPTEMBER – OCTOBER 2025
Recommended Action:
Receive and file.
7. RATIFY RATES EFFECTIVE OCTOBER 20, 2025
Recommended Actions:
Ratify rates effective October 20, 2025.
9. 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. RECEIVE THE FINANCIAL AUDIT REPORT FOR THE FISCAL YEAR ENDED JUNE 30, 2025 AND 2024 FROM SORREN CPAs, P.C.
Recommended Action:
Receive the Year-End Financial Statements and Independent Auditor’s Report for the fiscal year ended June 30, 2025 and 2024 from Sorren CPAs, P.C.
2. APPROVE AMENDMENT NO. 4 WITH AM CONSERVATION GROUP, INC. (FORMERLY THE ENERGY FEDERATION, INC.)
Recommended Action:
Approve and authorize the Chief Executive Officer to execute Amendment No. 4 to the Professional Services Agreement with AM Conservation Group, Inc. (formerly The Energy Federation, Inc.) to increase the total contract not-to-exceed amount by $80,000, from $400,000 to $480,000, to support continued implementation of Orange County Power Authority’s Residential Marketplace Program through June 30, 2026.
3. BASIC SERVICES CHARGE IMPLEMENTATION BY SOUTHERN
CALIFORNIA EDISON
Recommended Action:
Receive and file.
10. 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.
11. 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.
MINUTES
REGULAR MEETING
BOARD OF DIRECTORS
ORANGE COUNTY POWER AUTHORITY
Monday, October 13, 2025
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, October 13, 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
Michelle Johnson, City of Irvine resident, commented via Zoom on items 9.1 and 9.4.
5. PUBLIC COMMENTS ON NON-AGENDA ITEMS
Nancy Colacino, City of Irvine resident, spoke via Zoom regarding SCE and OCPA.
6. DIRECTOR ANNOUNCEMENTS
None.
7. CLOSED SESSION
Recess to Closed Session
At 4:39 p.m., Chair Sonne called on General Counsel Norvell to recess the Board to Closed Session to discuss Items 7.1 and 7.2 on the Agenda. General Counsel Norvell announced the Board was recessing to Closed Session. The following Board members were present:
Go, Grandis, Jung, Mai and Sonne. Also present was Board Counsel Norvell.
1. CONFERENCE WITH LABOR NEGOTIATORS
Pursuant to Government Code § 54957.6
Agency designated representatives: Susan Sonne, Board Chair; Nicholaus Norvell, General Counsel; Unrepresented employee: Chief Executive Officer
2. CONFERENCE WITH LEGAL COUNSEL – ANTICIPATED LITIGATION Significant exposure to litigation pursuant to Government Code Section 54956.9(d)(2): One (1) potential case
Reconvene
At 4:41 p.m., the regular meeting of the Orange County Power Authority Board of Directors reconvened with the following present: Go, Grandis, Jung, Mai and Sonne.
General Counsel Norvell reported out of closed session that the Board met in Closed Session and discussed Items 7.1 and 7.2 as listed on the agenda, and there was no reportable action taken.
8. CONSENT CALENDAR
Director Jung made the motion, seconded by Vice Chair Mai to:
Approve consent calendar 8.1 – 8.6.
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
1. MINUTES FOR THE SPECIAL BOARD MEETING OF AUGUST 25, 2025 Action Taken:
Approved as submitted.
2. MINUTES FOR THE REGULAR BOARD MEETING OF SEPTEMBER 22, 2025
Action Taken:
Approved as submitted.
3. COMMUNITY ADVISORY COMMITTEE (CAC) REPORT
Action Taken:
Received and filed.
4. LEGISLATIVE AND REGULATORY UPDATE
Action Taken:
Received and filed.
5. STRATEGIC PLAN MONTHLY STATUS REPORT
Action Taken:
Received and filed.
6. TREASURER’S REPORT – FISCAL YEAR ENDED JUNE 30, 2025, AND Q2 2025 CHECK REGISTER
Action Taken:
Received and filed.
9. REGULAR CALENDAR
1. APPROVAL OF CONTINUED EVALUATION AND PREPARATION FOR
A POTENTIAL PREPAYMENT FINANCING STRUCTURE, INCLUDING
ENGAGEMENT OF A FINANCIAL ADVISOR AND PREPAY COUNSEL
Chief Financial Officer Tiffany Law presented this item.
Director Jung made the motion, seconded by Chair Sonne, to:
1. Approve the continued evaluation and preparation for a potential prepayment financing structure in early 2026;
2. Approve a service agreement with PFM Financial Advisors LLC for municipal financial advisory services, with a not-to-exceed amount of $300,000, contingent upon transaction completion and payable from bond proceeds, as outlined in Attachment 1;
3. Approve a service agreement with PFM Swap Advisors LLC for swap advisory services, with a not-to-exceed amount of $25,000, contingent upon transaction completion and payable from bond proceeds, as outlined in Attachment 2; and
4. Approve a legal service agreement with Chapman and Cutler LLP for prepayment and disclosure counsel, with a not-to-exceed amount of $300,000, contingent upon transaction completion and payable from bond proceeds, as outlined in Attachment 3.
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
2. 2025 TRACKING SURVEY RESULTS
Director of Communications and External Affairs Jacquie Henderson and Tom Patras with EMC Research Inc. presented the item. They presented a PowerPoint presentation showing a survey conducted among registered voters in Buena Park, Fullerton, Fountain Valley, and Irvine.
Action Taken:
Received and filed.
3. SECOND AMENDMENT TO CHIEF EXECUTIVE OFFICER
EMPLOYMENT AGREEMENT
General Counsel Nicholaus Norvell presented the item.
Chair Sonne made the motion, seconded by Director Jung, to:
Approve the Second Amendment to Chief Executive Officer Employment Agreement with Joseph Mosca; providing for a 5% adjustment to base salary; and an extension of 2 years to the employment term through November 12, 2027.
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
4. CONSIDER EARLY PAYDOWN OPTIONS FOR IRVINE CAPITAL LOAN CEO Mosca and CFO Law presented options for early repayment of the Irvine Capital Loan.
Action Taken:
Director Jung made the motion, seconded by Chair Sonne, to select Option 1 (Prepay $750,000 (plus Accrued Interest) by June 30, 2026) on the schedule listed below and direct the CEO to initiate repayment as soon as possible, without restructuring the loan agreement.
Ayes: Chair Sonne, Vice Chair Mai, Director Jung,
Director Grandis, Director Go
Noes: None
Absent: None
10. STAFF REPORT
CEO Joe Mosca said he provided his full staff report in the agenda packet. He announced that the next Board meeting would be held on Monday, November 10, 2025, at 4:30 p.m.
CEO Mosca recognized two staff members celebrating their work anniversaries: CFO Tiffany Law and Procurement Analyst Aracely Cardona.
11. ADJOURNMENT
There being no further business to come before the Board, Chair Sonne adjourned the October 13, 2025, Orange County Power Authority Board Regular meeting at 6:09 p.m.
Chair Sonne noted that the next Orange County Power Authority Board Regular meeting will be held on Monday, November 10, 2025, at 4:30 p.m.
Submitted by:
Lisette Chel Walker, Interim Board Clerk
MINUTES
SPECIAL MEETING
BOARD OF DIRECTORS
ORANGE COUNTY POWER AUTHORITY
Monday, October 27, 2025
1. CALL TO ORDER
Chair Sonne called to order the Special Meeting of the Orange County Power Authority Board of Directors at 4:30 p.m. on Monday, October 27, 2025.
2. PLEDGE OF ALLEGIANCE
Director Grandis 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
Director Jung announced that he is participating in today's meeting remotely under Brown Act teleconferencing provisions due to family caregiving needs that prevent him from participating in person. He noted that there is no one under 18 or anyone else in the room with him.
4. PUBLIC COMMENTS ON AGENDA ITEMS
None.
5. REGULAR CALENDAR
1. APPROVE RESOURCE ADEQUACY AGREEMENT WITH ATHOS
STORAGE, LLC
Director of Power Resources Louis Ting, presented this item.
Moved by Director Jung, seconded by Director Grandis to:
Authorize the CEO to execute a Resource Adequacy (RA) Agreement between OCPA and Athos Storage, LLC for a fifteen (15)-year term agreement to provide 52 megawatts (MWs) of nameplate capacity, equating to 38 MWs of Net Qualifying Capacity (NQC), which will satisfy a significant portion of OCPA’s supplemental mid-term reliability procurement obligations based on the California Public Utilities Commission’s (CPUC) applicable Decision.
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
6. ADJOURNMENT
There being no further business to come before the Board, Chair Sonne adjourned the October 27, 2025, Orange County Power Authority Board Special meeting at 4:58 p.m.
Chair Sonne noted that the next Orange County Power Authority Board Regular meeting will be held on Monday, November 10, 2025, at 4:30 p.m.
Submitted by:
Interim Board Clerk Lisette Chel Walker
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.3
-------------------------------------------------------------------------------------------------------------------- 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 REPORT
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☐ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☒ Not Applicable:
RECOMMENDED ACTION(S)
Receive and file.
BACKGROUND
On Monday, November 3, 2025, at 6:00 p.m., the Community Advisory Committee (CAC) held its regular monthly meeting. The agenda featured four informational items: an overview of the Orange County Power Authority’s (OCPA) Diversity, Equity, and Inclusion (DEI) practices, a report on OCPA’s participation in the Sustain SoCal 16th Annual Energy Event, a discussion to initiate development of the 2026 CAC Workplan, and an update on upcoming public engagement efforts scheduled for November and December. The meeting offered committee members the opportunity to provide input on strategic priorities, strengthen understanding of regional energy issues, and reinforce OCPA’s commitment to equitable outreach, inclusive programming, and community collaboration.
DISCUSSION/ANALYSIS
The CAC regular meeting on November 3, 2025, included the following presentations and updates:
Orange County Power Authority Diversity, Equity and Inclusion Practices Staff provided a substantive overview of current DEI efforts aimed at making clean energy access more inclusive and responsive to community needs. The update focused on expanding participation in income-qualified programs, building partnerships with culturally representative organizations, and improving multilingual outreach across OCPA’s service area. Staff also shared recent steps to incorporate equity into hiring, procurement, and program design. Committee members were asked to provide input on emerging needs and help shape future efforts to ensure all communities benefit from OCPA services.
Report on Sustain SoCal 16th Annual Energy Event
Staff and committee members shared highlights from the Sustain SoCal 16th Annual Energy Event, held October 16, 2025, at the UCI Beall Applied Innovation Center. The event convened regional stakeholders to explore trends in energy policy, technology, and innovation. OCPA participated in three panels, contributing expertise on procurement strategies, building efficiency, and cleantech education. Contributing OCPA representatives included CEO Joe Mosca, Community Engagement Manager Linda Kraemer, and CAC Member Ralph Futch serving as panelists. 2026 Update to Community Advisory Committee Workplan
Staff initiated discussion on the development of the 2026 CAC Workplan by reviewing the structure and focus areas of the 2025 plan. Committee members were asked to provide input on future priorities, with feedback centering on expanded outreach to underserved communities, stronger youth and workforce development initiatives, and flexible programming aligned with Board goals. The discussion emphasized the CAC’s advisory role and the importance of adapting to evolving community needs. A revised draft will return in December for final review ahead of being provided to the Board.
Public Engagement for November and December 2025
Staff provided an overview of OCPA’s community engagement calendar for November and December, including Veterans Day commemorations, holiday events, cultural festivals, and business galas in all member cities. These events are designed to enhance visibility, educate customers, and promote renewable energy options. Committee members were encouraged to volunteer and help strengthen OCPA’s public presence during the holiday season.
Updates from Staff
OCPA staff provided a comprehensive update covering recent communications, community engagement, and program developments. Communications efforts continue to show strong results, with newsletter subscriptions surpassing 6,300 recipients, marking a 51% increase year-over-year, and notable growth across all social media platforms. A recent blog by Dr. Faisal Qazi, titled “Climate Change Is Messing with Your Mind,” was featured prominently, addressing the health impacts of pollution and climate change on Orange County residents.
Programmatically, the Community Power Plan has moved into its evaluation phase, with an expert panel reviewing eleven program concepts for feasibility and alignment with community needs. High-priority initiatives include electrification for renters, demand response for small businesses, and targeted energy efficiency programs. The Charge@Home EV Charger Rebate Program officially concluded after distributing over 200 chargers, while the Energy Efficiency Kit Program nears full capacity with almost 1,500 kits sent to customers.
In community engagement, staff reflected on a successful presence at the Irvine Global Village Festival, where OCPA connected with thousands of residents in one of the county’s most diverse community celebrations. Additional outreach included the Fullerton OctoBOOfest, the Huntington Valley Boys & Girls Club Gala, and an OCPA Day of Service at the Second Harvest Food Bank.
OCPA also received external recognition through two awards: the California Green Business Innovator Award and the ABAOC Energy Visionary Award, reinforcing its leadership in sustainability and community impact.
FISCAL IMPACT
None
ATTACHMENT(S)
None
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.4
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Steven Halligan, Regulatory and Legislative Manager Matt Chill, Regulatory Analyst
Approved By: Joe Mosca, Chief Executive Officer
Subject: LEGISLATIVE AND REGULATORY UPDATE
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☐ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☒ Raise Awareness of Community Energy & Advocate for Our Customers:
☐ Not Applicable:
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 of high priority, active proceedings is provided below.
Staff have identified 120 bills (Attachment A – 2025 Orange County Power Authority Bill Tracker) to analyze and monitor. 79 of the bills have failed to meet statutory deadlines to continue moving forward, and 11 bills have been flagged as high priority. Staff track bills in several categories, including but not limited to affordability, building standards, energy sources, CEQA, transmission, decarbonization, demand forecasting, electrification, IOU rate cases, oversight, and workforce development.
ANALYSIS AND DISCUSSION
Legislative Update
The California Legislature adjourned on September 12. Of the 120 bills OCPA has been tracking throughout the year, 41 were passed by the legislature. The Governor had until October 12 to sign or veto bills. Of the 11 high priority bills OCPA has been tracking; the Governor signed nine and vetoed two. One of the bills vetoed was AB 527 (Papan), a bill supported by CalCCA related to CEQA exemptions for geothermal exploratory projects. The reasoning for the veto was that several changes to these types of projects were made with AB 1359 (Papan) last year and the result of those changes has not been fully understood yet. The second high priority bill that was vetoed was SB 541 (Becker). CalCCA opposed this bill. The reasoning for the veto was that the bill was “largely redundant and, in some cases, disruptive of existing and planned efforts by the CPUC, CEC and CAISO to maximize the cost—effective potential of electric load-management strategies”.
Staff are currently working on scheduling meetings with Orange County legislators during the winter recess and for the CalCCA Sacramento Lobby Day in February 2026. Staff are beginning the process to update the OCPA Legislative and Regulatory Policy Platform for 2026.
Regulatory Update
Power Charge Indifference Adjustment (PCIA) Proceeding – R.25-02-005 Background: On February 11, 2025, the CPUC issued an Order Instituting Rulemaking (OIR) to initiate a new proceeding related to the Power Charge Indifference Adjustment (PCIA). The proceeding will consist of two tracks. The first track will be an expedited track focused on modifications to the Market Price Benchmark (MPB). Track two may consider several issues, including a review of the revisions to the MPB, consideration of ERRA-specific implementation guidance for RA program changes, changes to Bundled Procurement Plan directions, and consideration of improved PCIA and ERRA mechanisms to reduce rate volatility. The CPUC has identified four objectives of the proceeding:
1. Consider and identify reasonable improvements to existing ERRA and PCIA rules, mechanisms, and processes to ensure best practices in utility forecasting and other procurement plan activities;
2. Identify ways to mitigate and respond to rate volatility, whether resulting from market conditions or ratemaking constructs;
3. Best ensure indifference among bundled and departed customers;
4. Provide policy guidance to ensure that individual utility forecast ratemaking proceedings function as efficiently and consistently as possible.
The CPUC adopted the Track 1 modifications to the RA MPB in Decision (D.25-06-049). These changes include 1) combining the Local, System, and Flex RA into a single MPB; 2) using a three-year and four-year lookback period for RA transactions in calculating the forecast and true-up RA MPB, respectively; and 3) applying the new methodology to the 2025 true-up RA MPB.
On July 28th, 2025, CalCCA filed an Application for Rehearing (AfR) on Track 1 of the proceeding. This AfR addressed CCA opposition for the CPUC’s engagement with retroactive ratemaking in the MPB calculation methodology for the 2025 ERRA True Up, which is prohibited under Section 728 of the Public Utilities Code.
Update: Now that the deadline for a decision on the PCIA Track 1 Application for Rehearing has passed, it is deemed denied by the CPUC. OCPA with CalCCA are exploring the next steps.
Integrated Resource Planning – R.20-05-003 and R.25-06-019 Background: On April 29, 2025, the CPUC released its long-awaited Reliable and Clean Power Procurement Program (RCPPP) Staff Proposal through an ALJ Ruling. The CPUC’s goal in RCPPP is to give LSEs a more predictable regulatory framework to procure their share of the resources needed to meet electric system reliability and GHG emission reduction goals at least cost. The Staff Proposal includes a reliability framework and GHG reduction framework, each with the following key design elements: need determination, need allocation, compliance, and enforcement. The Staff Proposal proposes two options for the reliability framework. The first requires LSEs to demonstrate procurement of new and existing resources. The second requires LSEs to demonstrate procurement of new resources plus adopt a multi-year RA framework for existing resources. The Staff Proposal also proposes a clean energy standard framework for GHG reduction. Finally, the Staff Proposal includes a proposal to allocate CPE procurement via credits to LSEs to show in RCPPP filings.
The CPUC issued an OIR on July 2, 2025, for a new IRP proceeding to continue IRP activities.
Update: A Ruling on the 2026-2027 Transmission Planning Process (TPP) portfolios and a near-term procurement needs assessment, and potential order was released on September 30, 2025.
CalCCA submitted comments on the Ruling on October 22, 2025, recommending the CPUC update framework for TPP portfolio selection to align the base case with that of least regrets and modifying the base case to use more conservative load assumptions given significant uncertainty with data center and electrification demand in the 2024 IEPR Demand Forecast. Over-procurement and affordability implications are key to CalCCA here. Other key CalCCA priorities within comments are:
• Maintaining LSE autonomy with power procurement instead of through a Central Procurement Entity;
• Minimizing ad hoc procurement orders and instead focusing on developing the RCPPP for predictable procurement periods and processes; but if ad hoc procurement orders are released, they should:
o Order procurement of generic capacity instead of technology- or attribute-specific orders;
o Only issue an order for 2,000 MW in 2029-30 and 2,000 MW in 2031-32, and then reevaluate whether an additional 2,000 MW of procurement is needed in Q1 of 2028;
o Ensure LSE’s net positions aren’t revealed to potential sellers o Refrain from ordering procurement within local capacity areas CalCCA plans to submit reply comments in line with these priorities which are due on October 31, 2025.
The CPUC approved Resolution E-5426 at the October 30, 2025, CPUC voting meeting.
Resolution E-5426 adopts a citation program for enforcing compliance with filing deadlines and reporting requirements for the IRP proceedings. The Commission delegates to Staff the authority to issue citations and levy fines for failure to comply with any mandatory filing deadlines and reporting requirements in IRP proceedings, including planning and procurement tracks. LSEs are given at least seven calendar days to correct issues when given a “Correction Notice.” Citations can be given without a Correction Notice for failure to comply with a Filing Deadline. This penalty is $1,000 per filing plus $500 per day for the first ten days the Filing was late and $1,000 for each day thereafter, until the violation is corrected. A Correction Notice must be given for failure to comply with Reporting Requirements. The penalty amount is the same but begins after the Correction Notice period of at least 7 calendar days.
This replaces the citation program established by Resolution E-5080, which enabled fines for non-compliance with mandatory filing deadlines and reporting requirements for individual IRPs.
CAISO 2025-26 Transmission Planning Process (TPP)
Background: Each year, the CAISO conducts its Transmission Planning Process (TPP) to identify potential system limitations as well as opportunities for system reinforcements that improve reliability, efficiency, and California’s ability to meet policy goals. The TPP results in the CAISO publishing its Transmission Plan and recommends transmission projects for CAISO management or board approval.
The California ISO 2025-2026 transmission planning cycle involves key stakeholder activities from 2025 through early 2026. Each year, the ISO conducts its transmission planning process to identify potential system limitations as well as opportunities for system reinforcements that improve reliability and efficiency. The transmission planning process core product is the ISO Transmission Plan, which provides an evaluation of the ISO control grid, examines conventional grid reliability requirements and projects, summarizes key collaborative activities and provides details on key study areas and associated findings.
Update: CalCCA commented on preliminary reliability results in CAISO’s TPP process on October 9, 2025. Comments focused on increasing transparency around what is driving transmission system upgrades or other mitigations (e.g., data center deployment, electrification) and increasing collaboration on appropriate criteria to adequately consider data center load within TPP, especially focusing on accurately forecasting the certainty of load materializing.
Distributed Energy Reosurce Interconnections (R.25-08-004) Background: The Commission opened this rulemaking to consider refinements to the interconnection of distributed energy resources (DER) under Electric Tariff Rule 21 (Rule 21).
The OIR can be found here.
Update: CalCCA filed Opening Comments on the OIR on October 20. The recommended comments:
• Modification of Scoping Item 7 regarding the communications and interoperability of DERs to include consideration of costs and standards for communications and interoperability of non-IOU-owed DER and DER Management Systems (DERMS), which will help enable non-IOU DER participation within VPPs and help mitigate local constraints;
• Modify Scoping Item 2 regarding interconnection processes to include the consideration of financial penalties for IOU noncompliance with interconnection timelines; • Divide the proceeding into two phases: first to address process improvements and technical requirements, and second to address cost issues;
• Consider workshops to address updates to Electrical Independence Tests, interconnection timeline compliance and penalties, cost allocation and fees, and communications and interoperability standards and costs for non-IOU-managed DER and DERMS. • Coordinate this proceeding with the OIR to Enhance DR in California, to the extent it addresses relevant issues, including those considered by the CAISO DDEMI WG.
Reply Comments are due November 10.
Climate Credit Order Instituting Rulemaking (R.25-07-013) Background: The Commission opened this rulemaking to consider refinements to the Climate Credit. The Preliminary Scope Memo includes the following issues to be considered:
• Eligibility. Should the Commission modify electric and natural gas Climate Credit eligibility criteria for residential and small business customers? • Should the Commission modify the implementation of the California Industry Assistance for EITE customers?
• How and When to Distribute. How and when should Cap-and-Trade proceeds be distributed to eligible residential, small business, and EITE customers each year? • Customer Messaging. If changes are made to the Climate Credit allocation or distribution, how should these changes be communicated to customers?
Update: Reply comments were submitted on October 14. CalCCA supported including scoping items from (1) the IOUs collectively on clear, cost-effective, and administratively simple climate credit messaging and (2) PG&E about developing a formal process around master meters to ensure routine updates to tenant configuration such that all customers receive fair and accurate payment of their Climate Credit. CalCCA opposes SDG&E’s recommendation about bifurcating Climate Credit eligibility and distribution timeline, arguing that the two topics are inherently intertwined and should be considered together.
PG&E and SDG&E oppose TURN’s and CalCCA’s proposal of a publicly accessible climate credit tool due to it likely being overly complex and costly. It instead proposes a fit-for-purpose analysis using standardized modeling data.
NRDC’s Reply Comments push back against SoCalGas and PG&E, which seek to explore the modification of changing distribution of natural gas climate credits to customers during high gas bill months. NRDC does not want to send misleading price signals that could cause customers to maintain gas usage for longer or purchase new gas equipment.
A Scoping Memo and Ruling is due by December 15.
Diablo Canyon Forecast (A.25-03-015)
Background: PG&E filed A.25-03-015 (DCPP Forecast) on March 28, 2025, to recover its costs to support the extended operation of DCPP from January 1, 2026, through December 31, 2026, and for approval of its planned expenditures of the 2026 Volumetric Performance Fees. The proceeding addresses the allocation of RA and GHG-free energy attributes associated with DCPP’s extended operations.
Update: PG&E submitted its October Update Testimony on October 9, 2025. CalCCA submitted comments on October 20. The Comments identify two numerical errors made by PG&E. The first relates to PG&E’s off-peak energy MPB value, which was lower than the correct value by about ten cents per MWh, leading to understated forecast DCPP generation revenue by $728,958. The second error relates to PG&E’s accounting adjustment used to true up the monthly accrual entries for the VPF between January and August 2025. PG&E misallocated a piece of VPF funding to all LSEs rather than to just PG&E territory. This piece is paid by only PG&E customers, which is why it should not be allocated to all LSEs. CalCCA filed a Reply Brief in the DCPP Forecast case on October 22, 2025, which responded to parties that supported using alternatives to the RA MPB for valuing substitution capacity costs for DCPP in 2026. CalCCA, PG&E, and the CPUC have all supported use of the RA MPB, which is more administratively simple to implement and allows better consistency with other RA cost forecasts that use the RA MPB.
Demand Response Order Instituting Rulemaking (R.25-09-004) Background: On September 18, the CPUC voted to open a new proceeding regarding Demand Response. This Order Instituting Rulemaking (OIR) seeks to evaluate and enhance the consistency, predictability, reliability, and cost-effectiveness of demand response resources. The Commission will accomplish this enhancement by updating its demand response guiding principles, policies, and data system and process requirements.
• They hope to address the following issues in this proceeding: "In this rulemaking, we intend to re-evaluate several key Commission demand response policies, including our dual participation policy, valuation methodologies, evaluation metrics, and others. We will evaluate these topics in this rulemaking and consider amendments to ensure continued alignment with the evolving demand response landscape and the state’s policy goals." AND "demand response policies related to resource adequacy and CAISO market integration require further consideration, such as the alternative supply-side demand response qualifying capacity methodology, the proxy demand resource bid cap, and the implementation of the slice-of-day framework."
• With the OIR they have released a document of "Guiding Principles for Demand Response in California." They have identified four guiding principles:
ο Demand response shall be predictable and reliable in order to be incorporated into the State’s forecasting and planning frameworks and depended on in both system planning and real-time grid operations.
ο Standard and consistent valuation methodologies and evaluation metrics, along with standardized data formats, communication protocols, and data access processes, shall be adopted to enhance the transparency, comparability, and effectiveness of demand response resources and programs across the State. ο Demand response resources in California shall be cost-effective and demonstrate clear value by delivering measurable systems and ratepayer benefits. ο Demand response resources and programs shall continue to support California’s energy and environmental goals and prohibit the use of fossil fuel generation except under strictly limited conditions.
Update: Comments on the OIR are due November 3, and Reply Comments are due November 17.
Disconnections (R.18-07-005)
Background: This OIR was opened in 2018 and addresses rising disconnection rates from customer nonpayment of electric bills. After issuing several decisions instituting various rules and programs, Phase 2 is now addressing issues to further prevent disconnections. CalCCA has been successful in ensuring CCA customers can participate in the various programs, including the AMP and the PIPP, with CCA recovery of costs identical to the IOUs’ recovery of costs.
CalCCA has also been successful in obtaining the proportional allocation of payment on past-due bills between IOUs and CCAs (i.e., suspension of the “waterfall” method).
Phase 2 was amended via an Amended Phase 2 Scoping Ruling to specifically address implementation of SB 1142, protections for customers under extreme weather events, and disconnection rate caps.
Update: The ALJ issued a Ruling on October 13, 2025, requesting IOU and party comments on procedural pathways for the Percentage of Income Payment Program (PIPP) Pilot, the Arrearage Management Plan Program (AMP), and the Community-Based Organization (CBO) Pilot. The main feedback solicited was about whether the programs/pilots should continue and any other suggested modifications.
The ALJ granted the extension request for comments on the Ruling on October 21, 2025.
Comments on the OIR are now due November 14, 2025, with Reply Comments due December 5, 2025.
Interconnection Process Enhancements (IPE) 5.0
Background: The 2023 Interconnection Process Enhancements (IPE) initiative is focused on enhancing coordination of resource procurement and interconnection, resource planning and transmission planning to achieve state reliability and policy needs. In the 2023 IPE initiative, the CAISO intends to consider more fundamental changes to the Generator Interconnection and Deliverability Allocation Procedures than were considered in IPE 2021.
With IPE 2023, intake scoring and ranking processes are leveraged to determine which projects are included in cluster studies for determining Transmission Plan Deliverability (TPD) allocation.
The scoring and ranking processes led to an overall 73% reduction in the number of submissions for cluster 15 projects.
IPE 5.0 is to address commitments the ISO made during IPE 2023, where the ISO made foundational changes to its interconnection procedures, which were approved by FERC. IPE 5.0 seeks to further enhance the interconnection process, but not nearly as substantially as IPE 2023.
Update: Staff attended Stakeholder Meeting on Draft Final Proposal on October 20, 2025. CalCCA is planning to submit comments on the Draft Final Proposal by the deadline, November 3, 2025.
Updates from the IPE 5.0 Draft Final Proposal as it currently stands will (in addition to other smaller changes):
• Make minor updates to the intake scoring and ranking rubric that largely seek to reduce the extent to which large projects are able to dominate the Commercial Interest section of the scoring process by instituting a project size cap (max of 500 MW); • Require distribution system projects to also go through this same intake scoring and ranking process;
• Allow Operational Energy Only projects in cluster 15 and beyond to seek deliverability through this process as part of the Commercial Allocation Group; o This originated from a CalCCA proposal. However, the current language in the Draft Final Proposal differs from CalCCA’s proposal in that any Energy Only project that is found to be behind a transmission constraint will be ineligible for TPD. The project will not be able to fund network upgrades to enable the project to receive TPD either.
o Introduce protocols for removing stagnant projects from the interconnection queue if they have been in-queue for seven years (plus potentially three years of extensions); and
o Result in projects that are not within CAISO but impact CAISO to enter the queue lower than projects within existing cluster studies.
Integrated Energy Policy Report Update 2024 (25-IEPR-01 to 06) Background: Dockets 24-IEPR-01, 02, and 03 are the proceedings to develop the 2024 IEPR Update, focusing on electricity resource plans, the electricity demand forecast, and the feasibility of wave and tidal energy per SB 605. Dockets 25-IEPR-01 through 06 focus on the Electricity Resource Plan, Electric and Gas Demand Forecast, Hydrogen, Load Shift Goals, and Accelerating Interconnection and Energization.
Update: The CEC adopted the Final 2024 IEPR Update at the October 8, 2025, CEC Business Meeting. CalCCA attended the CEC Business Meeting to provide its support for establishing a new track to consider large load forecasting issues. Staff attended the DAWG Working Group meeting on October 30, 2025, where technical aspects of the IEPR forecasts were discussed.
Events, Workshops, and Meetings
During the past month, staff attended several events, workshops, and meetings. These included:
• CalCCA Regulatory Policy meetings – including several tiger team meetings covering PCIA, POLR, IRP, Large Load, Distribution, and RA proceedings • Weekly CalCCA Legislative Policy meetings - including several Tiger teams such as Infrastructure, Building Decarbonization, Zero-Emission Vehicles, Autonomy, and Affordability
• CalCCA Federal Policy meetings
• CalCCA Monthly CAISO meeting
• Stakeholder Policy meetings
• CAISO Interconnection Process Enhancements (IPE) 5.0 Draft Final Proposal Stakeholder Meeting
• CalCCA Regulatory Directors meeting
• CalCCA Compliance meetings
• CEC Business meeting
• Pathways Stakeholder meetings
• Joint CCA SCE ERRA Forecast Review and Phase 1 GRC meetings • CAISO stakeholder meetings
• CPUC Pre-Hearing Conference for IRP
• CEC EPIC Symposium
• CEC Demand Analysis Working Group (DAWG) Meeting
• Coordinated Holistic Orchestration of Inverter-based Resources (CHOIR) Pre-Application Workshop
• CARB Public Workshop on Potential Amendments to the Cap-and-Invest Program • CPUC Voting Meeting
• CPUC Workshop on Unforced Capacity Accreditation for Storage and Dispatchable Thermal Resources
• CPUC Workshop on Long-Duration Energy Storage (LDES) and Pumped Storage Hydro Accreditation
FISCAL IMPACT
None
ATTACHMENTS
Attachment A – 2025 Orange County Power Authority Bill Tracker Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
High Priority
Bill # Author Title Category Summary Status Position
AB 527 Papan California Environmental
Quality Act: geothermal
exploratory projects
Geothermal This bill provides that “geothermal exploratory project” includes, among other things, equipment and activities necessary to establish interconnectivity between wells and reservoirs. The bill would exempt geothermal exploratory projects for which the county is the lead agency that meet specified conditions from CEQA. The bill would require the lead agency, at least 30 days before the making the determination to approve or carry out a change in use pursuant to this exemption, to post a written notice on its internet website and at the project site. Because the exemption would apply to projects where the county is the lead agency and the county would be required to determine if a project qualifies for this exemption, the bill would impose a state-mandated local program.
Vetoed by Governor CalCCA
Support
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.
Approved by Governor
on October 6
CalCCA
Support
AB 825 Petrie-Norris Independent System
Operator: independent
regional organization
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 to use voluntary energy markets governed by an independent regional organization, only if specified requirements are satisfied.
Approved by Governor
on September 19
Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
High Priority
AB 1207 Irwin Climate change: market-based compliance
mechanism: price ceiling
Cap-and-Trade Extends Cap and Invest to January 1, 2046. The bill would require that moneys generated from the sale of additional allowances at the price ceiling be deposited into the California Climate Mitigation Fund, which the bill would create in the State Treasury. The bill would require moneys in the California Climate Mitigation Fund be available, upon appropriation by the Legislature, for purposes of providing direct rebates and investments to reduce household energy costs. This bill would require the credits provided to residential customers to be provided on the bills of those customers in no more than 4 high-billed months of each year to maximize customer electric bill affordability or as otherwise directed by the commission to address extreme, unforeseen, and temporary circumstances. This bill would make the 15% allocation for clean energy and energy efficiency projects inoperative on July 1, 2026. The bill would require, from July 1, 2026, to January 1, 2031, inclusive, 5% of those revenues be remitted to the State Treasury for deposit into the California Transmission Accelerator Revolving Fund and be available to California Infrastructure and Economic Development Bank for purposes of the California Transmission Accelerator Revolving Fund Program.
Approved by Governor
on September 19
SB 57 Padilla Electrical corporations:
data centers: report
Data Centers This bill would authorize the commission to assess the extent to which electrical corporation costs associated with new loads from data centers result in cost shifts to other electrical corporation customers provided. The bill would require the commission to submit an assessment completed pursuant to that authorization to the relevant policy committees of the Legislature and to publicly post a copy of the assessment on the commission’s internet website on or before January 1, 2027.
Approved by Governor
on October 11
Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
High Priority
SB 254 Becker Energy Affordability • Includes an $18 billion replenishment of a wildfire fund to be split between shareholders and ratepayers (not to be used for Eaton Fire).
• Includes both a $6 billion limit on the wildfire prevention costs utilities can pass along to ratepayers and the creation of a state loan program for building new transmission lines. • Requires the Energy Unit within Go-Biz to establish a Transmission Infrastructure Accelerator (accelerator) to develop a financing and development strategy for eligible transmission projects receiving California Transmission Accelerator financing and sunsets this authority January 1, 2031.
Requires the accelerator, before December 31, 2026, to coordinate the state’s ongoing activities related to transmission planning and development and to ensure accelerator projects meet specified criteria
o Accelerator will receive funding from Cap & Invest
• Extends the date by one year, to June 30, 2030, that a person proposing an eligible facility is authorized to apply to the CEC for certification within the AB 205 “Opt-in” program. • Allows the CA Consumer Power and Conservation Financing Authority program to finance, own, lease, and sponsor transmission projects.
• Allows the CPUC to consider tying energization timelines to executive compensation.
Approved by Governor
on September 19
CalCCA
Support
Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
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.
Approved by Governor
on October 6
CalCCA
Support if
Amended
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.
Approved by Governor
on October 1
CalCCA
Support
Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
High Priority
SB 541 Becker Electricity: load shifting Dynamic Rates This bill would require the Energy Commission, in consultation with specified entities, to analyze the cost-effectiveness of specific load and programs and other types of load-shifting interventions and identify both the approximate amount of load shifting and the cost-effectiveness of each type of load-shifting intervention in the next update to the biennial integrated energy policy report after January 1, 2027, as provided. The bill would require the Energy Commission, as part of each integrated energy policy report, to estimate each retail supplier’s load-shifting potential, giving consideration to certain factors, as specified. The bill would require the Energy Commission, on or before July 1, 2028, and biennially thereafter, to analyze and publish the amount of load shifting that each retail supplier achieved in the prior calendar year.
Vetoed by Governor CalCCA
Oppose
SB 707 Durazo Open meetings: meeting
and teleconference
requirements.
Brown Act This bill would, until January 1, 2030, require an eligible legislative body, as defined, to comply with additional meeting requirements, including that, except as specified, all open and public meetings include an opportunity for members of the public to attend via a 2-way telephonic service or a 2- way audiovisual platform, as defined, and that the eligible legislative body take specified actions to encourage residents to participate in public meetings, as specified. This bill would revise and recast the above-described definition of a legislative body and would specify that advisory committees with a continuing subject matter jurisdiction or a fixed meeting schedule, as specified, are legislative bodies. This bill would also require the agenda for each meeting of an eligible legislative body, as defined, to be translated into all applicable languages. The bill would define “applicable languages” to mean languages spoken jointly by 20% or more of the population in the city or county in which the eligible legislative body is located that, among other things, speaks English less than “very well,” as specified, and except as provided.
Approved by Governor
on October 3
Orange County Power Authority
2025 California Bill Tracker (Updated 10/23/2025)
High Priority
SB 840 Limon and McGuire Greenhouse gases:
Greenhouse Gas
Reduction Fund: studies
Cap-and-Trade This bill would state the intent of the Legislature to direct specific percentages of the revenues deposited into the Greenhouse Gas Reduction Fund to individual funds dedicated to funding clean transportation, housing and community investment, clean air and water, wildfire prevention and resilience, agriculture, clean energy, and climate-focused innovation. The bill would make the continuous appropriations from the fund inoperative on July 1, 2026. The bill would, beginning with the 2026–27 fiscal year, allocate moneys in the fund in a specified priority and would continuously appropriate a certain amount of moneys in the fund for certain purposes.
Approved by Governor
on September 19
Medium Priority
Bill # Author Title Category Summary Status
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 and other zero-emission vehicle fueling infrastructure, 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 designate 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.
Approved by Governor on
October 6
AB 44 Schultz Energy: electrical
demand forecasts.
Demand Forecasts This bill would require the commission, on or before December 1, 2026, and in consultation with load-serving entities and resource aggregators, to define and publicize methodologies for load modification protocols by which a load-serving entity may reduce or modify its electrical demand forecast upon aggregated system operation of behind-the-meter load modifying technologies and programmatic measures deemed to reliably reduce or modify the load-serving entity’s electrical demand, as specified.
Vetoed by Governor
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.
Approved by Governor on
October 1
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. The bill would require each public utility, as a part of its general rate case, to report all transactions performed pursuant to this exemption, enumerated by date, value, location, and party.
Approved by Governor on
October 1
Medium Priority
AB 615 Davies Power facilites:
emergency response and
action plan
Power Facilities This bill would require that those applications also contain emergency response and action plans, to be paid for by the applicant, that incorporate 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 applications for an energy storage system also contain emergency response and action plans, to be paid for by the applicant, and that the plan plans include analysis and feedback from the local emergency management agencies as to whether the proposed facilities require supplemental first responder capabilities and meet National Fire Protection Association 855 Standard as it relates to setbacks, as specified.
Vetoed by Governor
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.
Approved by Governor on
October 3
AB 738 Tangipa and
Patterson
Energy: building
standards: photovoltaic
requirements
Building Standards This bill would, until January 1, 2028, 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.
Vetoed by Governor
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 virtual power plant deployment plan. The bill would require the Energy Commission, in developing the plan, to take certain actions, and would require that the plan meet specified requirements. The bill would require the plan adopted pursuant to these provisions to be included in the above-described integrated energy policy report.
Vetoed by Governor
Medium Priority
AB 777 Rodriguez Food assistance:
disasters: utilities.
Data Sharing This bill would require electrical corporations, gas corporations, water corporations, and local publicly owned electric utilities to respond to data requests from the department, and would require the commission to establish any memoramdum memorandum of understanding or other data sharing agreements agreement necessary to direct those utilities to provide data to the department to maximize food assistance, as provided. The bill would require the department to maximize the amount of assistance requested and received through D-SNAP and all other federally funded nutrition assistance, including utilizing that provided utility data, in order to timely seek automated mass replacement of specified federally funded nutrition assistance programs. The bill would require the department, on or before December 31, 2026, to submit a report to the Legislature related to food assistance, as specified.
Approved by Governor on
October 13
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.
Approved by Governor on
October 6
AB 1104 Pellerin Net energy metering:
construction of
renewable electrical
generation facilities:
public works project
requirements.
Solar Existing law provides for various enforcement mechanisms related to ensuring a contractor pays each construction worker the prevailing rate of per diem wages, and provides that an enforcement of a willful violation of any of these mechanisms against a contractor for the construction of a renewable electrical generation facility disqualifies that facility from eligibility being eligible to receive service pursuant to NEM
1.0, NEM 2.0, or the net billing tariff. This bill instead would make a renewable electrical generation facility eligible to receive service pursuant to NEM 1.0, NEM 2.0, or the net billing tariff despite enforcement of a willful violation against a contractor for the construction of the facility, as described above, if restitution has been made to the affected workers and all associated penalties and fines have been paid.
Approved by Governor on
October 11
Medium Priority
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 public messages, 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 public messages 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 May 31, 2026, and annually thereafter, to include, as part of a specified statement to the commission, certain information.
Approved by Governor on
October 11
AB 1273 Patterson Public utilities:
ratesetting proceedings:
local publicly owned
electric utilities:
California Renewables
Portfolio Standard
Program
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.
Vetoed by Governor
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.
Approved by Governor on
October 6
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.
Approved by Governor on
October 11
AB 1408 Irwin Electricity:
interconnections
Interconnections This bill would require each electrical corporation, and each local publicly owned utility with an annual electrical demand exceeding 700 gigawatthours, to require the evaluation of surplus interconnection options and to consider surplus interconnection options, for purposes of its integrated resource plan.
Vetoed by Governor
Medium Priority
AB 1410 Garcia Utilities: service outages
and updates: alerts
Outages This bill would require each electrical corporation, gas corporation, water corporations, or local publicly owned electric 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 they do not wish to receive, except as provided. The bill would require each public utility to provide information on customers’ bills on how to update their preferred contact methods and to allow customers to update their contact information by email or telephone.
Approved by Governor on
October 6
AB 1423 Irwin Transportation
electrification: electric
vehicle charging stations:
payment methods.
EVSE This bill would authorize the commission to modify, add to, or subtract from those required payment methods, as appropriate in light of changing technologies or cost impacts.
Approved by Governor on
October 1
SB 24 McNerney Public utilities: review of
accounts: electrical and
gas corporations: rates:
political influence
activities and promotional
advertising.
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 May 31, 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.
Vetoed by Governor
SB 80 Caballero The Fusion Research and
Development Innovation
Hub Program.
Fusion This bill would establish 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 by the 2040s.
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.
Approved by Governor on
October 3
Medium Priority
SB 86 McNerney California Alternative
Energy and Advanced
Transportation Financing
Authority Act: sales and
use tax exclusion.
Fusion This bill would extend to January 1, 2031 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 $200,000,000 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.
Approved by Governor on
October 1
SB 88 Caballero Air resources: carbon
emissions: biomass.
Biomass The bill would require the state board, on or before January 1, 2028, to adopt a method of quantification of the life-cycle emissions from alternative uses of forest and agricultural biomass residues. The bill would require the state board, on or before January 1, 2029, to include in the next scoping plan update a strategy to support beneficial carbon removal products, including, but not limited to, biochar, that are generated from agricultural or forest biomass resources.
Vetoed by Governor
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 State Lands Commission, the Transportation Agency, and the state board, to develop a plan on or before December 31, 2030, for the alternative fuel needs of oceangoing vessels at California’s public seaports that will enable the seaports to meet their emissions reduction goals. The bill would require the plan to do specified things, including, among other things, identifying barriers to permitting alternative fuel facilities at seaports and opportunities to address those barriers. 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. The bill would require the state board to provide the Energy Commission with information regarding fuels for oceangoing vessels that comply with the state board’s regulations for those vessels.
Vetoed by Governor
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.
Vetoed by Governor
Medium Priority
SB 500 Stern Energy: usage data Energy Data Existing law requires each utility, on and after January 1, 2017, to, upon the request and authorization of the owner, owner’s agent, or operator of a covered building, as defined, deliver or otherwise provide aggregated energy usage data for a covered building to the owner, owner’s agent, or building operator, or to the owner’s account in the ENERGY STAR Portfolio Manager, as specified.
This bill would authorize a utility to satisfy that requirement by delivering or otherwise providing aggregated energy usage data to the owner’s account in any alternative system or tool approved by the State Energy Resources Conservation and Development Commission.
Approved by Governor on
October 13
SB 533 Richardson Electric vehicle charging
stations: arenas:
payments: 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 an arena that has a seating capacity of at least 15,000 seats and can only be accessed through the use of that internet-based application.
Approved by Governor on
October 13
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.
Approved by Governor on
October 6
SB 593 Hurtado Voltage changes:
consumer protection.
Notice This bill would require the commission, on or before July 1, 2027, to require electrical corporations to adjust their consumer protections to better protect customers from significant voltage changes that can result in damage to customers’ equipment and appliances if the commission determines adjustments to the consumer protections are necessary. The bill would specify the factors that the commission would be required to evaluate when determining whether to adjust the consumer protections, as provided.
Approved by Governor on
October 6
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.
Approved by Governor on
October 3
Medium Priority
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.
Approved by Governor on
October 10
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 Industrial Policy and Clean Energy Development to convene working groups that focus on certain issues, as provided. The bill would require the commission, the Governor’s Office of Business and Economic Development, the Labor and Workforce Development Agency, the Public Utilities Commission, the Department of Water Resources, the Department of General Services, and the office of the Treasurer, on or before March 1, 2026, to enter into an a memorandum of understanding on equitable clean energy supply chains and industrial policy in California to, among other things, review, investigate, and develop strategies for building integrated industrial bases in California to support the zero-emission vehicle and battery supply chain industries, offshore wind and offshore wind component industries, and building decarbonization and heat pump industries through industrial planning and public investment, procurement, and subsidization, as provided. The bill would require the Senior Counselor on Industrial Policy and Clean Energy Development to track and coordinate the work taken under the memorandum of understanding and to prepare an annual report summarizing the key findings and recommendations resulting from that work. The bill would require that the report be presented at a public meeting of the commission and be published on the commission’s internet website. The bill would establish in the State Treasury the Equitable Clean Energy Supply Chain and Industrial Policy Fund and would, upon appropriation by the Legislature, authorize the moneys in the fund be expended for the purposes of the bill.
Vetoed by Governor
Failed Deadline
Bill # Author Title Category Summary Status
AB 13 Ransom Public Utilities
Commission:
membership: reports.
CPUC Reporting The bill would require the Governor, in selecting, and the Senate, in confirming, members of the commission to consider regional diversity in the membership of the commission. The bill would require the Governor, in appointing a candidate for membership in the commission, to consider using a candidate pool that comprises persons with permanent residences in certain regions of the state, as specified.
Read second time and
amended. 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.
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. Re-referred to Com.
on APPR.
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.
In committee: Held under
submission.
Failed Deadline
AB 222 Bauer-Kahan Data centers: power
usage effectiveness:
cost shifts.
Data Centers This bill would require the Energy Commission to establish a process for the owner of a data center, as defined, to submit the power usage effectiveness ratio, as defined, for the data center to the Energy Commission on a biannual basis, and require the owner of a data center to submit this information for the data center in the manner and timeframe specified by the Energy Commission. The bill would require the Energy Commission, as part of the 2027 edition of the integrated energy policy report, to include an assessment of electrical load trends for data centers, as provided.
From committee: Do pass and
re-refer to Com. on APPR. (Ayes
11. Noes 2.) (July 15). Re-referred to Com. on APPR.
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
aerial response:
program
Wildfires This bill would require the Office of Emergency Services, in consultation with the Department of Forestry and Fire Protection, to establish, on or before December 31, 2026, a working group to evaluate and develop recommendations for implementing a wildfire aerial response program to provide year-round, 24 hours per day, 7 days per week, rapid aerial suppression capabilities. The bill would require the working group to consider specified elements to ensure effective statewide aerial wildfire suppression and to develop recommendations, including whether the program should be implemented as a pilot program, a full-scale statewide initiative, or if implementation is not recommended based on feasibility findings. The bill would require the Director of Emergency Services, in consultation with the department, to appoint members to the working group who are familiar with wildfire aviation response programs, as provided. The bill would require the working group to report its findings and implementation recommendations to the Assembly Committee on Emergency Management and the Senate Committee on Governmental Organization on or before December 31, 2027, as provided.
In committee: Set, second
hearing. Hearing canceled at the
request of author.
Failed Deadline
AB 286 Gallagher Electricity: mandatory
rate reduction.
Rates This bill would require the commission to generate a report outlining recommendations to decrease the kilowatt-per-hour rate for electricity charged to ratepayers by not less than 30% by January 1, 2027. The bill would require the commission, in making those reduction recommendations, to take certain actions, as specified.
In committee: Held under
submission.
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 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.
In committee: Hearing
postponed by committee.
AB 306 Schultz and Riv 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.
From committee chair, with
author's amendments: Amend,
and re-refer to committee. Read
second time, amended, and re-referred to Com. on HOUSING.
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.
In committee: Held under
submission.
Failed Deadline
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.
In committee: Set, first hearing.
Referred to suspense file.
AB 441 Hadwick Wildfire prevention:
Office of Wildfire
Technology Research
and Development:
wildfire mitigation
program
Wildfires Would repeal provisions related to the Office of Wildifre Technology Research and Development. In committee: Set, first hearing.
Hearing canceled at the request
of author.
AB 443 Bennett Energy Commission:
integrated resource
policy report: curtailed
solar and wind
generation: hydrogen
production
Hydrogen This bill would require the Energy Commission, as part of the 2027 edition of the integrated energy policy report and each edition thereafter, and contingent upon an appropriation for this purpose, to include an assessment of funding needs for port infrastructure for offshore wind energy development, as specified. The bill would require the Energy Commission, in consultation with specified entities, to include in the assessment any 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.
In committee: Referred to APPR.
suspense file.
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.
In committee: Held under
submission.
Failed Deadline
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.
In committee: Held under
submission.
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.
From committee: Do pass and
re-refer to Com. on APPR. (Ayes
15. Noes 1.) (July 15). Re-referred to Com. on APPR.
AB 716 Carillo Fire safety standards:
hydrogen facilities
Hydrogen This bill would require the State Fire Marshal to to appoint a hydrogen fire expert to answer questions and provide clarification on the implementation of hydrogen production, storage, and distribution facilities, ensuring that hydrogen facilities comply with the most up-to-date fire safety standards. The bill would require the State Fire Marshal to provide ongoing training to local fire departments and building inspectors to ensure that hydrogen-related safety protocols are understood and enforced statewide.
Read second time and
amended. Re-referred to Com.
on APPR.
AB 729 Zbur Public utilities: climate
credits
Climate Credits This bill would require that the electric California Climate Credit be provided to the residential and small business retail customers of electrical corporations on the bills of those customers for the months of August and September of each year, and to the emissions-intensive trade-exposed retail customers of electrical corporations on the bills of those customers for the month of August of each year, unless otherwise directed by the commission, as specified. The bill would require that the natural gas California Climate Credit be provided to residential customers on the bills of those customers for the month of February of each year unless otherwise directed by the commission, as specified.
From committee chair, with
author's amendments: Amend,
and re-refer to committee. Read
second time, amended, and re-referred to Com. on E., U & C.
AB 745 Irwin Electricity: climate
credits
Climate Credits This bill would require the credit provided to residential customers of an electrical corporation to be provided on the bills of those customers for the months of July, August, and September of each year, or as otherwise directed by the commission to address extreme, unforeseen, and temporary circumstances. The bill would require the credit to be volumetric, rather than independent of consumption.
From committee: Do pass and
re-refer to Com. on APPR. (Ayes
16. Noes 0.) (July 15). Re-referred to Com. on APPR.
Failed Deadline
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, except as provided, 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. The bill would make the universal waste designation applicable to a solar photovoltaic module that is intended for recycling and cannot otherwise be resold, reused, or refurbished only until the department adopts regulations implementing alternative management standards for solar photovoltaic modules.
The bill would also designate a solar photovoltaic module that can be resold, reused, or refurbished as surplus material. The bill would make a conforming change.
Read second time and
amended. Re-referred to Com.
on APPR.
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.
In committee: Hearing
postponed by committee.
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.
In committee: Held under
submission.
AB 942 Calderon Electricity: climate
credits
Climate Credits This bill would exclude residential customers from receiving the California Climate Credit if they are not enrolled in the CARE or FERA program and their total electricity bills for the previous year were less than $300.
Read second time and
amended. Re-referred to Com.
on APPR.
Failed Deadline
AB 1016 Gonzalez Power facility and site
certifications: thermal
powerplants:
geothermal resources
Geothermal This bill would additionally authorize 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 that a person proposing an eligible thermal powerplant files an application on or before June 30, 2029, for certification with the local governmental agency that has land use and related jurisdiction over the area in which the powerplant is located to certify the site and related facility, and that the powerplant has a generating capacity of up to 150 megawatts, or that modifications are being made to a thermal powerplant that generates electricity using geothermal resources that do not add capacity in excess of 150 megawatts and for any plan for multiple geothermal powerplants that use at least one common infrastructure component and those powerplants, in total, have a net generating capacity of 50 or more megawatts.. Upon the commission granting an exemption, the bill would require the local governmental agency to be the lead agency to certify the site and related facility, as provided. 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.
In committee: Set, first hearing.
Hearing canceled at the request
of author.
AB 1017 Boerner Energy: electrical and
gas corporations:
general rate cases.
General Rate
Cases
This bill would require an electrical corporation or gas corporation, as a part of its general rate case, to provide to the commission certain information, including, among other things, the authorized and actual rate of return and return on equity for the past 10 years and projects related to the corporation’s distribution capacity that include the forecast submitted in the prior general rate case of the corporation.
In committee: Hearing
postponed by committee.
AB 1020 Schiavo Public utilities: energy:
taxpayer 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 taxpayer funding, as defined, greater than or equal to $1,000,000, 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 taxpayer 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 taxpayer funding to ratepayers, as provided.
From committee: Do pass and
re-refer to Com. on APPR. (Ayes
12. Noes 3.) (July 15). Re-referred to Com. on APPR.
Failed Deadline
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.
Read second time and
amended. Re-referred to Com.
on APPR.
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.
Read second time and
amended. Re-referred to Com.
on APPR.
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.
In committee: Held under
submission.
Failed Deadline
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 In committee: Hearing
postponed by committee.
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.
In committee: Held under
submission.
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.
In committee: Set, first hearing.
Failed passage.
Reconsideration granted.
Failed Deadline
AB 1222 Bauer-Kahan Public utilities: judicial
review
IOUs This bill would prohibit the commission from authorizing electrical or gas corporations to recover from their ratepayers the costs associated with seeking judicial review of a commission decision by a state or federal court or requesting relief from a commission decision at a federal agency. The bill would require the electrical and gas corporation to track those costs.
In committee: Held under
submission.
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.
Failed Deadline
AB 1260 Ward Electricity: renewable
energy subscription
programs
Community
Renewables
This bill would revise and recast the requirements for the customer renewable energy subscription program to, among other things, specify that the avoided costs include certain avoided cost values. The bill would impose additional requirements that the program is required to meet, including requiring facilities participating in the program to have no more than 5 megawatts of generation capacity and no more than 5 megawatts of storage, and capping the total program capacity at 5 gigawatts or ending program subscription after 7 years, when either limit is first reached. The bill would require the PUC, on or before September 1, 2026, to adopt or modify the community renewable energy program to ensure consistency with certain requirements, as provided. The bill would require each community choice aggregator and electric service provider, within 180 days of the adoption or modification of the program, to notify the PUC regarding whether it will participate in the program. The bill would authorize a community choice aggregator or electric service provider to begin participating in, or end its participation in, the program at any time by notifying the PUC. The bill would require the PUC, beginning 2 years from the adoption or modification of the program, to evaluate the program to ensure consistency with the program’s requirements and would require the PUC to authorize the termination or modification of the program if the PUC determines that the program does not meet those requirements. The bill would require the State Energy Resources Conservation and Development Commission (Energy 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. The bill would require the Energy Commission to undertake the evaluation and issue a determination on or before September 1, 2026, as provided.
In committee: Held under
submission.
AB 1295 Patterson Public utilities: bills
and notices:
consolidation and
transparency
Billing This bill would require the commission, on or before June 1, 2026, to evaluate all customer billing and noticing requirements existing on January 1, 2026, that apply to gas or electric utilities, and to identify and consider potential avenues to consolidate and enhance billing transparency, including avenues that clearly show the source and value of each charge within each customer’s bill, as specified, and use the most cost-effective communications channels, as provided. The bill would authorize the commission to seek and consider input from utilities and other relevant stakeholders to inform its evaluation and identification and consideration of potential avenues to consolidate notices and enhance billing transparency.
In committee: Held under
submission.
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 E., U & C.
Failed Deadline
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. In committee: Hearing postponed by committee.
AB 1342 Soria Public Utilities
Commission: energy
efficiency programs:
report.
Programs Existing law requires the Public Utilities Commission, on or before December 31, 2018, and biennially thereafter, as part of a specified report, to identify and report to the Legislature on electrical and gas corporation ratepayer-funded energy efficiency programs that are similar to programs administered by the State Energy Resources Conservation and Development Commission, the State Air Resources Board, and the California Alternative Energy and Advanced Transportation Financing Authority. This bill would instead require the commission to identify and report to the Legislature on those programs on an annual basis.
In committee: Hearing
postponed by committee.
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.
In committee: Set, first hearing.
Hearing canceled at the request
of author.
Failed Deadline
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.
In committee: Hearing
postponed by committee.
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.
In committee: Hearing
postponed by committee.
AB 1436 Avila Farias Public Utilities
Commission:
outreach.
PUC Outreach Existing law, in effect until January 1, 2020, required the Policy and Planning Division of the Public Utilities Commission to undertake one or more studies of outreach efforts undertaken by other state and federal utility regulatory bodies and make recommendations to the commission to promote effective outreach, including metrics for use in evaluating success. This bill would repeal that obsolete provision.
Referred to Com. on E., U & C.
Failed Deadline
AB 1484 Bennett Energy reliability Spot Spot Bill Read first time.
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.
May 14 set for first hearing
canceled at the request of
author.
Failed Deadline
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 each physical meeting location designated by the subsidiary body, as specified. 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.
Ordered to inactive file on
request of Senator Arreguín.
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.
SB 256 Perez Electricity: electrical
infrastructure: wildfire
mitigation.
Infrastructure This bill would require an electrical corporation, for the description in the wildfire mitigation plan of the preventative strategies and programs to minimize the risk of its electrical lines and equipment causing catastrophic wildfires, to include consideration of areas adjacent to high fire threat areas. The bill would require an electrical corporation’s wildfire mitigation plan to consider the impacts on the opportunity for residents within a household who are not the customer of record to subscribe to receive notifications related to deenergization events and communication with public safety partners, identify any lapses in communication coordination during recent past emergency response events with local governments, describe opportunities to collaborate with local governments and other steps that can be taken to establish more efficient communication coordination during future emergency responses, consider undergrounding distribution infrastructure when it is being rebuilt, include an accounting of all transmission facilities, including permanently abandoned facilities, and include a plan for how and when each permanently abandoned facility will be removed and the wildfire mitigation measures that are being implemented to prevent hazards, as provided. The bill would also require electrical corporations to conduct annual wildfire preparedness workshops, as provided.
Read second time and
amended. Re-referred to Com.
on APPR.
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.
May 23 hearing: Held in
committee and under
submission.
Failed Deadline
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.
May 23 hearing: Held in
committee and under
submission.
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.
May 23 hearing: Held in
committee and under
submission.
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.
April 29 set for first hearing
canceled at the request of
author.
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 a project subject to competitive bidding and 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.
July 16 set for second hearing
canceled at the request of
author.
SB 332 Wahab Investor-Owned
Utilities Accountability
Act
IOU Oversight This bill would require the research institute to conduct the first phase of the comparative analysis and to submit an interim report, on or before December 31, 2026, to the Energy Commission on threshold legal issues, as provided. The bill would require the Energy Commission to convene a group of state attorneys from the legal departments of state agencies that regulate electrical corporations to advise the research institute on the first phase of the comparative analysis, as specified.
Read second time and
amended. Re-referred to Com.
on APPR.
Failed Deadline
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.
May 23 hearing: Held in
committee and under
submission.
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.
April 7 set for first hearing
canceled at the request of
author.
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.
Referred to Com. on E.D., G., &
H.I.
Failed Deadline
SB 540 Becker and
Stern
Independent System
Operator: independent
regional organization
Regional
Organization
This bill would delete 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. This bill would specify that the above-described provisions do not diminish the PUC’s authority to direct an electrical corporation to withdraw from an energy market governed by an independent regional organization, and would authorize the PUC to direct an electrical corporation to withdraw from an energy market governed by an independent regional organization under specific circumstances. The bill would also require an electrical corporation within the balancing authority of the ISO to withdraw from an energy market governed by an independent regional organization under two specified conditions. This bill would establish the Regional Energy Market Oversight Council, which would be responsible for ensuring that participation in regional energy markets serves the interests of the state. The bill would require the council to approve or disapprove initial participation in the independent regional organization by electrical corporations and any other participating load-serving entities and determine whether electrical corporations and any other participating load-serving entities should be required to withdraw from an energy market governed by the independent regional organization. The bill would require the council to convene a duly noticed public meeting to make a finding of approval or withdrawal of participation in the independent regional organization and would require the council to disapprove of initial participation in the independent regional organization, or order withdrawal, if the council makes any of specified findings.
July 16 set for first hearing
canceled at the request of
author.
SB 559 Stern Electricity:
deenergization events:
communications
Deenergization eve 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.
May 23 hearing: Held in
committee and under
submission.
Failed Deadline
SB 620 Stern Energy utility data. Data This bill would require the State Energy Resources Conservation and Development Commission (Energy Commission) to create the Data Access Governance Committee, with specified membership, and would require the committee, on or before January 1, 2027, to provide initial recommendations on prescribed topics to the Energy Commission and the PUC, as specified. The bill would authorize the Energy Commission to work with certain gas corporations, electrical corporations, and local publicly owned utilities that provide gas or electrical service to enact cost-effective energy utility data programs, as specified. The bill would create, and would require the PUC and the Energy Commission to administer and enforce, the Customer Energy Utility Data Bill of Rights, with specified protections and customer rights.
April 29 set for first hearing
canceled at the request of
author.
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.
May 23 hearing: Held in
committee and under
submission.
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.
April 22 set for first hearing
canceled at the request of
author.
Failed Deadline
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.
May 23 hearing: Held in
committee and under
submission.
SB 708 Alvarado-Gil Public Utilities
Commission: quorum
for the transaction of
business
CPUC Spot Bill Referred to Com. on RLS.
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.
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.
May 23 hearing: Held in
committee and under
submission.
SB 755 Blakespear California Contractor
Climate Transparency
Act
California Contract This bill would enact the California Contractor Climate Transparency Act, which would require the board, beginning January 1, 2027, to require a large contractor and a significant contractor, as defined, to report annually specified information, including, 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.
May 23 hearing: Held in
committee and under
submission.
Failed Deadline
SB 803 Durazo California
Conservation Corps:
Green Collar
Certification Program
California Conserva Thisbill 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.
May 23 hearing: Held in
committee and under
submission.
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: Do pass and
re-refer to Com. on APPR. with
recommendation: To consent
calendar. (Ayes 7. Noes 0.) (July
14). Re-referred to Com. on
APPR.
SB 810 Dahle Electricity: ratepayer-funded programs:
reports
Reporting 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.
May 23 hearing: Held in
committee and under
submission.
Failed Deadline
SB 842 Stern Energy: firm zero-carbon resourcesZero-Carbon ResouThis bill would require commission, 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 report to include, among other things, characterization of the resource attributes vital for local reliability and identification of barriers, including market barriers, to deploying firm zero-carbon resources to enhance local reliability.
From committee: Do pass and
re-refer to Com. on APPR. with
recommendation: To consent
calendar. (Ayes 18. Noes 0.)
(July 9). Re-referred to Com. on
APPR.
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.5
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Saul Viramontes, Administrative Services Manager
Approved By: Joe Mosca, Chief Executive Officer
Subject: STRATEGIC PLAN MONTHLY STATUS REPORT
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☐ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☒ Not Applicable: Project management for Strategic Plan; promote transparency
RECOMMENDED ACTION
Receive and file.
BACKGROUND
On May 12, 2025, the Orange County Power Authority (OCPA) Board of Directors (Board) approved the 2025-26 Strategic Plan. This strategic plan marks the third iteration of the OCPA strategic planning process. This year’s strategic plan includes five (5) strategic goals and 27 objectives. Specific details on the status of each objective, the expected completion date, and the responsible parties are included in Attachment A.
The strategic plan is available online at – https://www.ocpower.org/strategic-plan 2025-26 Strategic Goals
1. Enrich and Grow the OCPA Community
2. Prioritize Fiscal Sustainability and Affordability
3. Design and Deploy Community-Aligned Customer Programs
4. Energize Our Community with Renewable Energy Sources
5. Raise Awareness of Community Energy & Advocating for Our Customers Not Started In Progress Completed
Objectives 13 14 2
Summary of changes since the last Board meeting:
2.3 Explore innovative financing to optimize long-term power procurement costs and educate the board on options.
Issuing Green Prepayment Bonds through the California Community Choice Financing Authority (CCCFA) is a proven financing strategy successfully implemented by more than 11 Community Choice Aggregators (CCAs), achieving significant long-term reductions in power costs. By leveraging tax-exempt financing, OCPA can lower Power Purchase Agreement (PPA) payments by an estimated 10% to 12%, generating projected annual savings of $4 to $6 million on its first transaction. This structure allows OCPA to secure renewable energy at lower interest rates and provide affordable, reliable, and sustainable power to nearly 200,000 customers.
To ensure a coordinated and transparent process, staff held educational sessions with each Board Member in September 2025. On October 13, 2025, the Board authorized staff to proceed with evaluating and preparing for a potential Green Prepayment Bond transaction, including engaging PFM as municipal advisor and Chapman and Cutler as prepay counsel. An RFP for a prepay counterparty bank was issued on October 23, with proposals due November 7 and work expected to begin by November 28, 2025.
PFM, the selected counterparty, and staff will jointly develop the transaction structure.
Staff will provide an update to the Board in December 2025 on the selected counterparty and seek authorization to join the CCCFA, followed by final Board approval of all transaction documents in January 2026. Execution of the prepay transaction is targeted for completion by the end of the first quarter of 2026.
This phased approach provides adequate time for Board engagement, market preparation, and risk management to maximize customer savings.
2.4 Initiate planning for a 0.5MW local renewable energy project in a Disadvantaged Community (DAC) to serve income-qualified residential customers without rooftop solar access.
The project will provide 100% renewable energy and a 20% bill discount.
On September 2, Southern California Edison (SCE) filed its formal response to Advice Letter 13-E, expressing support for OCPA’s capacity transfer request. Shortly thereafter, OCPA made additional refinements in accordance with Energy Division guidance and submitted a supplemental Advice Letter on September 17. The supplemental filing further revised the PY2026–2027 budget forecast downward to $395,051. OCPA anticipates timely CPUC approval of supplemental Advice Letter 13-E by the first quarter of 2026. Upon approval, the agency plans to begin providing interim service using existing renewable resources in the third quarter of 2026. OCPA also anticipates that the Energy Division will prepare a draft decision on its DAC-GT program request for Commission consideration by the first quarter of 2026.
FISCAL IMPACT
None
ATTACHMENTS
Attachment A – 2025-26 OCPA Strategic Plan Monthly Status Report – November 2025 Update Strategic Goal Objective Progress Due Date Assigned To Status Date Status Update #1 Enrich & Grow the OCPA Community
1.1 Present an overview of CCAs and OCPA to two (2) organizations per quarter that cover the wider Orange County region or those that are focused on non-member cities.
In progress 10/13/2025 Director of Communications & External Affairs 11/3/2025 Presented to the Santa Ana Chamber of Commerce on May 13; League of Women Voters; Climate/Environmental Committee;In October, we presented at the Fountain Valley Mayor's Breakfast and at the Fullerton Senior Center x
#1 Enrich & Grow the OCPA Community
1.2 Present OCPA to key stakeholders in at least two (2) prospective member cities to promote OCPA’s mission and benefits.
In progress 06/01/2026 Director of Communications & External Affairs 11/3/2025 We have done presentations for representatives from two prospective cities. #1 Enrich & Grow the OCPA Community
1.3 Develop educational tools and programs that promote renewable energy for students of all ages, including school partnerships, curriculum support, internship program, youth ambassador program, and community academy.
In progress 06/01/2026 Director of Communications & External Affairs 11/3/2025 OCPA staff have begun engaging local students through the OC Leadership Academy, which visited OCPA headquarters and learned about community energy and clean tech careers on June 24, as well as, provided a presentation to the Irvine high school students at the Irvine Youth Action Team Summer Camp Cleantech Workshop on June 10;OCPA is working with the OC Department of Education on co-branded curriculum to live on the OCPA website for download by educators #1 Enrich & Grow the OCPA Community
1.4 Partner with new local CBOs, including food assistance organizations, to promote state-funded low-income programs widely in member cities, including CARE, FERA, and Medical Baseline.
In progress 12/08/2025 Director of Communications & External Affairs 11/3/2025 OCPA now has a point of contact at Families Forward (Irvine) and has shared program materials, partnered with Pathways of Hope (Fullerton) to promote the community power plan survey, hosted tables at Buena Park food distribution center and Fullerton food distribution center. #2 Prioritize Fiscal Sustainability & Affordability
2.1 Ensure affordable rates for OCPA customers while covering all expenses and advancing equitable renewable energy initiatives. Not started 01/01/2026 Chief Financial Officer #2 Prioritize Fiscal Sustainability & Affordability 2.2 Strengthen Financial Resilience and Credit Rating Preparation. Not started 12/08/2025 Chief Financial Officer#2 Prioritize Fiscal Sustainability & Affordability
2.3 Explore innovative financing to optimize long-term power procurement costs and educate the board on options. In progress 12/08/2025 Chief Financial Officer 11/3/2025 Issuing Green Prepayment Bonds through the California Community Choice Financing Authority (CCCFA) is a proven financing strategy successfully implemented by more than 11 Community Choice Aggregators (CCAs), achieving significant long-term reductions in power costs. By leveraging tax-exempt financing, OCPA can lower Power Purchase Agreement (PPA) payments by an estimated 10% to 12%, generating projected annual savings of $4 to $6 million on its first transaction. This structure allows OCPA to secure renewable energy at lower interest rates and provide affordable, reliable, and sustainable power to nearly 200,000 customers.To ensure a coordinated and transparent process, staff held educational sessions with each Board Member in September 2025. On October 13, 2025, the Board authorized staff to proceed with evaluating and preparing for a potential Green Prepayment Bond transaction, including engaging PFM as municipal advisor and Chapman and Cutler as prepay counsel. An RFP for a prepay counterparty bank was issued on October 23, with proposals due November 7 and work expected to begin by November 28, 2025.PFM, the selected counterparty, and staff will jointly develop the transaction structure. Staff will provide an update to the Board in December 2025 on the selected counterparty and seek authorization to join the CCCFA, followed by final Board approval of all transaction documents in January 2026. Execution of the prepay transaction is targeted for completion by the end of the first quarter of 2026.This phased approach provides adequate time for Board engagement, market preparation, and risk management to maximize customer savings. #2 Prioritize Fiscal Sustainability & Affordability
2.4 Initiate planning for a 0.5MW local renewable energy project in a Disadvantaged Community (DAC) to serve income-qualified residential customers without rooftop solar access. The project will provide 100% renewable energy and a 20% bill discount.
In progress 01/01/2026 Chief Financial Officer 10/31/2025 On September 2, Southern California Edison (SCE) filed its formal response to Advice Letter 13-E, expressing support for OCPA’scapacity transfer request. Shortly thereafter, OCPA made additional refinements in accordance with Energy Division guidance and submitted a supplemental Advice Letter on September 17. The supplemental filing further revised the PY2026–2027 budget forecast downward to $395,051. OCPA anticipates timely CPUC approval of supplemental Advice Letter 13-E by the first quarter of 2026. Upon approval, the agency plans to begin providing interim service using existing renewable resources in the third quarter of 2026. OCPA also anticipates that the Energy Division will prepare a draft decision on its DAC-GT program request forCommission consideration by the first quarter of 2026. #3 Design & Deploy Community-Aligned Customer Programs 3.1 Finalize the Community Needs Assessment for the Community Power Plan and present the findings and next steps. In progress 10/13/2025 Director of Communications & External Affairs 11/3/2025 The Executive Summary is complete and a draft will be shared with the Community Advisory Committee at their December meeting for feedback. #3 Design & Deploy Community-Aligned Customer Programs 3.2 Develop three (3) new customer programs consistent with the needs identified in the Community Needs Assessment of the OCPA Community Power Plan. In progress 04/01/2026 Director of Communications & External Affairs#3 Design & Deploy Community-Aligned Customer Programs 3.3 Continue to expand grant and program offerings with a year- over-year growth goal of 25%, respective to total funds allocated, number of applications received, and number of new recipients. In progress 06/01/2026 Director of Communications & External Affairs 6/3/2025 The summer 2025 Bright Futures Grant will award 60% more than the previous year. #3 Design & Deploy Community-Aligned Customer Programs
3.4 Develop a landing page specifically for low-income residents to connect with programs, including EBD-DI and DAC-GT programs, once launched; and market resource to community partners and networks.
Not started 12/08/2025 Director of Communications & External Affairs 11/3/2025 Preliminary research into programs for this page has begun and will pick up in 1Q26. #4 Energize Our Community with Renewable Energy Sources
4.1 Implement the first OCPA local generation programs, establishing contracts for developing small-scale distributed storage facilities with a 1-5 megawatt capacity each.
Not started 03/01/2026 Director of Power Resources
#4 Energize Our Community with Renewable Energy Sources
4.2 Establish precise metrics and effective tools to proficiently identify, avoid, and mitigate market and credit risks for OCPA. Not started 03/01/2026 Director of Power Resources #4 Energize Our Community with Renewable Energy Sources
4.3 Create local partnerships with clean technology companies to advance emerging long-term energy storage and technologies. Not started 06/01/2026 Director of Power Resources #4 Energize Our Community with Renewable Energy Sources
4.4 Forge partnerships with other CCAs to acquire shared resources, mitigate development risks, and capitalize on economies of scale.
Not started 12/08/2025 Director of Power Resources
#4 Energize Our Community with Renewable Energy Sources
4.5 Create a more sustainable electric grid with measurable milestones above California’s renewable energy goals. Not started 06/01/2026 Director of Power Resources #4 Energize Our Community with Renewable Energy Sources
4.6 Create partnerships with member agencies to identify local development opportunities. Not started 12/08/2025 Director of Power Resources #4 Energize Our Community with Renewable Energy Sources
4.7 Release at least two (2) long-term solicitations for renewable energy resources.
Not started 06/01/2026 Director of Power Resources
#5 Raise Awareness of Community Energy & Advocate for Our Customers
5.1 Develop a toolkit of materials for Board member use in engaging with prospective cities about OCPA. In progress 12/08/2025 Director of Communications & External Affairs 11/3/2025 A trifold brochure has been created based on Board input. #5 Raise Awareness of Community Energy & Advocate for Our Customers
5.2 Host at least two (2) independent pop-up events in member cities per quarter. In progress 06/01/2026 Director of Communications & External Affairs 11/3/2025 The Communications & External Affairs team has hosted three (3) pop-ups, including: Diamond Jamboree, Irvine: 4/12/25; Fullerton City Hall: 4/15/25; Buena Park City Hall: 5/27/25; due to lack of attendance, staff is thinking through alternative strategies #5 Raise Awareness of Community Energy & Advocate for Our Customers
5.3 Sponsor and help facilitate a small business mixer to build community and opportunities for education about OCPA and renewable energy solutions.
Not started 02/01/2026 Director of Communications & External Affairs #5 Raise Awareness of Community Energy & Advocate for Our Customers
5.4 Develop education curricula for elected officials and their staff; provide this training opportunity annually. Not started 03/01/2026 Director of Communications & External Affairs #5 Raise Awareness of Community Energy & Advocate for Our Customers
5.5 Develop working relationships with culturally representative organizations to ensure representative and equitable outreach in the top threshold languages.
In progress 12/08/2025 Director of Communications & External Affairs 11/3/2025 OCPA has begun Community Power Plan outreach work with the Asian Business Association Collective, which will hopefully turn into a long-term relationship.Partnered with PACE LA to host a procurement series geared towards introducing OCPA and community energy to diverse businesses to help increase local business engagement and economic growth. Community grants continue to prioritize diverse representation and diverse communities served. #5 Raise Awareness of Community Energy & Advocate for Our Customers
5.6 Enhance OCPA’s legislative and regulatory advocacy efforts by developing an advocacy roadmap to engage with key stakeholders and legislators to ensure outcomes consistent with OCPA’s strategic goals.
Complete 07/14/2025 Regulatory & Legislative Manager 7/3/2025 Strategic Goal 5.6 in Orange County Power Authority’s (“OCPA”) 2025-2026 Strategic Plan (“Strategic Plan”) is to enhance OCPA’s legislative and regulatory advocacy efforts by developing an advocacy roadmap to engage with key stakeholders and legislators to ensure outcomes consistent with OCPA’s strategic goals. To create the advocacy roadmap, staff identified over 100 key stakeholder organizations and individuals (75+ organizations, 30+ individuals), researched the legislative and regulatory spaces they are active in and key topics they support and oppose, determined where OCPA and key stakeholders align, prioritized stakeholders, and determined current relationship strength. Staff then created engagement plans based on the type of organization, current relationship, and key issues, and overlayed the roadmap with legislative calendars and regulatory timelines. By enhancing its advocacy capacity, OCPA aims to shape a policy and regulatory landscape that enables greater renewable energy adoption, grid resilience, community empowerment, and competitive rates. Lastly, as part of the Strategic Goal, staff have created an implementation plan and feedback loop to ensurethe roadmap stays up to date. Staff will track shifts in stakeholder policies, update relationship status as advocacy is conducted, and make changes to the roadmap as internal policy priorities shift. #5 Raise Awareness of Community
Energy & Advocate for Our Customers
5.7 Develop and implement a regulatory monitoring framework to ensure all departments are consistently informed about regulatory changes and their implications.
Complete 12/08/2025 Regulatory & Legislative Manager
#5 Raise Awareness of Community Energy & Advocate for Our Customers
5.8 Create a Policy Risk Assessment Guide to help OCPA determine the risk involved with different policy decisions at the state and federal level in both the regulatory and legislative arena.
Not started 12/08/2025 Regulatory & Legislative Manager
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.6
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Jacquie Henderson, Director of Communications & External Affairs Subject: PUBLIC OUTREACH UPDATE FOR SEPTEMBER – OCTOBER 2025 Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
RECOMMENDED ACTION
Receive and file.
BACKGROUND
Following is a summary of the Public Outreach efforts for the months of September - October 2025.
Highlights include:
Public Outreach
• Developed the FY25-26 ad concept, “Powering the Communities We Call Home,” and secured advertising media buys in local and multicultural publications and bus shelters • Placed community-focused print ads in Fountain Valley Living, Go Green Health & Expo, and School News Mayor’s Edition
• Distributed direct mail postcards for the residential battery storage and energy efficiency kit rebates
• Created a children’s coloring and activity book to be distributed at community outreach events
• Created a flyer, landing page, and social media graphics to launch promote the 2025 Calpine Community Benefits Grant
• Developed the annual Power Content Label mailer to be sent to all OCPA customers in November 2025
Media Relations
• Distributed five news releases announcing the Bright Futures Grants recipients, City of Irvine affirmation of membership, Lock Energy Center agreement, the Calpine Community Benefits Grant application, and applications opening for a new at-large Community Advisory Committee member
• Earned a story in The Orange County Register about the Community Benefits Grant opportunity
Community Outreach
• Hosted OCPA’s third anniversary event to celebrate OCPA’s Sustainability Champions and Community Grant recipients
• The OCPA team participated in a Day of Service at Second Harvest Food Bank of Orange County
• Participated in 16 community outreach and networking events Awards and Recognition
• OCPA was recognized as an Innovator Green Business by the California Green Business Network
• OCPA received the 2025 Energy Visionary Award from the Asian Business Association of Orange County
Digital Communications
• Developed and published social media content for the months of September and October • Distributed the October newsletter highlighting current and upcoming OCPA news • Published two blog posts: “Climate Change is Messing with Your Mind” by Faisal M. Qazi, D.O. and OCPA Community Advisory Committee member, and a feature on Green P100NEERs: AQ Skin Solutions and Commercial Printer OC Print Company • Updated OCPA Brand Guidelines to include ADA Compliance to ensure consistency and compliance across external communications
More information and details on the projects are included in Attachment A.
FISCAL IMPACT
None
ATTACHMENT
Attachment A – Public Outreach September - October 2025 Public Outreach Update
September – October 2025
PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
Public Outreach
• Developed the FY25-26 ad concept, “Powering the Communities We Call Home,” and secured advertising media buys in local and multicultural publications and bus shelters
• Placed community-focused print ads in Fountain Valley Living, Go Green Health & Expo, and School News Mayor’s Edition • Distributed direct mail postcards for the residential battery storage and energy efficiency kit rebates • Created a children’s coloring and activity book to be distributed at community outreach events • Developed a flyer, landing page and social media graphics to launch the 2025 Calpine Community Benefits Grant • Developed the annual Power Content Label mailer that will be sent to all OCPA customers in November Media Relations
• Distributed five news releases announcing the Bright Futures Grants recipients, City of Irvine affirmation of membership, Lock Energy Center agreement, the Calpine Community Benefits Grant application, and applications opening for a new at-large Community Advisory Committee member
• Earned a story in The Orange County Register about the Community Benefits Grant opportunity Community Outreach
• Hosted OCPA’s third anniversary event to celebrate OCPA’s Sustainability Champions and Community Grant recipients • The OCPA team participated in a Day of Service at Second Harvest Food Bank of Orange County • Participated in 16 community outreach and networking events 2 HIGHLIGHTS
PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
Awards and Recognition
• OCPA was recognized as an Innovator Green Business by the California Green Business Network • OCPA received the 2025 Energy Visionary Award from the Asian Business Association of Orange County Digital Communications
• Published two blog posts including: “Climate Change is Messing with Your Mind” by Faisal M. Qazi, D.O. and OCPA Community Advisory Committee member, and a feature on Green P100NEERs: AQ Skin Solutions and Commercial Printer OC Print Company
• Developed and published social media content for the months of September and October • Distributed the October newsletter highlighting current and upcoming OCPA news • Updated OCPA Brand Guidelines to include ADA Compliance to ensure consistency and compliance across external communications
3 HIGHLIGHTS
4 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• Developed the FY25-26 ad concept, “Powering the Communities We Call Home,” and secured advertising media buys in local and multicultural publications and bus shelters. The new concept features imagery specific to OCPA member cities.
5 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• Placed community-focused print ads in Fountain Valley Living, Go Green Health & Expo, and School News Mayor’s Edition
6 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• Distributed direct mail postcards for the residential battery storage and energy efficiency kit rebates. Mailers were sent to almost 60,000 NEM customers without battery storage and CARE/FERA customers respectively. 7 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• Created a children’s coloring and activity book to be distributed at community outreach events that focuses on clean energy and sustainability education
8 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• Developed a landing page, flyer and social media graphics to launch the 2025 Calpine Community Benefits Grant 9 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
PUBLIC OUTREACH
• With support and feedback from the Marketing and Communications Committee, OCPA developed its annual Power Content Label (PCL) mailer focused on PCL explanation and OCPA’s community reinvestment 10 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
MEDIA RELATIONS
• Distributed five news releases announcing the Bright Futures Grants recipients, City of Irvine affirmation of membership, Lock Energy Center agreement, the Calpine Community Benefits Grant application, and applications opening for a new at-large Community Advisory Committee member
11 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
MEDIA RELATIONS
• Earned a story in The Orange County Register about he Calpine Community Benefits Grant opportunity 12 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
COMMUNITY OUTREACH
• Planned and hosted OCPA’s third anniversary event to spotlight OCPA’s Sustainability Champions and Community Grant Recipients 13 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
COMMUNITY OUTREACH
• The OCPA team participated in a Day of Service at Second Harvest Food Bank of Orange County and learned about the nonprofit’s operations and food insecurity
14 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
COMMUNITY OUTREACH
Participated in 16 community events
1. Buena Park Pumpfest
2. Girls Inc. Ignite HER Summit
3. Buena Park’s National Night Out
4. Kiwanis Club of Fountain Valley’s “Pins for Kids”
5. Super Senior Saturday in Buena Park
6. Attended “Pins for Kids” bowling tournament hosted
by The Kiwanis Club of Fountain Valley
7. Mehregan Festival in Irvine hosted by the Iranian
American Chamber of Commerce
8. Fountain Valley Legislative Breakfast
9. Buena Park Senior Resource Fair
10. Go Green & Health Expo
11. Fullerton High School Career Fair
12. Diwali Festival
13. Global Village Festival
14. Hyundai 5k Color Run
15. Park Culturefest
16. Irvine Mid-Autumn Fest
15 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
AWARDS AND RECOGNITION
• OCPA was recognized as an Innovator Green Business by the California Green Business Network, a reflection of the agency’s ongoing commitment to making communities
healthier and more sustainable
• OCPA received the 2025 Energy Visionary Award from the Asian Business Association of Orange County, which was
presented at their annual gala
16 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
DIGITIAL COMMUNICATIONS
• Developed and published social media content for September and October focused on sustainability awareness observances, the Bright Futures Grant recipients, OCPA’s open positions, federal tax credit incentives and more 17 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
DIGITAL COMMUNICATIONS
• Distributed the October newsletter highlighting current and upcoming OCPA news 18 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
DIGITAL COMMUNICATIONS
Published two blog posts:
• “Climate Change is Messing with Your Mind” by Faisal M. Qazi, D.O. and OCPA CAC member • OCPA’s newest Green P100NEERs: AQ Skin Solutions and Commercial Printer OCPC 19 PUBLIC OUTREACH UPDATE SEPT. – OCT. 2025
DIGITAL COMMUNICATIONS
• Updated OCPA Brand Guidelines to include ADA Compliance to ensure consistency and compliance across external communications
THANK YOU!
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 8.7
--------------------------------------------------------------------------------------------------------------------- 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 OCTOBER 20, 2025
Date: November 10, 2025
---------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☒ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☐ Not Applicable:
RECOMMENDED ACTION
Ratify rates effective October 20, 2025.
BACKGROUND
On October 1, 2025, Southern California Edison (SCE) submitted Advice Letter 5643-E requesting authorization from the California Public Utilities Commission (CPUC) to implement rate changes effective upon CPUC approval.
The system average bundled generation rate increased from 9.6 cents per kWh in June 2025 to
11.4 cents per kWh in October 2025, representing an 18.8% increase across all major customer classes. This increase is primarily due to the expiration of the 2024 ERRA Trigger refund, which had been credited to bundled customers through September 30, 2025. In addition, SCE implemented its 2025 General Rate Case (GRC) Phase 1, which raised both base distribution and generation revenue requirements to fund wildfire mitigation, vegetation management, and grid hardening initiatives.
Updated Power Charge Indifference Adjustment (PCIA) rates also took effect, increasing across most vintages to reflect the higher generation revenue requirements approved in the 2025 GRC.
ANALYSIS AND DISCUSSION
Due to Calpine’s billing system requirements, OCPA’s new rates became effective on October 20, 2025. The attached OCPA rate schedules, effective October 20, 2025, have been published on the OCPA website. These rates have also been communicated to customers through their bills and incorporated into OCPA’s online rate comparison tool, effective the same date.
FISCAL IMPACT
The Board’s ratification of the OCPA rates for October 20, 2025, has no fiscal impact.
ATTACHMENTS
Attachment A – OCPA Rate Schedules Effective October 20, 2025 – Residential and Commercial Customers
Effective: October 20, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
DOMESTIC
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.13983 $ 0.14983 $ 0.15483 $ All electric usage TOU-D-4 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.27772 $ 0.28772 $ 0.29272 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.15845 $ 0.16845 $ 0.17345 $ 4pm - 9pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.09541 $ 0.10541 $ 0.11041 $ All other hours WINTER MID-PEAK 0.20482 $ 0.21482 $ 0.21982 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.12398 $ 0.13398 $ 0.13898 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.10466 $ 0.11466 $ 0.11966 $ 8am - 4pm, every day TOU-D-5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.42963 $ 0.43963 $ 0.44463 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.23069 $ 0.24069 $ 0.24569 $ 5pm - 8pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.08550 $ 0.09550 $ 0.10050 $ All other hours WINTER MID-PEAK 0.29519 $ 0.30519 $ 0.31019 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.12225 $ 0.13225 $ 0.13725 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.09415 $ 0.10415 $ 0.10915 $ 8am - 5pm, every day TOU-D-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.30576 $ 0.31576 $ 0.32076 $ 2pm - 8pm, Monday - Friday SUMMER OFF-PEAK 0.13544 $ 0.14544 $ 0.15044 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
SUMMER SUPER OFF-PEAK 0.09933 $ 0.10933 $ 0.11433 $ 10pm - 8am, every day WINTER ON-PEAK 0.18702 $ 0.19702 $ 0.20202 $ 2pm - 8pm, Monday - Friday WINTER OFF-PEAK 0.10631 $ 0.11631 $ 0.12131 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
WINTER SUPER OFF-PEAK 0.10132 $ 0.11132 $ 0.11632 $ 10pm - 8am, every day TOU-D-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.45185 $ 0.46185 $ 0.46685 $ 2pm - 8pm, Monday - Friday SUMMER OFF-PEAK 0.13539 $ 0.14539 $ 0.15039 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
SUMMER SUPER OFF-PEAK 0.05525 $ 0.06525 $ 0.07025 $ 10pm - 8am, every day WINTER ON-PEAK 0.18080 $ 0.19080 $ 0.19580 $ 2pm - 8pm, Monday - Friday WINTER OFF-PEAK 0.10631 $ 0.11631 $ 0.12131 $ 8am - 2pm & 8pm - 10pm, Monday - Friday 8am - 10pm, Saturday, Sunday & holidays
WINTER SUPER OFF-PEAK 0.05622 $ 0.06622 $ 0.07122 $ 10pm - 8am, every day TOU-D-PRIME Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.33509 $ 0.34509 $ 0.35009 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.12780 $ 0.13780 $ 0.14280 $ 4pm - 9pm, Saturday, Sunday, & holidays SUMMER OFF-PEAK 0.08974 $ 0.09974 $ 0.10474 $ All other hours WINTER MID-PEAK 0.29466 $ 0.30466 $ 0.30966 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07790 $ 0.08790 $ 0.09290 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.07790 $ 0.08790 $ 0.09290 $ 8am - 4pm, every day TOU-D-T Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.17374 $ 0.18374 $ 0.18874 $ 12pm - 6pm, Monday - Friday except holidays*
SUMMER OFF-PEAK 0.15916 $ 0.16916 $ 0.17416 $ All other hours WINTER ON-PEAK 0.13239 $ 0.14239 $ 0.14739 $ 12pm - 6pm, Monday - Friday except holidays*
WINTER OFF-PEAK 0.12156 $ 0.13156 $ 0.13656 $ 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: October 20, 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 0.12953 $ 0.13953 $ 0.14453 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11766 $ 0.12766 $ 0.13266 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07956 $ 0.08956 $ 0.09456 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12235 $ 0.13235 $ 0.13735 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08847 $ 0.09847 $ 0.10347 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.06798 $ 0.07798 $ 0.08298 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00050) (0.00050) $ (0.00050) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00095) (0.00095) $ (0.00095) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00098) (0.00098) $ (0.00098) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 17.25 $ 17.25 $ 17.25 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 5.30 $ 5.30 $ 5.30 $ 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 0.46378 $ 0.47378 $ 0.47878 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.12867 $ 0.13867 $ 0.14367 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.09401 $ 0.10401 $ 0.10901 $ 9pm - 4pm, every day WINTER MID-PEAK 0.19162 $ 0.20162 $ 0.20662 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.10960 $ 0.11960 $ 0.12460 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.06090 $ 0.07090 $ 0.07590 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00137) (0.00137) $ (0.00137) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00299) (0.00299) $ (0.00299) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00305) (0.00305) $ (0.00305) $ All electric usage TOU-GS-1-ES Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.49370 $ 0.50370 $ 0.50870 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.14024 $ 0.15024 $ 0.15524 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.09926 $ 0.10926 $ 0.11426 $ 9pm - 4pm, every day WINTER MID-PEAK 0.18386 $ 0.19386 $ 0.19886 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.10280 $ 0.11280 $ 0.11780 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.05772 $ 0.06772 $ 0.07272 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00138) (0.00138) $ (0.00138) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00300) (0.00300) $ (0.00300) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00305) (0.00305) $ (0.00305) $ All electric usage TOU-GS-1-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.17096 $ 0.18096 $ 0.18596 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.16037 $ 0.17037 $ 0.17537 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.15457 $ 0.16457 $ 0.16957 $ All other hours WINTER MID-PEAK 0.11585 $ 0.12585 $ 0.13085 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.10498 $ 0.11498 $ 0.11998 $ All other hours TOU-GS-1-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09646 $ 0.10646 $ 0.11146 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.09068 $ 0.10068 $ 0.10568 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08753 $ 0.09753 $ 0.10253 $ All other hours WINTER MID-PEAK 0.11585 $ 0.12585 $ 0.13085 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.10498 $ 0.11498 $ 0.11998 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.67 $ 12.67 $ 12.67 $ 12pm - 6pm, Monday - Friday
COMMERCIAL CUSTOMERS
Effective: October 20, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 4.12 $ 4.12 $ 4.12 $ 8am - 12pm & 6pm - 11pm, Monday - Friday Effective: October 20, 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 0.12530 $ 0.13530 $ 0.14030 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11491 $ 0.12491 $ 0.12991 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07639 $ 0.08639 $ 0.09139 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08700 $ 0.09700 $ 0.10200 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08748 $ 0.09748 $ 0.10248 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04946 $ 0.05946 $ 0.06446 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00096) (0.00096) $ (0.00096) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00214) (0.00214) $ (0.00214) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00214) (0.00214) $ (0.00214) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 21.88 $ 21.88 $ 21.88 $ 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) $ (0.50) (0.50) $ (0.50) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (1.14) (1.14) $ (1.14) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (1.16) (1.16) $ (1.16) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.13) (0.13) $ (0.13) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.30) (0.30) $ (0.30) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.30) (0.30) $ (0.30) $ 4pm - 9pm, Monday - Friday
TOU-GS-2-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.40463 $ 0.41463 $ 0.41963 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11491 $ 0.12491 $ 0.12991 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07639 $ 0.08639 $ 0.09139 $ 9pm - 4pm, every day WINTER MID-PEAK 0.13145 $ 0.14145 $ 0.14645 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08748 $ 0.09748 $ 0.10248 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04946 $ 0.05946 $ 0.06446 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00144) (0.00144) $ (0.00144) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00323) (0.00323) $ (0.00323) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00325) (0.00325) $ (0.00325) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 6.08 $ 6.08 $ 6.08 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.35 $ 2.35 $ 2.35 $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.20) (0.20) $ (0.20) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (0.47) (0.47) $ (0.47) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.48) (0.48) $ (0.48) $ 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)
$ (0.12) (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-2-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.09275 $ 0.10275 $ 0.10775 $ 12pm - 6pm, Monday - Friday Effective: October 20, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 0.08724 $ 0.09724 $ 0.10224 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08421 $ 0.09421 $ 0.09921 $ All other hours WINTER MID-PEAK 0.11111 $ 0.12111 $ 0.12611 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06867 $ 0.07867 $ 0.08367 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 15.17 $ 15.17 $ 15.17 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 5.10 $ 5.10 $ 5.10 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-GS-2-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.29310 $ 0.30310 $ 0.30810 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.14318 $ 0.15318 $ 0.15818 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08421 $ 0.09421 $ 0.09921 $ All other hours WINTER MID-PEAK 0.11111 $ 0.12111 $ 0.12611 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06867 $ 0.07867 $ 0.08367 $ All other hours
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00246) (0.00246) $ (0.00246) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00556) (0.00556) $ (0.00556) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00562) (0.00562) $ (0.00562) $ All electric usage Effective: October 20, 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 0.11657 $ 0.12657 $ 0.13157 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10693 $ 0.11693 $ 0.12193 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07455 $ 0.08455 $ 0.08955 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08493 $ 0.09493 $ 0.09993 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08540 $ 0.09540 $ 0.10040 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04827 $ 0.05827 $ 0.06327 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00097) (0.00097) $ (0.00097) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00213) (0.00213) $ (0.00213) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00216) (0.00216) $ (0.00216) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 18.78 $ 18.78 $ 18.78 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 6.79 $ 6.79 $ 6.79 $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 2-50kV ($/kW) $ (0.43) (0.43) $ (0.43) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 51-219kV ($/kW) $ (1.00) (1.00) $ (1.00) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (1.01) (1.01) $ (1.01) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.17) (0.17) $ (0.17) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.36) (0.36) $ (0.36) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.37) (0.37) $ (0.37) $ 4pm - 9pm, Monday - Friday
TOU-GS-3-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.33108 $ 0.34108 $ 0.34608 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10693 $ 0.11693 $ 0.12193 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07455 $ 0.08455 $ 0.08955 $ 9pm - 4pm, every day WINTER MID-PEAK 0.13266 $ 0.14266 $ 0.14766 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08540 $ 0.09540 $ 0.10040 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04827 $ 0.05827 $ 0.06327 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00179) (0.00179) $ (0.00179) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00399) (0.00399) $ (0.00399) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00404) (0.00404) $ (0.00404) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 5.22 $ 5.22 $ 5.22 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.79 $ 2.79 $ 2.79 $ 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) $ (0.42) (0.42) $ (0.42) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.41) (0.41) $ (0.41) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 2-50kV
($/kW)
$ (0.07) (0.07) $ (0.07) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 51-
219kV ($/kW)
$ (0.16) (0.16) $ (0.16) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.15) (0.15) $ (0.15) $ 4pm - 9pm, Monday - Friday
TOU-GS-3-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08856 $ 0.09856 $ 0.10356 $ 12pm - 6pm, Monday - Friday Effective: October 20, 2025
OCPA Rate Schedule Period Basic Choice Smart Choice
100% Renewable
Choice Time Period Definitions
COMMERCIAL CUSTOMERS
SUMMER MID-PEAK 0.08318 $ 0.09318 $ 0.09818 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08043 $ 0.09043 $ 0.09543 $ All other hours WINTER MID-PEAK 0.11047 $ 0.12047 $ 0.12547 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06737 $ 0.07737 $ 0.08237 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.58 $ 12.58 $ 12.58 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.20 $ 4.20 $ 4.20 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-GS-3-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.24347 $ 0.25347 $ 0.25847 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.12371 $ 0.13371 $ 0.13871 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08043 $ 0.09043 $ 0.09543 $ All other hours WINTER MID-PEAK 0.11047 $ 0.12047 $ 0.12547 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06737 $ 0.07737 $ 0.08237 $ All other hours
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00209) (0.00209) $ (0.00209) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00469) (0.00469) $ (0.00469) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00476) (0.00476) $ (0.00476) $ All electric usage Effective: October 20, 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 0.11595 $ 0.12595 $ 0.13095 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10635 $ 0.11635 $ 0.12135 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07431 $ 0.08431 $ 0.08931 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08469 $ 0.09469 $ 0.09969 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08517 $ 0.09517 $ 0.10017 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04804 $ 0.05804 $ 0.06304 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 19.75 $ 19.75 $ 19.75 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 6.05 $ 6.05 $ 6.05 $ 4pm - 9pm, Monday - Friday TOU-8-PRI-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.11007 $ 0.12007 $ 0.12507 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10118 $ 0.11118 $ 0.11618 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07065 $ 0.08065 $ 0.08565 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08062 $ 0.09062 $ 0.09562 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08124 $ 0.09124 $ 0.09624 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04589 $ 0.05589 $ 0.06089 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 18.80 $ 18.80 $ 18.80 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 7.03 $ 7.03 $ 7.03 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-D Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10331 $ 0.11331 $ 0.11831 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09522 $ 0.10522 $ 0.11022 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06616 $ 0.07616 $ 0.08116 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07555 $ 0.08555 $ 0.09055 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07637 $ 0.08637 $ 0.09137 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04314 $ 0.05314 $ 0.05814 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00062) (0.00062) $ (0.00062) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 20.77 $ 20.77 $ 20.77 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 6.71 $ 6.71 $ 6.71 $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.20) (0.20) $ (0.20) $ 4pm - 9pm, Monday - Friday
WINTER MID-PEAK (WEEKDAYS)
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.06) (0.06) $ (0.06) $ 4pm - 9pm, Monday - Friday
TOU-8-SEC-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.31943 $ 0.32943 $ 0.33443 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10635 $ 0.11635 $ 0.12135 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07431 $ 0.08431 $ 0.08931 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12420 $ 0.13420 $ 0.13920 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08517 $ 0.09517 $ 0.10017 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04804 $ 0.05804 $ 0.06304 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 5.49 $ 5.49 $ 5.49 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.48 $ 2.48 $ 2.48 $ 4pm - 9pm, Monday - Friday TOU-8-PRI-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.29991 $ 0.30991 $ 0.31491 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10118 $ 0.11118 $ 0.11618 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07065 $ 0.08065 $ 0.08565 $ 9pm - 4pm, every day WINTER MID-PEAK 0.14162 $ 0.15162 $ 0.15662 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08124 $ 0.09124 $ 0.09624 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04589 $ 0.05589 $ 0.06089 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 4.61 $ 4.61 $ 4.61 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 0.81 $ 0.81 $ 0.81 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.32885 $ 0.33885 $ 0.34385 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09522 $ 0.10522 $ 0.11022 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06616 $ 0.07616 $ 0.08116 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12476 $ 0.13476 $ 0.13976 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07637 $ 0.08637 $ 0.09137 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04314 $ 0.05314 $ 0.05814 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00079) (0.00079) $ (0.00079) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 1.97 $ 1.97 $ 1.97 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 0.95 $ 0.95 $ 0.95 $ 4pm - 9pm, Monday - Friday Effective: October 20, 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: October 20, 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 0.08820 $ 0.09820 $ 0.10320 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.08256 $ 0.09256 $ 0.09756 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08008 $ 0.09008 $ 0.09508 $ All other hours WINTER MID-PEAK 0.10615 $ 0.11615 $ 0.12115 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06815 $ 0.07815 $ 0.08315 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 13.60 $ 13.60 $ 13.60 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.46 $ 4.46 $ 4.46 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-8-PRI-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08405 $ 0.09405 $ 0.09905 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07836 $ 0.08836 $ 0.09336 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07634 $ 0.08634 $ 0.09134 $ All other hours WINTER MID-PEAK 0.10878 $ 0.11878 $ 0.12378 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06634 $ 0.07634 $ 0.08134 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 13.23 $ 13.23 $ 13.23 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.26 $ 4.26 $ 4.26 $ 8am - 12pm & 6pm - 11pm, Monday - Friday TOU-8-SUB-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.07876 $ 0.08876 $ 0.09376 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07320 $ 0.08320 $ 0.08820 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07153 $ 0.08153 $ 0.08653 $ All other hours WINTER MID-PEAK 0.10058 $ 0.11058 $ 0.11558 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06287 $ 0.07287 $ 0.07787 $ All other hours
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00062) (0.00062) $ (0.00062) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 15.13 $ 15.13 $ 15.13 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 4.90 $ 4.90 $ 4.90 $ 8am - 12pm & 6pm - 11pm, Monday - Friday
SUMMER ON-PEAK AND MID-PEAK
VOLTAGE DISCOUNT - DEMAND 220kV
($/kW)
$ (0.30) (0.30) $ (0.30) $ 8am - 11pm, Monday - Friday
TOU-8-SEC-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.24436 $ 0.25436 $ 0.25936 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.12057 $ 0.13057 $ 0.13557 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08008 $ 0.09008 $ 0.09508 $ All other hours WINTER MID-PEAK 0.10615 $ 0.11615 $ 0.12115 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06815 $ 0.07815 $ 0.08315 $ All other hours TOU-8-PRI-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.23375 $ 0.24375 $ 0.24875 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.11226 $ 0.12226 $ 0.12726 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07634 $ 0.08634 $ 0.09134 $ All other hours WINTER MID-PEAK 0.10878 $ 0.11878 $ 0.12378 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06634 $ 0.07634 $ 0.08134 $ All other hours TOU-8-SUB-R Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.23170 $ 0.24170 $ 0.24670 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.10682 $ 0.11682 $ 0.12182 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07153 $ 0.08153 $ 0.08653 $ All other hours WINTER MID-PEAK 0.10058 $ 0.11058 $ 0.11558 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.06287 $ 0.07287 $ 0.07787 $ All other hours
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00098) (0.00098) $ (0.00098) $ All electric usage TOU-8-SEC-RBU Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.11595 $ 0.12595 $ 0.13095 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10635 $ 0.11635 $ 0.12135 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07431 $ 0.08431 $ 0.08931 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08469 $ 0.09469 $ 0.09969 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08517 $ 0.09517 $ 0.10017 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04804 $ 0.05804 $ 0.06304 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 19.75 $ 19.75 $ 19.75 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 6.05 $ 6.05 $ 6.05 $ 4pm - 9pm, Monday - Friday Effective: October 20, 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 0.11007 $ 0.12007 $ 0.12507 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10118 $ 0.11118 $ 0.11618 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07065 $ 0.08065 $ 0.08565 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08062 $ 0.09062 $ 0.09562 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08124 $ 0.09124 $ 0.09624 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04589 $ 0.05589 $ 0.06089 $ 8am - 4pm, every day DEMAND CHARGE ($/KW) SUMMER ON-PEAK 18.80 $ 18.80 $ 18.80 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 7.03 $ 7.03 $ 7.03 $ 4pm - 9pm, Monday - Friday TOU-8-SUB-RBU Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.10331 $ 0.11331 $ 0.11831 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09522 $ 0.10522 $ 0.11022 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06616 $ 0.07616 $ 0.08116 $ 9pm - 4pm, every day WINTER MID-PEAK 0.07555 $ 0.08555 $ 0.09055 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.07637 $ 0.08637 $ 0.09137 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04314 $ 0.05314 $ 0.05814 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00062) (0.00062) $ (0.00062) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 20.77 $ 20.77 $ 20.77 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 6.71 $ 6.71 $ 6.71 $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK VOLTAGE DISCOUNT -
DEMAND 220kV ($/kW) $ (0.20) (0.20) $ (0.20) $ 4pm - 9pm, Monday - Friday
WINTER WEEKDAYS VOLTAGE
DISCOUNT - DEMAND 220kV ($/kW) $ (0.06) (0.06) $ (0.06) $ 4pm - 9pm, Monday - Friday Effective: October 20, 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 0.34960 $ 0.35960 $ 0.36460 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.12867 $ 0.13867 $ 0.14367 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.10699 $ 0.11699 $ 0.12199 $ 9pm - 4pm, every day WINTER MID-PEAK 0.19162 $ 0.20162 $ 0.20662 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.12464 $ 0.13464 $ 0.13964 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.06090 $ 0.07090 $ 0.07590 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00137) (0.00137) $ (0.00137) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00299) (0.00299) $ (0.00299) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00305) (0.00305) $ (0.00305) $ All electric usage TOU-EV-8 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.38599 $ 0.39599 $ 0.40099 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11491 $ 0.12491 $ 0.12991 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.09057 $ 0.10057 $ 0.10557 $ 9pm - 4pm, every day WINTER MID-PEAK 0.16229 $ 0.17229 $ 0.17729 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.10515 $ 0.11515 $ 0.12015 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04946 $ 0.05946 $ 0.06446 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00246) (0.00246) $ (0.00246) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00556) (0.00556) $ (0.00556) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00562) (0.00562) $ (0.00562) $ All electric usage TOU-EV-9-SEC Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.30008 $ 0.31008 $ 0.31508 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10635 $ 0.11635 $ 0.12135 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.08415 $ 0.09415 $ 0.09915 $ 9pm - 4pm, every day WINTER MID-PEAK 0.15160 $ 0.16160 $ 0.16660 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09557 $ 0.10557 $ 0.11057 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04804 $ 0.05804 $ 0.06304 $ 8am - 4pm, every day TOU-EV-9-PRI Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.27293 $ 0.28293 $ 0.28793 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10118 $ 0.11118 $ 0.11618 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07907 $ 0.08907 $ 0.09407 $ 9pm - 4pm, every day WINTER MID-PEAK 0.14947 $ 0.15947 $ 0.16447 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08947 $ 0.09947 $ 0.10447 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04589 $ 0.05589 $ 0.06089 $ 8am - 4pm, every day TOU-EV-9-SUB Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.26595 $ 0.27595 $ 0.28095 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.09522 $ 0.10522 $ 0.11022 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07378 $ 0.08378 $ 0.08878 $ 9pm - 4pm, every day WINTER MID-PEAK 0.13291 $ 0.14291 $ 0.14791 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08309 $ 0.09309 $ 0.09809 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04314 $ 0.05314 $ 0.05814 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00098) (0.00098) $ (0.00098) $ All electric usage
BUSINESS ELECTRIC VEHICLE CUSTOMERS
Effective: October 20, 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 0.12600 $ 0.13600 $ 0.14100 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11552 $ 0.12552 $ 0.13052 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07891 $ 0.08891 $ 0.09391 $ 9pm - 4pm, every day WINTER MID-PEAK 0.10024 $ 0.11024 $ 0.11524 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08125 $ 0.09125 $ 0.09625 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.07047 $ 0.08047 $ 0.08547 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00099) (0.00099) $ (0.00099) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00219) (0.00219) $ (0.00219) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00220) (0.00220) $ (0.00220) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.02 $ 12.02 $ 12.02 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.72 $ 2.72 $ 2.72 $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 2-50kV ($/kW)
$ (0.17) (0.17) $ (0.17) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.37) (0.37) $ (0.37) $ 4pm - 9pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.37) (0.37) $ (0.37) $ 4pm - 9pm, Monday - Friday
YEAR ROUND 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 0.24375 $ 0.25375 $ 0.25875 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.23034 $ 0.24034 $ 0.24534 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07441 $ 0.08441 $ 0.08941 $ 8pm - 5pm, every day WINTER MID-PEAK 0.10443 $ 0.11443 $ 0.11943 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.08460 $ 0.09460 $ 0.09960 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.07329 $ 0.08329 $ 0.08829 $ 8am - 5pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00104) (0.00104) $ (0.00104) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00230) (0.00230) $ (0.00230) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00231) (0.00231) $ (0.00231) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 11.51 $ 11.51 $ 11.51 $ 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)
$ (0.16) (0.16) $ (0.16) $ 5pm - 8pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.33) (0.33) $ (0.33) $ 5pm - 8pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.34) (0.34) $ (0.34) $ 5pm - 8pm, Monday - Friday
YEAR ROUND WIND MACHINE CREDIT
($/kW) $ (9.76) (9.76) $ (9.76) $ All electric usage
AGRICULTURE CUSTOMERS
Effective: October 20, 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 0.40681 $ 0.41681 $ 0.42181 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.11552 $ 0.12552 $ 0.13052 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07891 $ 0.08891 $ 0.09391 $ 9pm - 4pm, every day WINTER MID-PEAK 0.11492 $ 0.12492 $ 0.12992 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09294 $ 0.10294 $ 0.10794 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.08043 $ 0.09043 $ 0.09543 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00164) (0.00164) $ (0.00164) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00357) (0.00357) $ (0.00357) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00358) (0.00358) $ (0.00358) $ All electric usage DEMAND CHARGE ($/KW) YEAR ROUND WIND MACHINE CREDIT
($/kW) $ (9.76) (9.76) $ (9.76) $ All electric usage
TOU-PA-2-E5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.67217 $ 0.68217 $ 0.68717 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.23034 $ 0.24034 $ 0.24534 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.07441 $ 0.08441 $ 0.08941 $ 8pm - 5pm, every day WINTER MID-PEAK 0.11540 $ 0.12540 $ 0.13040 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.09331 $ 0.10331 $ 0.10831 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.08074 $ 0.09074 $ 0.09574 $ 8am - 5pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00164) (0.00164) $ (0.00164) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00358) (0.00358) $ (0.00358) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00358) (0.00358) $ (0.00358) $ 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 0.25915 $ 0.26915 $ 0.27415 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.12236 $ 0.13236 $ 0.13736 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08527 $ 0.09527 $ 0.10027 $ All other hours WINTER MID-PEAK 0.11396 $ 0.12396 $ 0.12896 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.07777 $ 0.08777 $ 0.09277 $ 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 0.09394 $ 0.10394 $ 0.10894 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.08736 $ 0.09736 $ 0.10236 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.08527 $ 0.09527 $ 0.10027 $ All other hours WINTER MID-PEAK 0.11396 $ 0.12396 $ 0.12896 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.07777 $ 0.08777 $ 0.09277 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 8.52 $ 8.52 $ 8.52 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 2.61 $ 2.61 $ 2.61 $ 8am - 12pm & 6pm - 11pm, Monday - Friday
YEAR ROUND WIND MACHINE CREDIT
($/kW) $ (9.76) (9.76) $ (9.76) $ All electric usage
Effective: October 20, 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 0.11034 $ 0.12034 $ 0.12534 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10129 $ 0.11129 $ 0.11629 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06954 $ 0.07954 $ 0.08454 $ 9pm - 4pm, every day WINTER MID-PEAK 0.08697 $ 0.09697 $ 0.10197 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.08748 $ 0.09748 $ 0.10248 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04942 $ 0.05942 $ 0.06442 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00098) (0.00098) $ (0.00098) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00216) (0.00216) $ (0.00216) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00219) (0.00219) $ (0.00219) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.83 $ 12.83 $ 12.83 $ 4pm - 9pm, Monday - Friday WINTER MID-PEAK 2.76 $ 2.76 $ 2.76 $ 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-PA-3-D5 Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.20823 $ 0.21823 $ 0.22323 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.19681 $ 0.20681 $ 0.21181 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06583 $ 0.07583 $ 0.08083 $ 8pm - 5pm, every day WINTER MID-PEAK 0.08804 $ 0.09804 $ 0.10304 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.08854 $ 0.09854 $ 0.10354 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.04989 $ 0.05989 $ 0.06489 $ 8am - 5pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00100) (0.00100) $ (0.00100) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00220) (0.00220) $ (0.00220) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00223) (0.00223) $ (0.00223) $ All electric usage DEMAND CHARGE ($/KW) SUMMER ON-PEAK 12.30 $ 12.30 $ 12.30 $ 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)
$ (0.18) (0.18) $ (0.18) $ 5pm - 8pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 51-219kV ($/kW)
$ (0.44) (0.44) $ (0.44) $ 5pm - 8pm, Monday - Friday
SUMMER ON-PEAK AND WINTER MID-PEAK (WEEKDAYS) VOLTAGE DISCOUNT - DEMAND 220kV ($/kW)
$ (0.44) (0.44) $ (0.44) $ 5pm - 8pm, Monday - Friday
TOU-PA-3-E Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.34909 $ 0.35909 $ 0.36409 $ 4pm - 9pm, Monday - Friday SUMMER MID-PEAK 0.10129 $ 0.11129 $ 0.11629 $ 4pm - 9pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06954 $ 0.07954 $ 0.08454 $ 9pm - 4pm, every day WINTER MID-PEAK 0.12108 $ 0.13108 $ 0.13608 $ 4pm - 9pm, every day WINTER OFF-PEAK 0.09791 $ 0.10791 $ 0.11291 $ 9pm - 8am, every day WINTER SUPER OFF-PEAK 0.04022 $ 0.05022 $ 0.05522 $ 8am - 4pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00152) (0.00152) $ (0.00152) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00342) (0.00342) $ (0.00342) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00345) (0.00345) $ (0.00345) $ All electric usage Effective: October 20, 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 0.56802 $ 0.57802 $ 0.58302 $ 5pm - 8pm, Monday - Friday SUMMER MID-PEAK 0.19681 $ 0.20681 $ 0.21181 $ 5pm - 8pm, Saturday, Sunday, & holidays* SUMMER OFF-PEAK 0.06583 $ 0.07583 $ 0.08083 $ 8pm - 5pm, every day WINTER MID-PEAK 0.12634 $ 0.13634 $ 0.14134 $ 5pm - 8pm, every day WINTER OFF-PEAK 0.10210 $ 0.11210 $ 0.11710 $ 8pm - 8am, every day WINTER SUPER OFF-PEAK 0.04174 $ 0.05174 $ 0.05674 $ 8am - 5pm, every day
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 2-50kV ($/kWh) $ (0.00152) (0.00152) $ (0.00152) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 51-219kV ($/kWh) $ (0.00342) (0.00342) $ (0.00342) $ All electric usage
YEAR ROUND VOLTAGE DISCOUNT -
ENERGY 220kV ($/kWh) $ (0.00345) (0.00345) $ (0.00345) $ All electric usage TOU-PA-3-A Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.22617 $ 0.23617 $ 0.24117 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.10598 $ 0.11598 $ 0.12098 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07498 $ 0.08498 $ 0.08998 $ All other hours WINTER MID-PEAK 0.09901 $ 0.10901 $ 0.11401 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.07120 $ 0.08120 $ 0.08620 $ All other hours TOU-PA-3-B Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.08250 $ 0.09250 $ 0.09750 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 0.07670 $ 0.08670 $ 0.09170 $ 8am - 12pm & 6pm - 11pm, Monday - Friday SUMMER OFF-PEAK 0.07498 $ 0.08498 $ 0.08998 $ All other hours WINTER MID-PEAK 0.09901 $ 0.10901 $ 0.11401 $ 8am - 9pm, Monday - Friday WINTER OFF-PEAK 0.07120 $ 0.08120 $ 0.08620 $ All other hours DEMAND CHARGE ($/KW) SUMMER ON-PEAK 9.03 $ 9.03 $ 9.03 $ 12pm - 6pm, Monday - Friday SUMMER MID-PEAK 2.64 $ 2.64 $ 2.64 $ 8am - 12pm & 6pm - 11pm, Monday - Friday Effective: October 20, 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 0.07614 $ 0.08614 $ 0.09114 $ All electric usage LS-3
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.07623 $ 0.08623 $ 0.09123 $ All electric usage AL-2-F
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.07623 $ 0.08623 $ 0.09123 $ All electric usage AL-2-GF Summer - June through September; Winter - October through May GENERATION CHARGE ($/KWH) SUMMER ON-PEAK 0.17096 $ 0.18096 $ 0.18596 $ 8am - 4pm, every day SUMMER OFF-PEAK 0.07623 $ 0.08623 $ 0.09123 $ All other hours WINTER ON-PEAK 0.11585 $ 0.12585 $ 0.13085 $ 8am - 4pm, every day WINTER OFF-PEAK 0.07623 $ 0.08623 $ 0.09123 $ All other hours TC-1
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.10561 $ 0.11561 $ 0.12061 $ All electric usage WTR
GENERATION CHARGE ($/KWH) YEAR-ROUND 0.12192 $ 0.13192 $ 0.13692 $ 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: October 20, 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 $ 0.009294
GS-12 $ (0.00041) 0.00595 $ 0.009294
TC-13 $ (0.00044) 0.00595 $ 0.009294
GS-24 $ (0.00043) 0.00595 $ 0.009294
TOU-GS-35 $ (0.00042) 0.00595 $ 0.009294
TOU-8-Sec6 $ (0.00041) 0.00595 $ 0.009294
TOU-8-Pri6 $ (0.00040) 0.00595 $ 0.009294
TOU-8-Sub6 $ (0.00038) 0.00595 $ 0.009294
Small AG7 $ (0.00042) 0.00595 $ 0.009294
Large AG8 $ (0.00042) 0.00595 $ 0.009294
St. Lighting9 $ (0.00053) 0.00595 $ 0.009294
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
p
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: October 20, 2025
Power Charge Indifference Adjustment
Rate Group PCIA Vintage
Domestic1 $ 2022 (0.01310)
GS-12 $ 2021 (0.00690)
TC-13 $ 2021 (0.00733)
GS-24 $ 2021 (0.00723)
TOU-GS-35 $ 2021 (0.00702)
TOU-8-Sec6 $ 2021 (0.00684)
TOU-8-Pri6 $ 2021 (0.00670)
TOU-8-Sub6 $ 2021 (0.00633)
Small AG7 $ 2021 (0.00708)
Large AG8 $ 2021 (0.00700)
St. Lighting9 $ 2021 (0.00884)
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.
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.
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 9.1
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Tiffany Law, Chief Financial Officer
Approved: Joe Mosca, Chief Executive Officer
Subject: RECEIVE THE FINANCIAL AUDIT REPORT FOR THE FISCAL YEAR ENDED JUNE 30, 2025 AND 2024 FROM SORREN CPAs, P.C.
Date: November 10, 2025
-------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☒ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☐ Not Applicable:
RECOMMENDED ACTION
Receive the Year-End Financial Statements and Independent Auditor’s Report for the fiscal year ended June 30, 2025 and 2024 from Sorren CPAs, P.C.
BACKGROUND
The financial statements of the Orange County Power Authority (OCPA) are audited annually by an independent certified public accounting firm, with each audit required to be completed within six months following the fiscal year-end.
In December 2021, Sorren CPAs, P.C. (formerly Pisenti & Brinker, LLP), a certified public accounting firm with extensive experience auditing Community Choice Aggregators (CCAs) and other California local government entities, completed OCPA’s first independent audit for the fiscal period ending June 30, 2021. Sorren subsequently performed the audits for the fiscal years ending June 30, 2022, through June 30, 2024. Each audit resulted in a clean opinion, confirming that the financial statements were materially accurate and fairly presented OCPA’s financial position. No material weaknesses in internal controls were identified, demonstrating the effectiveness of OCPA’s internal control framework.
The attached reports present the results of Sorren’s audit for the fiscal year ending June 30, 2025, and provide detailed insights into OCPA’s financial position and operating performance.
DISCUSSION
The annual audit of OCPA’s financial statements has been completed, with Sorren issuing the comparative audit report. The auditors provided a clean audit opinion, confirming the material accuracy of the financial statements and identifying no material weaknesses in internal control.
Key highlights from the report include:
• Adherence to Generally Accepted Auditing Standards (GAAS), ensuring integrity and thoroughness in the audit process.
• Compliance of OCPA’s financial statements with Generally Accepted Accounting Principles (GAAP), demonstrating transparency and consistency with standard accounting practices.
• No revisions required to the financial statements prepared by OCPA staff, reflecting strong accuracy and reliability in financial reporting.
• Validation of OCPA’s financial strength, as evidenced in the Independent Auditor’s comprehensive report.
• Affirmation of appropriate and transparent operations, as noted in the conclusion of the Required Board Communications.
Financial Highlights for the Fiscal Year Ended June 30, 2025:
The audited financial statements for the fiscal year ending June 30, 2025, representing OCPA’s second full year of operations, highlight the agency’s continued financial strength and stability.
Despite several challenges, including maintaining the 2024 rate design through 2025 to shield customers from rate volatility, the City of Irvine’s unexpected shift from 100% Renewable Choice to Basic Choice in February 2025, and higher-than-expected Renewable Portfolio Standard Market Price Benchmarks published by the California Public Utilities Commission on October 1, 2025, OCPA achieved results consistent with the June 2025 reforecast.
During FY2024/25, OCPA’s net position increased by approximately $150k, bringing total operating reserves to $45 million as of June 30, 2025, in line with expectations. At year-end, OCPA maintained approximately 119 days of liquidity on hand, equivalent to 16% of total operating expenses. These results reflect OCPA’s ability to balance customer affordability with prudent financial management while sustaining long-term fiscal health.
ATTACHMENTS
Attachment A – Sorren Report to the Board of Directors
Attachment B – Orange County Power Authority’s Audited Financial Statements for the Fiscal Year Ended June 30, 2025 and 2024 with Report of Independent Auditors CPAs, PC
Report to the
Board of
Directors
Orange County Power Authority
For the year ended June 30, 2025
Ph: (707) 542-3343 sorren.com
3562 Round Barn Cir, #200, Santa Rosa, CA 95403
To the Board of Directors
Orange County Power Authority
15642 Sand Canyon Avenue
P.O. Box 54283
Irvine, CA 92619-4283
We are pleased to present this report related to our audit of the financial statements of Orange County Power Authority (“OCPA”) as of and for the year ended June 30, 2025. Our report summarizes certain matters required by professional standards to be communicated to you in your oversight responsibility for OCPA’s financial reporting process.
This report is intended solely for the information and use of the Board of Directors and management of OCPA and is not intended to be and should not be used by anyone other than these specified parties. It will be our pleasure to respond to any questions you have about this report. We appreciate the opportunity to continue to be of service to Orange County Power Authority.
Santa Rosa, California
November 5, 2025
cc: Tiffany Law, Chief Financial Officer
TABLE OF CONTENTS
Required Communications 1
Significant Accounting Estimates 3
Appendices
Appendix A—Significant Written Communications Between Management and Our Firm
• Representation Letter 4
1 REQUIRED COMMUNICATIONS
The following required communications summarize our responsibilities regarding the financial statement audit as well as observations from our audit that are significant and relevant to your responsibility to oversee the financial reporting process.
Our Responsibilities
We described our responsibilities under auditing standards generally accepted in the United States of America have been described to you in our engagement letter dated August 1, 2025. Our audit of the financial statements does not relieve management or you of your responsibilities, which are also described in that letter.
Planned Scope and Timing
We previously issued a separate communication dated October 2, 2025 regarding the planned scope and timing of our audit and identified significant risks.
Accounting Policies and Practices
Preferability of Accounting Policies and Practices
Under accounting principles generally accepted in the United States of America, in certain circumstances, management may select among alternative accounting practices. In our view, in such circumstances, management has selected the preferable accounting practice.
Adoption of, or Change in, Accounting Policies
Management has the ultimate responsibility for the appropriateness of the accounting policies used by OCPA. OCPA did not change any existing significant accounting policies. As disclosed in Note 11, OCPA adopted GASB 102-104 which did not have a significant effect on the financial statements.
Significant Accounting Policies
We did not identify any significant accounting policies in controversial or emerging areas for which there is a lack of authoritative guidance or consensus.
Significant or Unusual Transactions
We did not identify any significant unusual transactions.
Management’s Judgments and Accounting Estimates
Summary information about the process used by management in formulating particularly sensitive accounting estimates and about our conclusions regarding the reasonableness of those estimates is in the attached Summary of Significant Accounting Estimates.
Audit Adjustments and Uncorrected Misstatements
We are not aware of any uncorrected misstatements other than misstatements that are clearly trivial. 2 Observations About the Audit Process
Disagreements With Management
We encountered no disagreements with management over the application of significant accounting principles, the basis for management’s judgments on any significant matters, the scope of the audit or significant disclosures to be included in the financial statements.
Consultations With Other Accountants
We are not aware of any consultations management had with other accountants about accounting or auditing matters.
Significant Issues Discussed With Management
No significant issues arising from the audit were discussed or were the subject of correspondence with management.
Significant Difficulties Encountered in Performing the Audit We did not encounter any significant difficulties in dealing with management during the audit.
Shared Responsibilities for Independence
Auditor independence is a joint responsibility and is managed most effectively when management, audit committees, and audit firms work together in considering compliance with applicable independence rules.
For Sorren CPAs P.C. (the Firm) to fulfill its professional responsibility to maintain and monitor independence, management, the Board of Directors, and the Firm each play an important role.
Our Responsibilities
• We are required to maintain both independence of mind and in appearance when providing audit and other attestation services. It is our responsibility to ensure that the general requirements for performing nonattest services are adhered to and included in all letters of engagement. • We are required to maintain a system of quality management over compliance with independence rules and firm policies.
OCPA’s Responsibilities
• Timely inform the Firm, before the effective date of transactions or other business changes, of the following:
− New affiliates, directors, or officers.
• Understand and conclude on the permissibility, prior to OCPA’s, officers, directors, or persons in a decision-making capacity, engaging in business relationships with the Firm. • Not entering into relationships resulting in close family members of the Firm covered persons, temporarily or permanently acting as an officer, director, or person in an accounting or financial reporting oversight role at the Company.
Significant Written Communications Between Management and Our Firm Copies of significant written communications between our firm and the management of OCPA, including the representation letter provided to us by management, are attached as Appendix A. 3 SIGNIFICANT ACCOUNTING ESTIMATES
Accounting estimates are an integral part of the preparation of financial statements and are based upon management’s current judgment. The process used by management encompasses their knowledge and experience about past and current events, and certain assumptions about future events. You may wish to monitor throughout the year the process used to determine and record these accounting estimates.
The following summarizes the significant accounting estimates reflected in OCPA’s June 30, 2025 financial statements.
Significant Accounting Estimates
Accrued Revenue
Accounting policy/
Management’s estimation
process
Management’s estimate of accrued revenue includes historical trends and anticipated energy usage.
Basis for our conclusion on
the reasonableness of the
estimate
We tested management’s estimate analytically and determined management’s estimate to be reasonable in relation to the financial statements taken as a whole.
Cost of Electricity
Accounting policy/
Management’s estimation
process
Management’s estimate of accrued cost of electricity includes historical trends and anticipated energy usage.
Basis for our conclusion on
the reasonableness of the
estimate
We tested management’s estimate through subsequent
disbursements and analytical procedures and determined
management’s estimate to be reasonable in relation to the financial statements taken as a whole.
Allowance for Uncollectible Accounts
Accounting policy/
Management’s estimation
process
Management’s estimate of the allowance for uncollectible accounts includes historical collection trends and anticipated future collections.
Basis for our conclusion on
the reasonableness of the
estimate
We evaluated the key factors and assumptions used to develop the estimate in determining that the allowance is reasonable in relation to the financial statements taken as a whole.
APPENDIX A
Significant Written Communications Between Management and Our Firm
November 5, 2024
Sorren CPAs, P.C.
3562 Round Barn Circle, Suite 200
Santa Rosa, CA 95403
This representation letter is provided in connection with your audit of the basic financial statements of Orange County Power Authority (“OCPA”) as of and for the years ended June 30, 2025 and 2024, for the purpose of expressing an opinion on whether the financial statements are presented fairly, in all material respects, in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP).
We confirm, to the best of our knowledge and belief, that as of November 5, 2025:
Financial Statements
1. We have fulfilled our responsibilities, as set out in the terms of the audit engagement letter dated August 1, 2025, for the preparation and fair presentation of the financial statements referred to above in accordance with U.S. GAAP.
2. We acknowledge our responsibility for the design, implementation and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.
3. We acknowledge our responsibility for the design, implementation and maintenance of controls to prevent and detect fraud.
4. The methods, data, and significant assumptions used by us in making accounting estimates and their related disclosures are appropriate to achieve recognition, measurement, or disclosure that is reasonable in the context of U.S. GAAP, and reflect our judgment based on our knowledge and experience about past and current events, and our assumptions about conditions we expect to exist and courses of action we expect to take.
5. Related-party transactions have been recorded in accordance with the economic substance of the transaction and appropriately accounted for and disclosed in accordance with the requirements of U.S. GAAP.
6. The financial statements properly classify all funds and activities in accordance with GASB Statement No. 54, Fund Balance Reporting and Governmental Fund Type Definitions, as amended.
7. All events subsequent to the date of the financial statements, and for which U.S. GAAP requires adjustment or disclosure, have been adjusted or disclosed.
8. The effects of all known actual or possible litigation and claims have been accounted for and disclosed in accordance with U.S. GAAP.
9. Management has followed applicable laws and regulations in adopting, approving and amending budgets.
10. Risk disclosures associated with deposit and investment securities and derivative transactions are presented in accordance with GASB requirements.
11. Provisions for uncollectible receivables have been properly identified and recorded.
12. Capital assets, including infrastructure, intangible assets, and right of use assets are properly capitalized, reported and, if applicable, depreciated.
13. The government properly separated information in debt disclosures related to direct borrowings and direct placements of debt from other debt and disclosed any unused lines of credit, collateral pledged to secure debt, terms in the debt agreements related to significant default or termination events with finance-related consequences and significant subjective acceleration clauses in accordance with GASB Statement No. 88, Certain Disclosures Related to Debt, including Direct Borrowings and Direct Placements.
14. Components of net position (net investment in capital assets, restricted, and unrestricted) and classifications of fund balance (nonspendable, restricted, committed, assigned, and unassigned) are properly classified and, if applicable, approved.
15. Leases have been properly identified, recorded, and disclosed in accordance with GASB Statement No. 87, Leases.
16. Subscription-based technology information arrangements (SBITAs) have been properly identified, recorded, and disclosed in accordance with GASB Statement No. 96, Subscription-Based Information Technology Arrangements.
17. There are no concentrations or constraints requiring disclosure in accordance with GASB Statement No. 102, Certain Risk Disclosures.
18. We have no direct or indirect legal or moral obligation for any debt of any organization, public or private, or to special assessment bond holders, that is not disclosed in the financial statements.
19. We have complied with all aspects of laws, regulations and provisions of contracts and agreements that would have a material effect on the financial statements in the event of noncompliance. In connection therewith, we specifically represent that we are responsible for determining that we are not subject to the requirements of the Single Audit Act because we have not received, expended or otherwise been the beneficiary of the required amount of federal awards during the period of this audit.
20. We have no knowledge of any uncorrected misstatements in the financial statements.
Information Provided
21. We have provided you with:
a. Access to all information of which we are aware that is relevant to the preparation and fair presentation of the basic financial statements such as records, documentation and other matters.
b. Additional information that you have requested from us for the purpose of the audit.
c. Unrestricted access to persons within OCPA from whom you determined it necessary to obtain audit evidence.
d. Minutes of the meetings of the governing board and committees, or summaries of actions of recent meetings for which minutes have not yet been prepared.
22. All transactions have been recorded in the accounting records and are reflected in the basic financial statements.
23. We have disclosed to you the results of our assessment of risk that the basic financial statements may be materially misstated as a result of fraud.
24. We have no knowledge of allegations of fraud or suspected fraud affecting OCPA’s basic financial statements involving:
a. Management.
b. Employees who have significant roles in internal control. c. Others where the fraud could have a material effect on the basic financial statements.
25. We have no knowledge of any allegations of fraud or suspected fraud affecting the OCPA’s basic financial statements received in communications from employees, former employees, analysts, regulators, or others.
26. We have no knowledge of noncompliance or suspected noncompliance with laws and regulations.
27. We are not aware of any pending or threatened litigation, claims or assessments; unasserted claims or assessments that are probable of assertion and must be disclosed in accordance with Accounting Standards Codification (ASC) Topic 450, Contingencies; violations or possible violations of laws and regulations; or other matters, including gain or loss contingencies, whose effects should be considered when preparing the financial statements.
28. We have disclosed to you the identity of all of OPCA’s related parties and all the related-party relationships and transactions of which we are aware.
29. We are aware of no significant deficiencies in internal control over financial reporting, including significant deficiencies or material weaknesses, in the design or operation of internal controls that could adversely affect OCPA’s ability to record, process, summarize and report financial data.
30. There have been no communications from regulatory agencies concerning noncompliance with, or deficiencies in, financial reporting practices.
Supplementary Information
31. With respect to the Management’s Discussion and Analysis presented as required by GAAP and the Governmental Accounting Standards Board to supplement the basic financial statements:
a. We acknowledge our responsibility for the presentation of such required supplementary information.
b. We believe such required supplementary information is measured and presented in accordance with guidelines prescribed by U.S. GAAP. c. The methods of measurement or presentation have not changed from those used in the prior period.
Tiffany Law, Chief Financial Officer
Orange County Power Authority
Mike Maher, Accountant
Michael Maher
Financial
Statements
Fiscal Years Ended June 30, 2025 and 2024
with Report of Independent Auditors
TABLE OF CONTENTS
Independent Auditor’s Report ………………………………………………….......... 1 Management’s Discussion and Analysis ……………………………………………... 4 Basic Financial Statements:
Statements of Net Position …………………………………………………… 9
Statements of Revenues, Expenses and Changes in Net Position …................ 10 Statements of Cash Flows ……………………………………………………. 11
Notes to the Basic Financial Statements ……………………………………… 13 Ph: (707) 542-3343 sorren.com
3562 Round Barn Cir, #200, Santa Rosa, CA 95403
Independent Auditor's Report
To the Board of Directors
Orange County Power Authority
Opinion
We have audited the accompanying financial statements of Orange County Power Authority (OCPA), which comprise the statements of net position as of June 30, 2025 and 2024, the related statements of revenue, expenses and changes in net position, and cash flows for the years then ended, and the related notes to the financial statements.
In our opinion, the accompanying financial statements present fairly, in all material respects, the financial position of OCPA as of June 30, 2025 and 2024, and the results of its operations and cash flows for the years then ended in accordance with accounting principles generally accepted in the United States of America.
Basis for Opinion
We conducted our audits in accordance with auditing standards generally accepted in the United States of America (GAAS). Our responsibilities under those standards are further described in the Auditor’s Responsibilities for the Audit of the Financial Statements section of our report. We are required to be independent of OCPA and to meet our other ethical responsibilities, in accordance with the relevant ethical requirements relating to our audits. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.
Responsibilities of Management for the Financial Statements Management is responsible for the preparation and fair presentation of the financial statements in accordance with accounting principles generally accepted in the United States of America, and for the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.
In preparing the financial statements, management is required to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about OCPA’s ability to continue as a going concern within one year after the date that the financial statements are issued or available to be issued, including any currently known information that may raise substantial doubt shortly thereafter.
Independent Auditor's Report (continued)
Auditor's Responsibilities for the Audit of the Financial Statements Our objectives are to obtain reasonable assurance about whether the financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s report that includes our opinion. Reasonable assurance is a high level of assurance but is not absolute assurance and therefore is not a guarantee that an audit conducted in accordance with GAAS will always detect a material misstatement when it exists. The risk of not detecting a material misstatement resulting from fraud is higher than for one resulting from error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the override of internal control. Misstatements are considered material if there is a substantial likelihood that, individually or in the aggregate, they would influence the judgment made by a reasonable user based on the financial statements.
In performing an audit in accordance with GAAS, we:
• Exercise professional judgment and maintain professional skepticism throughout the audit. • Identify and assess the risks of material misstatement of the financial statements, whether due to fraud or error, and design and perform audit procedures responsive to those risks. Such procedures include examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements.
• Obtain an understanding of internal control relevant to the audit in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of OCPA’s internal control. Accordingly, no such opinion is expressed. • Evaluate the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluate the overall presentation of the financial statements.
• Conclude whether, in our judgment, there are conditions or events, considered in the aggregate, that raise substantial doubt about OCPA’s ability to continue as a going concern for a reasonable period of time.
We are required to communicate with those charged with governance regarding, among other matters, the planned scope and timing of the audit, significant audit findings, and certain internal control-related matters that we identified during the audit.
Independent Auditor's Report (continued)
Required Supplementary Information
Accounting principles generally accepted in the United States of America require that management's discussion and analysis be presented to supplement the basic financial statements. Such information is the responsibility of management and, although not a part of the basic financial statements, is required by the Governmental Accounting Standards Board who considers it to be an essential part of financial reporting for placing the basic financial statements in an appropriate operational, economic, or historical context. We have applied certain limited procedures to the required supplementary information in accordance with auditing standards generally accepted in the United States of America, which consisted of inquiries of management about the methods of preparing the information and comparing the information for consistency with management's responses to our inquiries, the basic financial statements, and other knowledge we obtained during our audit of the basic financial statements. We do not express an opinion or provide any assurance on the information because the limited procedures do not provide us with sufficient evidence to express an opinion or provide any assurance.
Santa Rosa, California
November 5, 2025
ORANGE COUNTY POWER AUTHORITY
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEARS ENDED JUNE 30, 2025 AND 2024
4 The purpose of management’s discussion and analysis (MD&A) is to help stakeholders and other readers understand what the financial statements and notes in this report say about Orange County Power Authority’s (OCPA) financial health and why it has changed since last year. It contains information drawn from other parts of the report, accompanied by explanations informed by the finance staff’s knowledge of OCPA’s finances.
If you have questions about this report or require further information, our website at https://www.ocpower.org/contact-us/ contains information on how to contact us.
Overview of the Financial Statements
OCPA’s financial report contains basic financial statements, which include:
o The Statements of Net Position include all of OCPA’s assets, liabilities, and net position and provides information about the nature and amounts of resources and obligations at a specific point in time.
o The Statements of Revenues, Expenses, and Changes in Net Position report all of OCPA’s revenue and expenses for the years shown.
o The Statements of Cash Flows report on the cash provided and used by operating activities, as well as other sources and uses, such as capital and investing activities. o The notes to the Basic Financial Statements provide additional details and information related to the basic financial statements.
ORANGE COUNTY POWER AUTHORITY
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEARS ENDED JUNE 30, 2025 AND 2024
5 Financial Summary
OCPA’s Net Position
2025 2024 2023
Current assets $ 130,247,587 $ 158,152,396 $ 88,628,950 Noncurrent assets 14,107,749 14,278,857 5,000,000
Total assets 144,355,336 172,431,253 93,628,950
Current liabilities 60,483,211 74,718,452 47,445,424
Noncurrent liabilities 8,857,683 7,847,131 7,646,933
Total liabilities 69,340,894 82,565,583 55,092,357
Deferred inflows of resources 30,000,000 45,000,000 -
Net position
Net investment in capital assets 206,965 - -
Restricted for security collateral 1,241,140 - -
Unrestricted 43,566,337 44,865,670 38,536,593
Total net position $ 45,014,442 $ 44,865,670 $ 38,536,593 As of June 30, 2025, OCPA’s total net position was approximately $45,014,000, an increase of $149,000 compared to June 30, 2024.
OCPA’s Changes in Net Position
2025 2024 2023
Operating revenues $ 283,584,250 $ 337,084,243 $ 275,734,014 Nonoperating revenues 4,630,570 2,467,019 963,543
Total income 288,214,820 339,551,262 276,697,557
Operating expenses 287,767,291 333,022,450 237,669,189
Nonoperating expenses 298,757 199,735 701,477
Total expenses 288,066,048 333,222,185 238,370,666
Change in net position $ 148,772 $ 6,329,077 $ 38,326,891 The decrease in operating revenues and operating expenses from 2024 to 2025 was primarily attributable to the City of Huntington Beach’s return to Southern California Edison (SCE) service in June 2024, partially offset by revenue from the rate stabilization fund and higher investment income.
ORANGE COUNTY POWER AUTHORITY
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEARS ENDED JUNE 30, 2025 AND 2024
6 Detailed Analysis
Current assets decreased from $158,200,000 at the end of fiscal year 2024 to $130,200,000 at the end of fiscal year 2025. This decrease was primarily due to the withdrawal of the City Huntington Beach as well as accelerated payments made for certain energy products during fiscal year 2025.
Current assets at the end of fiscal year 2025 were primarily comprised of cash and investments of $80,635,000, accounts receivable of $14,300,000, accrued revenue of $14,058,000 and deposits of $16,370,000.
Noncurrent assets remained stable from 2024 to 2025 and mostly consisted of cash restricted for security purposes and collateral deposits required to be paid to energy suppliers. Also included at the end of fiscal year 2025 were capital assets, comprised of equipment, leasehold improvements, and right-of-use asset related to OCPA’s offices.
The largest component of current liabilities is the cost of electricity delivered to customers that is not yet paid by OCPA. Current liabilities for the cost of energy decreased in fiscal year 2025 due to less quantities purchased as a result of the City of Huntington Beach withdrawal, as well as changes in the payment terms for certain energy products. Accrued cost of electricity was approximately $58,010,000 and $71,613,000 at the end of fiscal years 2025 and 2024, respectively.
Noncurrent liabilities consist of a loan due to the City of Irvine and a lease liability related to right-to-use lease asset. With the exception of the addition of the lease liability in 2025, other noncurrent liabilities were fairly stable from 2024.
In fiscal year 2024, OCPA set aside $45,000,000 in a Rate Stabilization Fund in accordance with the Board approved Rate Stabilization Fund Policy. The Rate Stabilization Fund is designed to defer revenue for future years when financial conditions necessitate draws on reserves. By deferring and subsequently recognizing revenue, OCPA aims to mitigate the need for sudden rate increases rising from spikes in energy costs, regulatory shifts, and other unforeseen circumstances.
OCPA recognized $15,000,000 in revenue from the Rate Stabilization Fund in fiscal year 2025.
Operating revenues increased from fiscal years 2023 to 2024, despite the $45,000,000 revenue deferral recognized in 2024. The increase was primarily due to territory expansions and increases in rates charged to customers. However, there was a significant decrease from 2024 to 2025 due to the City of Huntington Beach withdrawal, despite being partially offset by recognition of $15,000,000 in revenue from the Rate Stabilization Fund in 2025.
ORANGE COUNTY POWER AUTHORITY
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEARS ENDED JUNE 30, 2025 AND 2024
7 Detailed Analysis (continued)
The largest operating expense is the cost of electricity which increased from 2023 to 2024 due to territory expansion and higher prices charged by electricity providers but decreased from 2024 to 2025 as a result of the member withdrawal previously mentioned. As OCPA continued to strengthen its operations over the last several years, there was an overall increase in expenses related to staff compensation for an expanded workforce, the rollout of customer incentive and rebate programs, and other general and administrative costs.
Nonoperating revenues include interest and investment income, with year-over-year changes reflecting higher average balances in diversified interest-bearing accounts.
Significant Capital Asset and Long-Term Financing Activity OCPA does not own assets used for electric generation or distribution. Included in capital assets are office equipment, such as computers, furniture, leasehold improvements, and a right-of-use lease asset.
Assets that are leased by OCPA, such as office premises, are recorded in the Statements of Net Position with a related liability for future obligations.
During 2021, OCPA borrowed approximately $2,700,000 from the City of Irvine, which is classified as a noncurrent liability. These funds were primarily used to cover formation costs paid directly to professional consultants by the City of Irvine, and pre-launch costs of $2,500,000 incurred during OCPA’s start-up phase. Additionally, OCPA borrowed an additional $5,000,000 from the City of Irvine to be used as collateral for its bank credit facility.
ORANGE COUNTY POWER AUTHORITY
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEARS ENDED JUNE 30, 2025 AND 2024
8 Currently Known Facts, Decisions, or Conditions
OCPA continues to operate in a challenging market environment shaped by both regulatory changes and evolving energy market conditions for 2026.
On the regulatory side, the California Public Utilities Commission’s (CPUC) Track-1 decision modified the calculation of the Resource Adequacy (RA) Market Price Benchmark to use a three-year historical average instead of a single-year snapshot. Although intended as a short-term adjustment, this change disproportionately benefits SCE’s bundled customers by lowering their generation rates while increasing Power Charge Indifference Adjustment (PCIA) costs for Community Choice Aggregators (CCAs) and their customers.
On the market side, prices for energy, RA, and Renewable Portfolio Standard (RPS) attributes have declined statewide. These lower market prices reduce SCE’s forecasted generation costs and further lower its bundled generation rates. In addition, SCE is expected to issue a one-time refund to bundled customers in 2026 for 2025 overcollections, further reducing its generation rates.
Collectively, these factors are expected to significantly decrease SCE’s 2026 generation rates while substantially increasing PCIA charges.
To manage these pressures and maintain financial and operational sustainability, OCPA plans to utilize the remaining $30 million balance in the Rate Stabilization Fund to help mitigate the anticipated impacts on financial performance and customer rates in 2026.
BASIC FINANCIAL STATEMENTS
ORANGE COUNTY POWER AUTHORITY
STATEMENTS OF NET POSITION
JUNE 30, 2025 AND 2024
9 The accompanying notes are an integral part of these financial statements. 2025 2024
ASSETS
Current assets
Cash - unrestricted $ 58,486,083 $ 79,735,416
Cash - restricted 200,000 600,000
Investments 21,948,918 19,975,918
Accounts receivable, net of allowance 14,299,580 26,828,551 Accrued revenue 14,057,594 20,085,848
Other receivables 4,801,083 6,977,630
Prepaid expenses 84,241 193,444
Deposits 16,370,088 3,755,589
Total current assets 130,247,587 158,152,396
Noncurrent assets
Cash - restricted 6,441,140 5,000,000
Deposits 6,578,659 9,278,857
Capital assets, net of depreciation and amortization 1,087,950 - Total noncurrent assets 14,107,749 14,278,857
Total assets 144,355,336 172,431,253
LIABILITIES
Current liabilities
Accrued cost of electricity 58,010,025 71,612,632
Accounts payable 735,275 1,005,354
Other accrued liabilities 1,017,276 895,522
User taxes and energy surcharges due to other governments 605,921 1,204,944 Lease liability 114,714 -
Total current liabilities 60,483,211 74,718,452
Noncurrent liabilities
Loans payable 7,527,841 7,527,841
Accrued interest 563,571 319,290
Lease liability 766,271 -
Total noncurrent liabilities 8,857,683 7,847,131
Total liabilities 69,340,894 82,565,583
DEFERRED INFLOWS OF RESOURCES
Rate Stabilization Fund 30,000,000 45,000,000
NET POSITION
Net investment in capital assets 206,965 -
Restricted for security collateral 1,241,140 -
Unrestricted 43,566,337 44,865,670
Total net position $ 45,014,442 $ 44,865,670
ORANGE COUNTY POWER AUTHORITY
STATEMENTS OF REVENUES, EXPENSES
AND CHANGES IN NET POSITION
YEARS ENDED JUNE 30, 2025 AND 2024
10 The accompanying notes are an integral part of these financial statements. 2025 2024
OPERATING REVENUES
Electricity sales, net $ 268,450,943 $ 382,084,243
Revenue from (deferred to) Rate Stabilization Fund 15,000,000 (45,000,000) Other income 133,307 -
Total operating revenues 283,584,250 337,084,243
OPERATING EXPENSES
Cost of electricity 275,724,133 321,916,334
Contract services 6,049,763 7,279,861
Staff compensation 4,388,061 2,563,579
Other operating expenses 1,423,819 1,262,676
Depreciation and amortization 181,515 -
Total operating expenses 287,767,291 333,022,450
Operating income (loss) (4,183,041) 4,061,793
NONOPERATING REVENUES (EXPENSES)
Investment income 4,630,570 2,467,019
Interest expense (298,757) (199,735)
Nonoperating revenues (expenses), net 4,331,813 2,267,284 CHANGE IN NET POSITION 148,772 6,329,077
Net position at beginning of year 44,865,670 38,536,593 Net position at end of year $ 45,014,442 $ 44,865,670
ORANGE COUNTY POWER AUTHORITY
STATEMENTS OF CASH FLOWS
YEARS ENDED JUNE 30, 2025 AND 2024
11 The accompanying notes are an integral part of these financial statements. 2025 2024
CASH FLOWS FROM OPERATING ACTIVITIES
Receipts from customers $ 290,540,829 $ 388,331,143
Receipts from wholesale sales and other operating receipts 34,113,300 10,015,931 Receipts of security deposits 1,472,695 1,466,303
Payments to suppliers for electricity (320,719,896) (297,182,886) Payments for other goods and services (7,689,536) (8,505,009) Payments for deposits and collateral (11,622,600) (12,647,698) Payments for staff compensation (4,127,457) (2,444,883) Payments of taxes and energy surcharges to other governments (4,131,684) (7,773,881) Net cash provided (used) by operating activities (22,164,349) 71,259,020
CASH FLOWS FROM CAPITAL AND RELATED
FINANCING ACTIVITIES
Payments of lease liability (66,215) -
Purchases of capital assets (376,742) -
Net cash used by capital and related financing activities (442,957) -
CASH FLOWS FROM INVESTING ACTIVITIES
Investment income received 4,333,780 2,199,657
Proceeds from investment sales and maturities of investments 2,000,000 - Purchase of investments (3,934,667) (19,950,556)
Net cash provided (used) by investing activities 2,399,113 (17,750,899) Net change in cash (20,208,193) 53,508,121
Cash at beginning of year 85,335,416 31,827,295
Cash at end of year $ 65,127,223 $ 85,335,416
Reconciliation to the Statements of Net Position
Cash - unrestricted, current $ 58,486,083 $ 79,735,416
Cash - restricted, current 200,000 600,000
Cash - restricted, noncurrent 6,441,140 5,000,000
Total cash at end of year $ 65,127,223 $ 85,335,416
ORANGE COUNTY POWER AUTHORITY
STATEMENTS OF CASH FLOWS (CONTINUED)
YEARS ENDED JUNE 30, 2025 AND 2024
12 The accompanying notes are an integral part of these financial statements.
RECONCILIATION OF OPERATING INCOME (LOSS) TO NET
CASH PROVIDED (USED) BY OPERATING ACTIVITIES
2025 2024
Operating income (loss) $ (4,183,041) $ 4,061,793
Adjustments to reconcile operating income (loss) to net cash provided (used) by operating activities
Depreciation and amortization expense 181,515 -
(Increase) decrease in:
Accounts receivable 12,528,971 (3,459,826)
Other receivables 2,381,817 (3,463,685)
Accrued revenue 6,028,254 1,977,614
Prepaid expenses 109,204 11,163,116
Deposits and other assets (9,835,420) (11,293,483)
Increase (decrease) in:
Accrued cost of electricity (13,602,607) 26,873,013
Accounts payable (281,446) 493,611
Other accrued liabilities 107,427 (48,364)
User taxes and energy surcharges due
to other governments (599,023) (44,769)
Rate Stabilization Fund (15,000,000) 45,000,000
Net cash provided (used) by operating activities $ (22,164,349) $ 71,259,020
NONCASH CAPITAL AND RELATED
FINANCING ACTIVITIES
Acquisition of lease asset $ 892,723 $ -
NONCASH INVESTING ACTIVITIES
Change in fair value of investments $ 91,520 $ 242,000
Change in interest receivable $ 205,270 $ 25,362
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
13 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
REPORTING ENTITY
Orange County Power Authority (OCPA) is a California joint powers authority created on November 20, 2020, and its jurisdictions consist of the following local governments as of June 30, 2025:
Cities
Buena Park Fullerton
Fountain Valley Irvine
OCPA is separate from and derives no financial support from its members. It is governed by a Board of Directors (Board) consisting of five regular members and two alternates, all of whom are elected officials representing the participating communities.
OCPA was established to procure retail electricity for residents and businesses within its members’ jurisdiction, promote and manage energy and climate change programs, and exercise all other necessary powers to achieve these objectives. A core function of OCPA is to provide electric service using renewable energy sources through the Community Choice Aggregation Program, as authorized by California Public Utilities Code Section 366.2.
OCPA began energy delivery operations in April 2022. Electricity is purchased from commercial suppliers and delivered through the existing infrastructure and equipment managed by Southern California Edison (SCE).
BASIS OF ACCOUNTING
OCPA’s financial statements are prepared in accordance with generally accepted accounting principles (GAAP). The Governmental Accounting Standards Board (GASB) is responsible for establishing GAAP for state and local governments through its pronouncements.
OCPA’s operations are accounted for as a governmental enterprise fund and are reported using the economic resources measurement focus and the accrual basis of accounting, similar to business enterprises. Accordingly, revenues are recognized when they are earned, and expenses are recognized at the time liabilities are incurred. Enterprise fund-type operating statements present increases (revenues) and decreases (expenses) in total net position. Reported net position is segregated into three categories, if applicable – net investment in capital assets, restricted and unrestricted. When both restricted and unrestricted resources are available for use, OCPA will use restricted resources first, and then unrestricted resources as they are needed.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
14 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued) CASH
For purposes of the Statements of Cash Flows, OCPA defines cash to include cash on hand, demand deposits, and short-term investments with an original maturity of three months or less.
Restricted cash reported on the Statements of Net Position includes collateral for a line of credit as well as a required minimum balance that must be maintained in one of OCPA’s bank accounts.
INVESTMENTS
Investments are stated at fair value based on prices listed on a national exchange for debt securities, except for certificates of deposits which are stated at cost. OCPA intends to hold its securities to maturity. Investments with a maturity of less than one year are classified as current assets in the Statements of Net Position. Investments with a maturity of one year or more are shown as noncurrent assets in the Statements of Net Position.
OCPA’s Investment Policy permits the following types of investments:
U.S. Treasury obligations Commercial paper
U.S. agency obligations Medium-term notes
Municipal obligations Negotiable certificates of deposits Deposits at banks Mortgage pass-through and asset-backed securities Placement service deposits Supranational obligations
Local Agency Investment Fund Joint power authority pool
ACCRUED REVENUE
Accrued revenue reflects the estimated value of electricity delivered to customers during the reporting period for which invoices had not been issued by the end of the fiscal year.
PREPAID EXPENSES
Payments made to vendors that will benefit periods beyond the end of the current fiscal year are recorded as prepaid expenses.
DEPOSITS
Contracts to purchase energy may require OCPA to provide the supplier with advanced payments or security deposits. Deposits are generally held for the term of the contract and are classified as current or noncurrent assets depending on the length of time the deposits will be outstanding.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
15 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
LEASE ASSETS AND LEASE LIABILITIES
OCPA recognizes an asset and liability when it enters into certain leasing arrangements. The cost of the leased asset is amortized over the term of the lease. The lease liability is the present value of payments expected to be paid to the lessor during the lease term. OCPA’s leased asset and liability are related to its office lease.
CAPITAL ASSETS AND DEPRECIATION
OCPA’s policy is to capitalize furniture and equipment valued greater than $5,000 that is expected to be in service for over one year. Depreciation is computed according to the straight-line method over estimated useful lives of three years for electronic equipment, five years for furniture, and the lease term for leasehold improvements. OCPA does not own any electric generation, transmission, or distribution assets.
RATE STABILIZATION FUND
In June 2024, OCPA established a Rate Stabilization Fund that is reported in accordance with GASB Statement No. 62. This fund allows OCPA to defer revenue during years of strong financial performance for use in future years when financial results may weaken. Amounts deposited into the fund are reported as a reduction of operating revenues and classified on the Statements of Net Position as deferred inflows of resources. OCPA deferred $45,000,000 to the fund in 2024 and transferred $15,000,000 out of the fund in 2025.
NET POSITION
Net position is presented in the following components:
Net investment in capital assets: This component of net position consists of capital assets, net of accumulated depreciation and amortization, and reduced by outstanding borrowings that are attributable to the acquisition, construction, or improvement of those assets.
Restricted: This component of net position consists of restraints placed on net asset use through external constraints imposed by creditors (such as through debt covenants), grantors, contributors, or law or regulations of other governments or constraints imposed by law through constitutional provisions or enabling legislation.
Unrestricted: This component of net position consists of net position that does not meet the definition of “net investment in capital assets” or “restricted.”
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
16 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
OPERATING AND NONOPERATING REVENUES
Operating revenues include energy sales to retail and wholesale customers, grant revenue earned from the delivery of program activities, and liquidated damages from suppliers that fail to meet delivery commitments. Operating revenues also include contributions to and distributions from the Rate Stabilization Fund
Investment income is considered nonoperating revenues.
REVENUE RECOGNITION
OCPA recognizes revenue on the accrual basis. This includes invoices issued to customers during the reporting period and electricity estimated to have been delivered, but not yet billed Management estimates that a portion of the billed amounts will be uncollectible. Accordingly, an allowance for uncollectible accounts has been recorded. Revenue is presented net of this allowance.
OPERATING AND NONOPERATING EXPENSES
Operating expenses include the costs of electricity, services, administrative expenses, and amortization and depreciation of capital assets. Interest expense is considered a nonoperating expense.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
17 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
COST OF ELECTRICITY
During the normal course of business, OCPA purchases electrical power from numerous suppliers. Electricity costs include the cost of energy and capacity arising from contracts with energy suppliers as well as generation credits, load and other charges arising from OCPA’s participation in the California Independent System Operator’s (CAISO) centralized market. The cost of electricity and capacity is recognized as “Cost of Electricity” in the Statements of Revenues, Expenses and Changes in Net Position.
To comply with the State of California’s Renewable Portfolio Standards (RPS) and self-imposed benchmarks, OCPA acquires RPS eligible renewable energy evidenced by Renewable Energy Certificates (Certificates) recognized by the Western Renewable Energy Generation Information System (WREGIS). OCPA obtains Certificates with the intent to retire them and does not sell or build surpluses of Certificates with a profit motive. An expense is recognized when the cost of the Certificate is due and payable to the supplier.
OCPA purchases capacity commitments from qualifying generators to comply with the California Public Utilities Commission’s (CPUC) Resource Adequacy Program. The goals of the Resource Adequacy Program are to provide sufficient resources to CAISO to ensure the safe and reliable operation of the grid in real-time and to provide appropriate incentives for the siting and construction of new resources needed for reliability in the future.
STAFFING COSTS
OCPA pays employees semi-monthly and fully satisfies its obligation for health benefits and contributions to its defined contribution retirement plan. OCPA does not provide post-employment healthcare or other fringe benefits and, accordingly, no related liability is recorded in these financial statements.
OCPA provides compensated absences, including paid time off, which are accrued when earned and recorded as part of accrued liabilities. The liability includes leave that is attributable to services already rendered, accumulates, and is more likely than not to be used or paid. The liability is measured using the employee’s pay rate as of the financial statement date.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
18 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)
INCOME TAXES
OCPA is a joint powers authority under the provision of the California Government Code and is not subject to federal or state income or franchise taxes.
USER TAXES AND ENERGY SURCHARGES DUE TO OTHER GOVERNMENTS OCPA is required by governmental authorities to collect and remit user taxes on certain customer sales. These taxes are not considered revenues or expenses to OCPA.
RECLASSIFICATIONS
Certain amounts in the prior year financial statements have been reclassified for comparative purposes to conform to the presentation of the current year’s financial statements. These reclassifications did not result in any change to the previously reported net position or change in net position.
ESTIMATES
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect certain reported amounts and disclosures. Accordingly, actual results could differ from those estimates.
2. CASH
OCPA maintains its cash in interest and non-interest-bearing accounts at U.S. Bank. OCPA’s deposits are subject to California Government Code Section 16521 which requires banks to provide collateral of 110% of account balances in excess of the $250,000 insurance coverage by Federal Deposit Insurance Corporation. OCPA has an investment policy addressing risks beyond the requirements of the relevant code and monitors its risk exposure on an ongoing basis. As of June 30, 2025 and 2024, all of OCPA’s cash was held as depository accounts or certificates of deposit.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
19 3. ACCOUNTS RECEIVABLE
Accounts receivable were as follows as of June 30:
2025 2024
Accounts receivable from customers $ 26,649,580 $ 35,595,551 Allowance for uncollectible accounts (12,350,000) (8,767,000) Net accounts receivable $ 14,299,580 $ 26,828,551
The majority of account collections occur within the first few months following customer invoicing. OCPA estimates that a portion of the billed accounts will not be collected. OCPA continues collection efforts on delinquent accounts in excess of de minimis balances regardless of the age of the account. Although collection success generally decreases with the age of the receivable, OCPA continues to have success in collecting older accounts.
4. INVESTMENTS
During the years ended June 30, 2025 and 2024, OCPA purchased investments with original maturities of three months or more. As of June 30, the fair value of investments, except for certificates of deposits which are stated at cost, was as follows:
2025 2024
Current Investments:
Certificate of deposits $ 20,000,000 $ 18,000,000
U.S. Treasury Securities 1,948,918 1,975,918
Total current investments $ 21,948,918 $ 19,975,918
FAIR VALUE MEASUREMENT
GASB Statement No. 72, Fair Value Measurement and Application, sets forth the framework for measuring fair value. This framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. Level 1 inputs are quoted prices in active markets for identical assets, Level 2 inputs are significant other observable inputs, and Level 3 inputs are significant unobservable inputs.
In instances where inputs used to measure fair value fall into more than one level in the fair value hierarchy, fair value measurements in their entirety are categorized based on the lowest level input that is significant to the valuation. OCPA’s assessment of the significance of particular inputs to these fair value measurements requires judgment and considers factors specific to each asset or liability.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
20 4. INVESTMENTS (continued)
As of June 30, 2025 and 2024, OCPA’s investments are valued at quoted prices in active markets (Level 1 inputs), except for certificates of deposits which are valued at amortized cost.
CREDIT RISK
Credit risk is the risk an issuer or other counterparty to an investment will not fulfill its obligations. Certain investments, such as obligations of the U.S. government or obligations explicitly guaranteed by the U.S. government are not considered to have credit risk.
OCPA’s investment policy addresses this risk. OCPA’s investment policy limits investments to those allowed by Section 53601 of the California Government Code that addresses the risk allowable for each investment.
CUSTODIAL CREDIT RISK
Cash and Cash Equivalents
Custodial credit risk is the risk that in the event of a financial institution failure, OCPA’s deposits may not be returned to OCPA. OCPA’s deposits are subject to California Government Code Section 16521, which requires banks to provide collateral of 110% of account balances in excess of the $250,000 insurance coverage by Federal Deposit Insurance Corporation.
As of June 30, 2025 and 2024, none of OCPA’s investments in certificates of deposit are considered to be exposed to custodial credit risk.
Investments
Custodial credit risk for investments is the risk that, in the event of the failure of the counterparty to a transaction, OCPA would not be able to recover the value of the investment or collateral securities that are in the possession of an outside party. All of OCPA’s investments are exposed to custodial credit risk.
OCPA’s investment policy addresses this risk. All investments owned by OCPA are held in safekeeping by a third-party custodian, acting as an agent for OCPA under the terms of a custody agreement.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
21 4. INVESTMENTS (continued)
INTEREST RATE RISK
Interest rate risk is the risk that changes in interest rates will adversely affect the fair value of an investment. Duration is a measure of the price sensitivity of a fixed income portfolio to changes in interest rates. It is calculated as the weighted average time to receive a bond’s coupon and principal payments. The longer the duration of a portfolio, the greater its price sensitivity to changes in interest rates. OCPA manages its exposure to declines in fair values by limiting the weighted average maturity of its investments.
As of June 30, 2025 and 2024, all of OCPA’s investments had a maturity of less than one year.
CONCENTRATION OF CREDIT RISK
Concentration of credit risk is the risk of loss to the magnitude of OCPA’s investment in a single issuer. OCPA manages the concentration of credit risk by diversifying its portfolio so that reliance on any one issuer will not place an undue burden on OCPA.
As of June 30, 2025 and 2024, there were no concentrations of credit risk.
5. CAPITAL ASSETS
Capital asset activity for the year ended June 30, 2025 was as follows:
Beginning
balance Increases Decreases
Ending
balance
Capital assets being depreciated and amortized:
Furniture and equipment -$ 217,292 $ -$ 217,292 $
Leasehold improvements - 159,450 - 159,450
Lease asset - 918,417 (25,694) 892,723
Total capital assets being depreciated and amortized: - 1,295,159 (25,694) 1,269,465 Less accumulated depreciation and amortization:
Furniture, equipment and leasehold improvements - (53,980) - (53,980) Lease asset - (127,535) - (127,535)
Total accumulated depreciation and amortization - (181,515) - (181,515) Total capital assets, net of depreciation and amortization -$ 1,113,644 $ $ (25,694) $ 1,087,950
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
22 6. LEASE
A lease asset is reported in accordance with Governmental Accounting Standards Board No. 87 (GASB 87).
In February 2024, OCPA entered into an 84-month non-cancelable lease for its office premises effective July 2024. As part of a prior office space lease, OCPA made rental payments in the amounts of $178,000 and $228,000 for the fiscal years ended June 30, 2025 and 2024, respectively.
As of June 30, 2025, future minimum lease payments under this lease were projected as follows:
Principal Interest Total
Year ending June 30,
2026 $ 114,714 $ 49,811 $ 164,525
2027 127,566 42,568 170,134
2028 141,211 34,531 175,742
2029 156,661 25,625 182,286
2030 173,065 15,765 188,830
2031 167,768 4,926 172,694
Total $ 880,985 $ 173,226 $ 1,054,211
7. DEBT
LOANS PAYABLE
Pre-launch
In January 2021, OCPA borrowed $2,500,000 from the City of Irvine for working capital costs associated with its launch. In September 2021, OCPA borrowed an additional $5,000,000 from the City of Irvine to use as collateral for its bank credit facility. The loan repayment is due on January 1, 2027. Interest on the loan is calculated based on the quarterly yield on the City of Irvine’s Pooled Investment Portfolio. As of June 30, 2025, the estimated interest rate was 3.5% per annum.
Formation costs
In addition to the loans mentioned, formation-related costs were paid directly by the City of Irvine to various professional consultants. OCPA is obligated to reimburse the City of Irvine for these costs no later than January 1, 2027. Interest does not accrue on the formation costs advanced by the City of Irvine. In 2023, OCPA repaid approximately $125,000 of these costs, leaving a balance of approximately $28,000 outstanding as of June 30, 2025 and June 30, 2024.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
23 7. DEBT (continued)
NOTE PAYABLE
In September 2021, OCPA and US Bank entered into a Revolving Credit Agreement for a $35,000,000 credit facility. The credit agreement enhances OCPA’s overall liquidity for potential working capital needs and collateral requirements. This agreement terminates in September 2026.
The borrowing rate on the credit facility is based on the daily Secured Overnight Financing Rate (SOFR) plus 1.5%. OCPA had no debt outstanding under the credit agreement at June 30, 2025 or 2024. OCPA did issue Standby Letters of Credit secured by the line of credit. At June 30, 2025 and June 30, 2024, these Letters of Credit reduced the available portion of the line by $0 and $6,200,000, respectively, but are not considered debt to OCPA.
Loan principal activity and balances were as follows:
Beginning Additions Payments Ending
Years ended June 30, 2025 and 2024
Loan payable-pre-launch costs 7,500,000 $ $ - $ 7,500,000 - $ Loan payable-formation costs 27,841 - 27,841 -
Total $ 7,527,841 $ - $ 7,527,841 -
Amounts due within one year -
Amounts due after one year $ 7,527,841
8. DEFINED CONTRIBUTION RETIREMENT PLAN
OCPA provides retirement benefits to eligible employees through a 401(a) Retirement Plan (Plan), which is a defined contribution (IRC 401(a)) retirement plan administered by Lincoln Financial. As of June 30, 2025, there were 20 plan participants. OCPA is required to contribute 10% of annual covered payroll. During the fiscal years ended June 30, 2025 and 2024, OCPA contributed approximately $375,000 and $252,000, respectively, to the 401(a) Retirement Plan.
OCPA has elected out of the Social Security system for employees eligible for the Plan. The Plan’s provisions and contribution requirements are established and may be amended by the Board. Additionally, OCPA offers a 457(b) Retirement Plan where employees may elect to participate and make tax-deferred contributions. OCPA provides an employer contribution to the 457(b) plan that matches the employee’s voluntary contribution, up to a maximum of 4% of salary.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
24 9. RISK MANAGEMENT
OCPA is exposed to various risks of loss related to torts; theft of, damage to, and destruction of assets; and errors and omissions. During the year, OCPA purchased insurance policies from investment-grade commercial carriers to mitigate risks that include those associated with cyber and private liability, earthquakes, theft, general liability, errors and omissions, and property damage. OCPA has general liability coverage of $2,000,000 with a deductible of $250.
OCPA maintains energy risk management policies, procedures and systems that help mitigate credit, liquidity, market, operating, regulatory and other risks that arise from participation in the California energy market.
Credit guidelines include a preference for transacting with investment-grade counterparties, evaluating counterparties’ financial condition and assigning credit limits as applicable. These credit limits are established based on risk and return considerations under terms customarily available in the industry. In addition, OCPA enters into netting arrangements whenever possible and where appropriate obtains collateral and other performance assurances from counterparties.
10. PURCHASE COMMITMENTS
POWER AND ELECTRIC CAPACITY
In the ordinary course of business, OCPA enters into various power purchase agreements to procure renewable energy, and other energy and electric capacity. The price and volume of purchased power are typically fixed but can also be variable. Variable pricing is generally based on the market price of either natural gas or electricity at the time of delivery. Variable volume is generally associated with contracts to purchase energy from as-available resources such as solar, wind, and hydroelectric facilities.
OCPA enters into power purchase agreements in order to comply with state law and voluntary targets for renewable and greenhouse gas free products and to ensure stable and competitive electric rates for its customers.
The following table details the expected, undiscounted, contractual obligations outstanding as of June 30, 2025:
Year ended June 30,
2026 279,300,000$
2027 223,800,000
2028 173,100,000
2029 134,500,000
2030 128,500,000
2031-2047 1,000,100,000
Total 1,939,300,000$
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
25 11. RECENTLY ADOPTED AND FUTURE ACCOUNTING PRONOUNCEMENTS OCPA implemented GASB Statement No. 102, Certain Risk Disclosures, which requires additional disclosures regarding concentrations and constraints that could impact OCPA’s financial position or results of operations. Implementation of this statement did not have a material effect on the financial statements.
OCPA also implemented GASB Statement No. 103, Financial Reporting Model Improvements, which establishes revised guidance for the presentation of financial statements by state and local governments. The adoption of this statement did not have a material effect on OCPA’s financial statements.
In addition, OCPA adopted GASB Statement No. 104, Disclosure of Certain Capital Assets.
Implementation of this statement did not have a material effect on the financial statements.
12. WITHDRAWAL OF MEMBER
CITY OF HUNTINGTON BEACH
After receiving the City’s withdrawal notice in May 2023, OCPA took steps to adjust its system energy and renewables portfolio for 2024. These adjustments included reducing the acquisition of system energy and renewables to fill open positions for the year, effectively mitigating potential liabilities. As a result, OCPA did not incur any liabilities related to system energy contracts due to the City’s withdrawal and its share of OCPA’s load.
OCPA had already purchased resource adequacy for 2024 to meet its year-ahead obligations with the CPUC and CAISO. The CPUC informed OCPA that its year-ahead load forecast could not be amended to reflect the City’s return to SCE bundled service, meaning OCPA could not reduce its resource adequacy obligations. As a result, OCPA retained the resource adequacy attributed to the City’s load for the months of July through December 2024, creating a stranded cost of $6,680,079, for which the City was liable.
Under Rule 23, OCPA is subject to SCE’s imposition of reentry fees for the return of the City’s customers, which includes SCE’s incremental administrative and procurement costs.
Additionally, OCPA incurred internal administrative and legal costs related to the City’s reentry, including consulting fees, the hiring of a project manager to ensure a smooth transition back to SCE, printing costs for customer notifications, and legal expenses. These expenses totaled $352,029, for which the City was liable.
ORANGE COUNTY POWER AUTHORITY
NOTES TO THE BASIC FINANCIAL STATEMENTS
YEARS ENDED JUNE 30, 2025 AND 2024
26 12. WITHDRAWAL OF MEMBER (continued)
On October 23, 2023, the City approved the transition of all existing customers from the 100% Renewable Choice to the Basic Choice tier, effective January 1, 2024. This change reduced the cost of renewable energy that OCPA needed to purchase for the first six months of 2024 by $7,467,753 (Renewable Cost Savings). These savings, directly related to the withdrawal and transition of the City’s customers, were applied to offset the City’s liability for withdrawal costs, including stranded resource adequacy costs, SCE administrative costs, and OCPA administrative, consulting, and legal expenses.
On September 3, 2024, OCPA determined the final withdrawal costs incurred in connection with the City’s departure, including resource adequacy costs, SCE reentry fees, and OCPA administrative expenses. These costs did not exceed the Renewable Cost Savings. As a result, the City has no further liability to OCPA regarding its withdrawal.
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 9.2
--------------------------------------------------------------------------------------------------------------------- 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: APPROVE AMENDMENT NO. 4 WITH AM CONSERVATION GROUP, INC. (FORMERLY THE ENERGY FEDERATION, INC.)
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☐ Prioritize Fiscal Sustainability & Affordability:
☒ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☐ Not Applicable:
RECOMMENDED ACTION(S)
Approve and authorize the Chief Executive Officer to execute Amendment No. 4 to the Professional Services Agreement with AM Conservation Group, Inc. (formerly The Energy Federation, Inc.) to increase the total contract not-to-exceed amount by $80,000, from $400,000 to $480,000, to support continued implementation of Orange County Power Authority’s Residential Marketplace Program through June 30, 2026.
BACKGROUND
As a not-for-profit public agency, Orange County Power Authority (OCPA) reinvests its revenue in the form of energy programs that benefit customers. At its June 21, 2023, meeting (Item 9.2), the Orange County Power Authority (OCPA) Board of Directors approved a Professional Services Agreement with The Energy Federation, Inc. (EFI) to develop and manage an online residential marketplace offering energy-efficient products including smart thermostats, LED bulbs, power strips, and smart plugs. This was the first energy program launched by OCPA, chosen for its turnkey implementation and ease of maintenance. The contract, valued at $400,000, was competitively procured following a request for proposals (RFP) issued May 5, 2023, and structured with a base term through June 30, 2024, with two optional one-year extensions. Marketplace costs consist of an annual maintenance fee; customer service costs for phone calls, emails, and chats; and the cost for products ordered through the marketplace. Additionally, if OCPA offers a rebate program for items offered in the marketplace, the cost of the rebate is incurred by OCPA and considered within the contract terms.
Subsequent contract amendments extended the agreement as follows:
• First Amendment (June 10, 2024) – Extended the contract term through June 30, 2025, and applied the Year 2 annual marketplace management fee of $40,000 • Second Amendment (June 30, 2025) – Formally recognized AM Conservation Group, Inc. as EFI’s successor following its 2024 acquisition of EFI’s assets and extended the term through June 30, 2026, contingent upon AM Conservation renewing California business license and insurance by August 30, 2025. The Year 3 management fee of $40,000 was applied to this period
• Third Amendment (August 20, 2025) – Confirmed the assignment of EFI’s contractual rights to AM Conservation Group, Inc., and reaffirmed the June 30, 2026 contract end date, contingent upon fulfillment of licensing and insurance requirements by November 30, 2025 Throughout the implementation of these amendments, AM Conservation has continued to provide program management, order fulfillment, digital hosting, and rebate administration for OCPA’s online residential marketplace.
DISCUSSION/ANALYSIS
Since its launch in 2023, the OCPA Residential Marketplace has enabled OCPA residents to conveniently access subsidized energy-efficient products that promote electrification and energy savings. Success of the program has been consistently moderate, with periods of high activity around promoted discounts like a steep cost reduction on smart thermostats ahead of summer or for Black Friday.
This third program year (FY25-26), OCPA has stepped up its program offerings by launching larger scale rebates and discounts, and has strategically utilized the Marketplace to streamline their deployment while promoting the platform. The first program implemented through the Marketplace was the Charge@Home EV charger program, which from July to October 2025 provided over 200 customers with free EV chargers at an average cost of $700 each. The total expenditure for this program was $141,980 across $99,000 for FY 2024-25 and a budget of $151,000 shared with the Residential Battery Rebate program for FY 2025-26. The second program is energy efficiency kits with 1,500 customers able to receive a free kit that includes almost $50 worth of energy saving products. The energy efficiency kit program was designed to ensure equitable access to energy-saving products across OCPA’s member cities, particularly among CARE/FERA customers and renters. The budget for this program was $75,000.
Additionally, as program integration expanded to support these pilot programs, the Marketplace experienced increased transaction volume and customer support needs that resulted in increased regular costs. Both program offerings were incredibly successful in terms of uptake and in driving measurable reductions in household energy use.
The Marketplace’s ability to streamline rebate processing reflects a fulfillment model that continues to scale effectively with customer demand. It also shows OCPA’s wherewithal to efficiently manage resources to their maximum capability. This year’s increased utilization and success of the Marketplace platform was not foreseen when the program contract was designed in 2023 with a $400,000 expenditure cap. The proposed $80,000 contract increase will enable OCPA to continue offering energy saving products on the Marketplace through contract completion on June 30, 2026, maintaining uninterrupted access for customers.
FISCAL IMPACT
The proposed not-to-exceed additional fee of $80,000 has been incorporated into the approved FY202526 Operating Budget.
ATTACHMENT(S)
Attachment A – DRAFT Fourth Amendment with AM Conservation Group Attachment B – Third Amendment with AM Conservation Group Attachment C – Second Amendment with AM Conservation Group Attachment D – Third Amendment with AM Conservation Group Attachment E – Professional Services Agreement with AM Conservation Group Docusign Envelope ID: 7268471E-4C59-4BC9-9E2D-CCE7F3CAC1A5 55735.00001\44355842.2
FOURTH AMENDMENT TO PROFESSIONAL SERVICES AGREEMENT BETWEEN ORANGE COUNTY POWER AUTHORITY AND AM CONSERVATION, INC.
This FOURTH AMENDMENT (“Fourth Amendment”) is entered into on November 10, 2025 (“Fourth Amendment Effective Date”), by and between the ORANGE COUNTY POWER AUTHORITY, a California joint powers authority (“OCPA”) and AM CONSERVATION GROUP, INC. (as successor to THE ENERGY FEDERATION, INC.) (“Consultant”). OCPA and Consultant are sometimes individually referred to herein as the “Party” and collectively as the “Parties.”
RECITALS
A. The Parties entered into a Professional Services Agreement between OCPA and Consultant, dated June 30, 2023, that certain First Amendment dated June 10, 2024, that certain Second Amendment dated June 30, 2025, and that certain Third Amendment dated August 20, 2025, collectively, as amended (the “Agreement”).
B. On June 13, 2024, AM Conservation Group, Inc., the products division of Franklin Energy Services, LLC announced its plan to acquire assets of The Energy Federation, Inc. (“EFI”), and the transaction was completed on August 12, 2024. Effective August 12, 2024, EFI client and vendor contracts were assigned to AM Conservation Group, Inc. AM Conservation Group, Inc. has assumed all of EFI’s rights and obligations under the Agreement between EFI and OCPA.
C. OCPA consented to the assignment of rights and obligation from EFI to AM Conservation on June 27, 2024.
D. Pursuant to the Agreement, Consultant provides online marketplace services to OCPA.
E. The Parties desire to further amend the Agreement to increase the total not to exceed by $80,000, for a new total not to exceed of $480,000.
AGREEMENT
NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, it is agreed by and between the Parties as follows:
1. Amendment of Section 3.1. Section 3.1 of the Agreement is amended to increase the total not to exceed amount by $80,000, for a new total not to exceed amount of $480,000.
2. Amendment of Section 1.2. Section 1.2 of the Agreement is amended to extend the term of the Agreement through June 30, 2026, provided that Consultant registers to do business in California and provides adequate insurance as required by the Agreement by December 31, 2025. If Consultant fails to register to do business in California or provides adequate insurance as required by the Agreement by December 31, 2025, 2025, the Agreement shall expire on December 31, 2025, without further obligation Docusign Envelope ID: 7268471E-4C59-4BC9-9E2D-CCE7F3CAC1A5 55735.00001\44355842.2
between the Parties.
3. Capitalized Terms. Any capitalized terms not defined herein shall have the meanings set forth in the Agreement.
4. Counterparts. This Amendment may be executed in two or more counterparts, including facsimile counterparts, each of which shall, for all purposes, be deemed an original and all such counterparts, taken together, shall constitute one and the same instrument.
5. Full Force. Except as expressly set forth herein, the Agreement shall remain unmodified and in full force and effect.
IN WITNESS WHEREOF, the Parties have executed this Fourth Amendment to the Professional Services Agreement between Orange County Power Authority and The Energy Federation as of the Fourth Amendment Effective Date.
ORANGE COUNTY POWER AUTHORITY,
a California joint powers authority
By : ________________________________
Name: ______________________________
Title: ________________________________
AM CONSERVATION GROUP, INC.
By : ________________________________
Name: ______________________________
Title: ________________________________
ATTEST:
_________________________________
Secretary, Authority Board of Directors
APPROVED AS TO FORM:
_________________________________
General Counsel
55735.00001\42348840.1
THIRD AMENDMENT TO PROFESSIONAL SERVICES AGREEMENT BETWEEN ORANGE COUNTY POWER AUTHORITY AND AM CONSERVATION, INC.
This THIRD AMENDMENT (“Third Amendment”) is entered into on August 20, 2025 (“Third Amendment Effective Date”), by and between the ORANGE COUNTY POWER AUTHORITY, a California joint powers authority (“OCPA”) and AM CONSERVATION GROUP, INC. (a successor to THE ENERGY FEDERATION, INC.) (“Consultant”). OCPA and Consultant are sometimes individually referred to herein as the “Party” and collectively as the “Parties.”
RECITALS
A. The Parties entered into a Professional Services Agreement between OCPA and Consultant, dated June 30, 2023, that certain First Amendment dated June 10, 2024, and that certain Second Amendment dated June 30, 2025, collectively, as amended (the “Agreement”).
B. On June 13, 2024, AM Conservation Group, Inc., the products division of Franklin Energy Services, LLC (“Frankin Energy”) announced its plan to acquire assets of The Energy Federation, Inc. (“EFI”), and the transaction was completed on August 12, 2024. Effective August 12, 2024, EFI client and vendor contracts were assigned to AM Conservation Group, Inc. AM Conservation Group, Inc. has assumed all of EFI’s rights and obligations under the Agreement between EFI and OCPA.
C. OCPA consented to the assignment of rights and obligation from EFI to AM Conservation on June 27, 2024.
D. Pursuant to the Agreement, Consultant provides online marketplace services to OCPA.
E. The Parties desire to further amend the Agreement to extend the term of the Agreement.
AGREEMENT
NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, it is agreed by and between the Parties as follows:
1. Amendment of Section 1.2. Section 1.2 of the Agreement is amended to extend the term of the Agreement through June 30, 2026, provided that Consultant obtains a license to do business in California and adequate insurance as required by the Agreement by November 30, 2025. If Consultant fails to obtain a license to do business in California and adequate insurance as required by the Agreement by November 30, 2025, the Agreement shall expire on November 30, 2025, without further obligation between the Parties.
2. Capitalized Terms. Any capitalized terms not defined herein shall have the meanings set forth in the Agreement.
3. Counterparts. This Amendment may be executed in two or more counterparts, including facsimile counterparts, each of which shall, for all purposes, be deemed an original and all such counterparts, taken together, shall constitute one and the same
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55735.00001\42348840.1
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4. Full Force. Except as expressly set forth herein, the Agreement shall remain unmodified and in full force and effect.
IN WITNESS WHEREOF, the Parties have executed this Third Amendment to the Professional Services Agreement between Orange County Power Authority and The Energy Federation as of the Third Amendment Effective Date.
ORANGE COUNTY POWER
AUTHORITY, a joint powers authority
Name:
Title:
Date:
AM CONSERVATION GROUP, INC.
Name:
Title:
Date:
APPROVED AS TO FORM:
General Counsel
PPROVED AS TO FORM:
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55735.00001\42348840.1
FIRST AMENDMENT TO PROFESSIONAL SERVICES AGREEMENT BETWEEN
ORANGE COUNTY POWER AUTHORITY AND THE ENERGY FEDERATION THIS FIRST AMENDMENT (“First Amendment”) is entered into on June 10, 2024 (“Amendment Effective Date”), by and between the ORANGE COUNTY POWER AUTHORITY, a California joint powers authority (“OCPA”) and THE ENERGY FEDERATION, INC. (“Consultant”). OCPA and Consultant are sometimes individually referred to herein as the “Party” and collectively as the “Parties.”
RECITALS
A. The Parties entered into a Professional Services Agreement between OCPA and Consultant, dated June 30, 2023 (“Agreement”).
B. Pursuant to the Agreement, Consultant provides online marketplace services to OCPA.
C. The Parties desire to amend the Agreement to extend the term of the Agreement.
AGREEMENT
NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, it is agreed by and between the Parties as follows:
1. Amendment of Section 1.2. Section 1.2 of the Agreement is amended to extend the term of the Agreement through June 30, 2025. The Parties agree that the “Year 2 Annual Marketplace Program Management” fee of $40,000 under Exhibit B shall apply to the extension period.
2. Capitalized Terms. Any capitalized terms not defined herein shall have the meanings set forth in the Agreement.
3. Counterparts. This Amendment may be executed in two or more counterparts, including facsimile counterparts, each of which shall, for all purposes, be deemed an original and all such counterparts, taken together, shall constitute one and the same instrument.
4. Full Force. Except as expressly set forth herein, the Agreement shall remain unmodified and in full force and effect.
55735.00001\42348840.1
IN WITNESS WHEREOF, the Parties have executed this First Amendment to the Professional Services Agreement between Orange County Power Authority and The Energy Federation as of the date first set forth above.
ORANGE COUNTY POWER
AUTHORITY
Name: _______________________________
Title:________________________________
Date: ________________________________
THE ENERGY FEDERATION, INC.
Name: _____________________________
Title: _______________________________
Date: _______________________________
APPROVED AS TO FORM:
_________________________________
General Counsel
June 10, 2024
CEO and President
Chief Executive Officer
6/10/2024
1 ORANGE COUNTY POWER AUTHORITY
PROFESSIONAL SERVICES AGREEMENT
This Professional Services Agreement (“Agreement”) is made and entered into on June 30, 2023, by and between ORANGE COUNTY POWER AUTHORITY, a California joint powers authority (“Authority”) and THE ENERGY FEDERATION, INC., a Massachusetts 501(c)(4) organization (“Consultant”). Authority and Consultant are sometimes individually referred to as “Party” and collectively as “Parties.”
RECITALS
A. Consultant desires to perform and assume responsibility for the provision of certain professional services required by Authority on the terms and conditions set forth in this Agreement.
Consultant represents that it is experienced in providing online marketplace services, is licensed in the State of California, and is familiar with the plans of Authority.
B. Authority desires to engage Consultant to render such professional services for the design and implementation of a public engagement strategy (“Project”) as set forth in this Agreement.
AGREEMENT
1. Scope of Services and Term.
1.1 General Scope of Services. Consultant promises and agrees to furnish to Authority all labor and services and incidental and customary work necessary to fully and adequately supply assist the Authority the implementation services necessary for the Project (“Services”). The Services are more particularly described in Exhibit A attached hereto, and which are stated in the proposal to Authority. All Services shall be subject to, and performed in accordance with, this Agreement, the exhibits attached hereto, and all applicable local, state and federal laws, rules and regulations.
1.2 Term. The term of this Agreement shall be from July 1, 2023 to June 30, 2024, unless earlier terminated as provided herein. Consultant shall complete the Services within the term of this Agreement and shall meet any other established schedules and deadlines. The term may be extended for two additional one-year terms.
2. Responsibilities of Consultant.
2.1 Control and Payment of Subordinates; Independent Contractor. The Services shall be performed by Consultant or under its supervision. Authority retains Consultant on an independent contractor basis and not as an employee. Consultant retains the right to perform similar or different services for others during the term of this Agreement. Any additional personnel performing the Services under this Agreement on behalf of Consultant shall also not be employees of Authority and shall at all times be under Consultant’s exclusive direction and control. 2 Consultant shall pay all wages, salaries, and other amounts due such personnel in connection with their performance of Services under this Agreement and as required by law. Consultant shall be responsible for all reports and obligations respecting such additional personnel, including, but not limited to: social security taxes, income tax withholding, unemployment insurance, disability insurance, and workers’ compensation insurance.
2.2 Schedule of Services. Consultant shall perform the Services expeditiously, within the term of this Agreement. Consultant represents that it has the professional and technical personnel required to perform the Services in conformance with such conditions. In order to facilitate Consultant’s conformance with the Schedule, Authority shall respond to Consultant’s submittals in a timely manner. Upon request of Authority, Consultant shall provide a more detailed schedule of anticipated performance to meet the Schedule of Services.
2.3 Conformance to Applicable Requirements. All work prepared by Consultant shall be subject to the approval of Authority.
2.4 Substitution of Key Personnel. Consultant has represented to Authority that certain key personnel will perform and coordinate the Services under this Agreement. Should one or more of such personnel become unavailable, Consultant may substitute other personnel of at least equal competence upon written approval of Authority. In the event that Authority and Consultant cannot agree as to the substitution of key personnel, Authority shall be entitled to terminate this Agreement for cause. As discussed below, any personnel who fail or refuse to perform the Services in a manner acceptable to Authority, or who are determined by the Authority to be uncooperative, incompetent, a threat to the adequate or timely completion of the Project, or a threat to the safety of persons or property, shall be promptly removed from the Project by the Consultant at the request of the Authority. The key personnel for performance of this Agreement are as follows:
x Caryn Denny, National Business Development Director
Brian Kissane, Vice President, Client Success
2.5 Authority’s Representative. Authority hereby designates the Chief Executive Officer, or designee, to act as its representative for the performance of this Agreement (“Authority’s Representative”). Authority’s Representative shall have the power to act on behalf of Authority for all purposes under this Agreement. Consultant shall not accept direction or orders from any person other than Authority’s Representative, or designee.
2.6 Consultant’s Representative. Consultant hereby designates Caryn Denny, or his or her designee, to act as its Representative for the performance of this Agreement (“Consultant’s Representative”). Consultant’s Representative shall have full authority to represent and act on behalf of the Consultant for all purposes under this Agreement. The Consultant’s Representative shall supervise and direct the Services, using his or her best skill and attention, and shall be responsible for all means, methods, techniques, sequences and procedures and for the satisfactory coordination of all portions of the Services under this Agreement.
2.7 Coordination of Services. Consultant agrees to work closely with Authority staff in the performance of Services and shall be available to Authority’s staff, consultants and other staff 3 at all reasonable times.
2.8 Standard of Care; Performance of Employees. Consultant shall perform all Services under this Agreement in a skillful and competent manner, consistent with the standards generally recognized as being employed by professionals in the same discipline in the State of California.
Consultant represents and maintains that it is skilled in the professional calling necessary to perform the Services. Consultant warrants that all employees and sub- contractors shall have sufficient skill and experience to perform the Services assigned to them. Finally, Consultant represents that it, its employees and subcontractors have all licenses, permits, qualifications and approvals of whatever nature that are legally required to perform the Services, and that such licenses and approvals shall be maintained throughout the term of this Agreement. As provided for in the indemnification provisions of this Agreement, Consultant shall perform, at its own cost and expense and without reimbursement from Authority, any services necessary to correct errors or omissions which are caused by the Consultant’s failure to comply with the standard of care provided for herein. Any employee of the Consultant or its subcontractors who is determined by Authority to be uncooperative, incompetent, a threat to the adequate or timely completion of the Project, a threat to the safety of persons or property, or any employee who fails or refuses to perform the Services in a manner acceptable to Authority, shall be promptly removed from the Project by the Consultant and shall not be re-employed to perform any of the Services or to work on the Project.
2.9 Laws and Regulations. Consultant shall keep itself fully informed of and in compliance with all local, state and federal laws, rules and regulations in any manner affecting the performance of the Project or the Services, including all Cal/OSHA requirements, and shall give all notices required by law. Consultant shall be liable for all violations of such laws and regulations in connection with Services. If the Consultant performs any work knowing it to be contrary to such laws, rules and regulations and without giving written notice to Authority, Consultant shall be solely responsible for all costs arising therefrom. Consultant shall defend, indemnify and hold Authority, its officials, directors, officers, employees and agents free and harmless, pursuant to the indemnification provisions of this Agreement, from any claim or liability arising out of any failure or alleged failure to comply with such laws, rules or regulations.
2.10 Insurance.
2.10.1 Time for Compliance. Consultant shall not commence the Services under this Agreement until it has provided evidence satisfactory to Authority that it has secured all insurance required under this section, in a form and with insurance companies acceptable to Authority. In addition, Consultant shall not allow any subcontractor to commence work on any subcontract until it has provided evidence satisfactory to Authority that the subcontractor has secured all insurance required under this section.
2.10.2 Minimum Requirements. Consultant shall, at its expense, procure and maintain for the duration of the Agreement insurance against claims for injuries to persons or damages to property which may arise from or in connection with the performance of the Agreement by the Consultant, its agents, representatives, employees or subcontractors. Consultant shall also require all of its subcontractors to procure and maintain the same insurance for the 4 duration of the Agreement. Such insurance shall meet at least the following minimum levels of coverage:
(A) Minimum Scope of Insurance. Coverage shall be at least as broad as the latest version of the following: (1) General Liability: Insurance Services Office Commercial General Liability coverage (occurrence form CG 0001 or exact equivalent); (2) Automobile Liability: Insurance Services Office Business Auto Coverage (form CA 0001, code 1 (any auto) or exact equivalent); and (3) Workers’ Compensation and Employer’s Liability: Workers’ Compensation insurance as required by the State of California and Employer’s Liability Insurance. (B) Minimum Limits of Insurance. Consultant shall maintain limits no less than: (1) General Liability: $1,000,000 per occurrence for bodily injury, personal injury and property damage. If Commercial General Liability Insurance or other form with general aggregate limit is used, either the general aggregate limit shall apply separately to this Agreement/location or the general aggregate limit shall be twice the required occurrence limit; (2) Automobile Liability: $1,000,000 per accident for bodily injury and property damage; and (3) Workers’ Compensation and Employer’s Liability: Workers’ Compensation limits as required by the Labor Code of the State of California. Employer’s Liability limits of $1,000,000 per accident for bodily injury or disease.
2.10.3 Professional Liability. Consultant shall procure and maintain, and require its subcontractors to procure and maintain, for a period of five (5) years following completion of the Services, errors and omissions liability insurance appropriate to their profession. Such insurance shall be in an amount not less than $2,000,000 per claim. This insurance shall be endorsed to include contractual liability applicable to this Agreement and shall be written on a policy form coverage specifically designed to protect against acts, errors or omissions of the Consultant. “Covered Professional Services” as designated in the policy must specifically include work performed under this Agreement. The policy must “pay on behalf of” the insured and must include a provision establishing the insurer's duty to defend.
2.10.4 Insurance Endorsements. The insurance policies shall contain the following provisions, or Consultant shall provide endorsements on forms supplied or approved by Authority to add the following provisions to the insurance policies:
(A) General Liability.
(i) Commercial General Liability Insurance must include coverage for (1) Bodily Injury and Property Damage; (2) Personal Injury/Advertising Injury; (3) Premises/Operations Liability; (4) Products/Completed Operations Liability; (5) Aggregate Limits that Apply per Project; (6) Explosion, Collapse and Underground (UCX) exclusion deleted; (7) Contractual Liability with respect to this Agreement; (8) Broad Form Property Damage; and (9) Independent Consultants Coverage.
(ii) The policy shall contain no endorsements or provisions limiting coverage for (1) contractual liability; (2) cross liability exclusion for claims or suits by one insured against another; or (3) contain any other exclusion contrary to the Agreement. 5 (iii) The policy shall give Authority, its directors, officials, officers, employees, and agents insured status using ISO endorsement forms 20 10 10 01 and 20 37 10 01, or endorsements providing the exact same coverage. (iv) The additional insured coverage under the policy shall be “primary and non-contributory” and will not seek contribution from Authority’s insurance or self-insurance and shall be at least as broad as CG 20 01 04 13, or endorsements providing the exact same coverage.
(B) Automobile Liability. The automobile liability policy shall be endorsed to state that: (1) Authority, its directors, officials, officers, employees, agents and volunteers shall be covered as additional insureds with respect to the ownership, operation, maintenance, use, loading or unloading of any auto owned, leased, hired or borrowed by the Consultant or for which the Consultant is responsible; and (2) the insurance coverage shall be primary insurance as respects Authority, its directors, officials, officers, employees, agents and volunteers, or if excess, shall stand in an unbroken chain of coverage excess of the Consultant’s scheduled underlying coverage. Any insurance or self-insurance maintained by Authority, its directors, officials, officers, employees, agents and volunteers shall be excess of the Consultant’s insurance and shall not be called upon to contribute with it in any way. (C) Workers’ Compensation and Employers Liability Coverage. (i) Consultant certifies that it is aware of the provisions of Section 3700 of the California Labor Code which requires every employer to be insured against liability for workers’ compensation or to undertake self-insurance in accordance with the provisions of that code, and Consultant will comply with such provisions before commencing work under this Agreement.
(ii) The insurer shall agree to waive all rights of subrogation against Authority, its directors, officials, officers, employees, agents and volunteers for losses paid under the terms of the insurance policy which arise from work performed by the Consultant. (D) All Coverages. Defense costs shall be payable in addition to the limits set forth hereunder. Requirements of specific coverage or limits contained in this section are not intended as a limitation on coverage, limits, or other requirement, or a waiver of any coverage normally provided by any insurance. It shall be a requirement under this Agreement that any available insurance proceeds broader than or in excess of the specified minimum insurance coverage requirements and/or limits set forth herein shall be available to Authority, its directors, officials, officers, employees and agents as additional insureds under said policies. Furthermore, the requirements for coverage and limits shall be (1) the minimum coverage and limits specified in this Agreement; or (2) the broader coverage and maximum limits of coverage of any Insurance policy or proceeds available to the named insured; whichever is greater. (i) The limits of insurance required in this Agreement may be satisfied by a combination of primary and umbrella or excess insurance. Any umbrella or excess 6 insurance shall contain or be endorsed to contain a provision that such coverage shall also apply on a primary and non-contributory basis for the benefit of Authority (if agreed to in a written contract or agreement) before Authority’s own insurance or self-insurance shall be called upon to protect it as a named insured. The umbrella/excess policy shall be provided on a “following form” basis with coverage at least as broad as provided on the underlying policy(ies). (ii) Consultant shall provide Authority at least thirty (30) days prior written notice of cancellation of any policy required by this Agreement, except that the Consultant shall provide at least ten (10) days prior written notice of cancellation of any such policy due to non-payment of premium. If any of the required coverage is cancelled or expires during the term of this Agreement, the Consultant shall deliver renewal certificate(s) including the General Liability Additional Insured Endorsement to Authority at least ten (10) days prior to the effective date of cancellation or expiration.
(iii) The retroactive date (if any) of each policy is to be no later than the effective date of this Agreement. Consultant shall maintain such coverage continuously for a period of at least three years after the completion of the work under this Agreement.
Consultant shall purchase a one (1) year extended reporting period A) if the retroactive date is advanced past the effective date of this Agreement; B) if the policy is cancelled or not renewed; or C) if the policy is replaced by another claims-made policy with a retroactive date subsequent to the effective date of this Agreement.
(iv) The foregoing requirements as to the types and limits of insurance coverage to be maintained by Consultant, and any approval of said insurance by Authority, is not intended to and shall not in any manner limit or qualify the liabilities and obligations otherwise assumed by the Consultant pursuant to this Agreement, including but not limited to, the provisions concerning indemnification.
(v) If at any time during the life of the Agreement, any policy of insurance required under this Agreement does not comply with these specifications or is canceled and not replaced, Authority has the right but not the duty to obtain the insurance it deems necessary and any premium paid by Authority will be promptly reimbursed by Consultant or Authority will withhold amounts sufficient to pay premium from Consultant payments. In the alternative, Authority may cancel this Agreement. Authority may require the Consultant to provide complete copies of all insurance policies in effect for the duration of the Project. (vi) Neither Authority nor any of its directors, officials, officers, employees or agents shall be personally responsible for any liability arising under or by virtue of this Agreement.
2.10.5 Separation of Insureds; No Special Limitations. All insurance required by this Section shall contain standard separation of insureds provisions. In addition, such insurance shall not contain any special limitations on the scope of protection afforded to Authority, its directors, officials, officers, employees, agents and volunteers.
2.10.6 Deductibles and Self-Insurance Retentions. Any deductibles or self-insured 7 retentions must be declared to and approved by Authority. Consultant shall guarantee that, at the option of Authority, either: (1) the insurer shall reduce or eliminate such deductibles or self-insured retentions as respects Authority, its directors, officials, officers, employees, agents and volunteers; or (2) the Consultant shall procure a bond guaranteeing payment of losses and related investigation costs, claims and administrative and defense expenses.
2.10.7 Acceptability of Insurers. Insurance is to be placed with insurers with a current A.M. Best’s rating of no less than A:VII, licensed to do business in California, and satisfactory to Authority.
2.10.8 Verification of Coverage. Consultant shall furnish Authority with original certificates of insurance and endorsements effecting coverage required by this Agreement on forms satisfactory to Authority. The certificates and endorsements for each insurance policy shall be signed by a person authorized by that insurer to bind coverage on its behalf and shall be on forms provided by Authority if requested. All certificates and endorsements must be received and approved by Authority before work commences. Authority reserves the right to require complete, certified copies of all required insurance policies, at any time.
2.10.9 Subcontractor Insurance Requirements. Consultant shall not allow any subcontractors to commence work on any subcontract until they have provided evidence satisfactory to Authority that they have secured all insurance required under this section. Policies of commercial general liability insurance provided by such subcontractors shall be endorsed to name Authority as an additional insured using ISO form CG 20 38 04 13 or an endorsement providing the exact same coverage. If requested by Consultant, Authority may approve different scopes or minimum limits of insurance for particular subcontractors.
2.10.10 Safety. Consultant shall execute and maintain its work so as to avoid injury or damage to any person or property. In carrying out its Services, the Consultant shall at all times be in compliance with all applicable local, state and federal laws, rules and regulations, and shall exercise all necessary precautions for the safety of employees appropriate to the nature of the work and the conditions under which the work is to be performed. Safety precautions as applicable shall include, but shall not be limited to: (A) adequate life protection and life-saving equipment and procedures; (B) instructions in accident prevention for all employees and subcontractors, such as safe walkways, scaffolds, fall protection ladders, bridges, gang planks, confined space procedures, trenching and shoring, equipment and other safety devices, equipment and wearing apparel as are necessary or lawfully required to prevent accidents or injuries; and (C) adequate facilities for the proper inspection and maintenance of all safety measures.
3. Fees and Payments.
3.1 Compensation. Consultant shall receive compensation, including authorized reimbursements, for all Services rendered under this Agreement at the rates set forth in Exhibit C, attached hereto. The total compensation shall not exceed $400,000 without written approval of Authority’s Board of Directors. Extra Work may be authorized, as described below, and, if authorized, said Extra Work will be compensated at the rates and manner set forth in this Agreement.
8 3.2 Payment of Compensation. Consultant shall submit to Authority a monthly itemized statement which indicates work completed and hours of Services rendered by Consultant.
The statement shall describe the amount of Services and supplies provided since the initial commencement date, or since the start of the subsequent billing periods, as appropriate, through the date of the statement. Authority shall, within 30 days of receiving such statement, review the statement and pay all approved charges thereon.
3.3 Reimbursement for Expenses. Consultant shall not be reimbursed for any expenses unless authorized in writing by Authority.
3.4 Extra Work. At any time during the term of this Agreement, Authority may request that Consultant perform Extra Work. As used herein, “Extra Work” means any work which is determined by Authority to be necessary for the proper completion of the Project, but which the Parties did not reasonably anticipate would be necessary at the execution of this Agreement.
Consultant shall not perform, nor be compensated for, Extra Work without written authorization from Authority’s Representative.
4. Accounting Records. Consultant shall maintain complete and accurate records with respect to all costs and expenses incurred under this Agreement. All such records shall be clearly identifiable. Consultant shall allow a representative of Authority during normal business hours to examine, audit, and make transcripts or copies of such records and any other documents created pursuant to this Agreement. Consultant shall allow inspection of all work, data, documents, proceedings, and activities related to the Agreement for a period of three (3) years from the date of final payment under this Agreement.
5. General Provisions.
5.1 Termination of Agreement.
5.1.1 Grounds for Termination. Authority may, by written notice to Consultant, terminate the whole or any part of this Agreement at any time and without cause by giving written notice to Consultant of such termination, and specifying the effective date thereof, at least sixty (60) days before the effective date of such termination. Upon termination, Consultant shall be compensated only for those services which have been adequately rendered to Authority, and Consultant shall be entitled to no further compensation. Consultant may not terminate this Agreement except for cause.
5.1.2 Effect of Termination. If this Agreement is terminated as provided herein, Authority may require Consultant to provide all finished or unfinished Documents and Data and other information of any kind prepared by Consultant in connection with the performance of Services under this Agreement. Consultant shall be required to provide such documents and other information within fifteen (15) days of the request.
5.1.3 Additional Services. In the event this Agreement is terminated in whole or in part as provided herein, Authority may procure, upon such terms and in such manner as it may 9 determine appropriate, services similar to those terminated.
5.2 Delivery of Notices. All notices permitted or required under this Agreement shall be given to the respective Parties at the following address, or at such other address as the respective parties may provide in writing for this purpose:
Consultant: The Energy Federation, Inc.
Attn: Paul Danehy, CEO
2 Mount Royal Avenue, Suite 325
Marlborough, MA 01752-1960
Authority: Orange County Power Authority
15642 Sand Canyon Ave.
P.O. Box 54283
Irvine, CA 92619-4283
Such notice shall be deemed made when personally delivered or when mailed, forty-eight (48) hours after deposit in the U.S. Mail, first class postage prepaid and addressed to the Party at its applicable address. Actual notice shall be deemed adequate notice on the date actual notice occurred, regardless of the method of service.
5.3 Ownership of Materials and Confidentiality.
5.3.1 Documents & Data; Licensing of Intellectual Property. This Agreement creates a non-exclusive and perpetual license for Authority to copy, use, modify, reuse, or sublicense any and all copyrights, designs, and other intellectual property embodied in plans, specifications, studies, drawings, estimates, and other documents or works of authorship fixed in any tangible medium of expression, including but not limited to, physical drawings or data magnetically or otherwise recorded on computer diskettes, which are prepared or caused to be prepared by Consultant under this Agreement (“Documents & Data”). Consultant shall require all subcontractors to agree in writing that Authority is granted a non-exclusive and perpetual license for any Documents & Data the subcontractor prepares under this Agreement. Consultant represents and warrants that Consultant has the legal right to license any and all Documents & Data. Consultant makes no such representation and warranty in regard to Documents & Data which were prepared by design professionals other than Consultant or provided to Consultant by Authority. Authority shall not be limited in any way in its use of the Documents & Data at any time, provided that any such use not within the purposes intended by this Agreement shall be at Authority’s sole risk.
5.3.2 Intellectual Property. In addition, Authority shall have and retain all right, title and interest (including copyright, patent, trade secret and other proprietary rights) in all plans, specifications, studies, drawings, estimates, materials, data, computer programs or software and source code, enhancements, documents, and any and all works of authorship fixed in any tangible medium or expression, including but not limited to, physical drawings or other data magnetically or otherwise recorded on computer media (“Intellectual Property”) prepared or developed by or on behalf of Consultant under this Agreement as well as any other such Intellectual Property 10 prepared or developed by or on behalf of Consultant under this Agreement.
Authority shall have and retain all right, title and interest in Intellectual Property developed or modified under this Agreement whether or not paid for wholly or in part by Authority, whether or not developed in conjunction with Consultant, and whether or not developed by Consultant. Consultant will execute separate written assignments of any and all rights to the above referenced Intellectual Property upon request of Authority.
Consultant shall also be responsible to obtain in writing separate written assignments from any subcontractors or agents of Consultant of any and all right to the above referenced Intellectual Property. Should Consultant, either during or following termination of this Agreement, desire to use any of the above-referenced Intellectual Property, it shall first obtain the written approval of the Authority.
All materials and documents which were developed or prepared by the Consultant for general use prior to the execution of this Agreement and which are not the copyright of any other party or publicly available and any other computer applications, shall continue to be the property of the Consultant. However, unless otherwise identified and stated prior to execution of this Agreement, Consultant represents and warrants that it has the right to grant the exclusive and perpetual license for all such Intellectual Property as provided herein.
Authority further is granted by Consultant a non-exclusive and perpetual license to copy, use, modify or sub-license any and all Intellectual Property otherwise owned by Consultant which is the basis or foundation for any derivative, collective, insurrectional, or supplemental work created under this Agreement.
5.3.3 Confidentiality. All ideas, memoranda, specifications, plans, procedures, drawings, descriptions, computer program data, input record data, written information, and other Documents and Data either created by or provided to Consultant in connection with the performance of this Agreement shall be held confidential by Consultant. Such materials shall not, without the prior written consent of Authority, be used by Consultant for any purposes other than the performance of the Services. Nor shall such materials be disclosed to any person or entity not connected with the performance of the Services or the Project. Nothing furnished to Consultant which is otherwise known to Consultant or is generally known, or has become known, to the related industry shall be deemed confidential. Consultant shall not use Authority’s name or insignia, photographs of the Project, or any publicity pertaining to the Services or the Project in any magazine, trade paper, newspaper, television or radio production or other similar medium without the prior written consent of Authority.
5.3.4 Infringement Indemnification. Consultant shall defend, indemnify and hold Authority, its directors, officials, officers, employees, volunteers and agents free and harmless, pursuant to the indemnification provisions of this Agreement, for any alleged infringement of any patent, copyright, trade secret, trade name, trademark, or any other proprietary right of any person or entity in consequence of the use on the Project by Authority of the Documents & Data, including any method, process, product, or concept specified or depicted. 11 5.4 Cooperation; Further Acts. The Parties shall fully cooperate with one another and shall take any additional acts or sign any additional documents as may be necessary, appropriate or convenient to attain the purposes of this Agreement.
5.5 Attorney’s Fees. If either Party commences an action against the other Party, either legal, administrative or otherwise, arising out of or in connection with this Agreement, the prevailing party in such litigation shall be entitled to have and recover from the losing party reasonable attorney’s fees and all other costs of such action.
5.6 Indemnification.
5.6.1 To the fullest extent permitted by law, Consultant shall defend (with counsel of Authority’s choosing), indemnify and hold the Authority, its officials, officers, employees, volunteers, and agents free and harmless 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, in any manner arising out of, pertaining to, or incident to any acts, errors or omissions, or willful misconduct of Consultant, its officials, officers, employees, subcontractors, consultants or agents in connection with the performance of the Consultant’s services, the Project or this Agreement, including without limitation the payment of all damages, expert witness fees and attorney’s fees and other related costs and expenses. Consultant shall defend, at Consultant’s own cost, expense and risk, any and all such aforesaid suits, actions or other legal proceedings of every kind that may be brought or instituted against Authority, its directors, officials, officers, employees, agents or volunteers. Consultant shall pay and satisfy any judgment, award or decree that may be rendered against Authority or its directors, officials, officers, employees, agents or volunteers, in any such suit, action or other legal proceeding.
Consultant shall reimburse Authority and its directors, officials, officers, consultants, employees, agents and/or volunteers, for any and all legal expenses and costs, including reasonable attorneys’ fees, incurred by each of them in connection therewith or in enforcing the indemnity herein provided. Consultant's obligation to indemnify shall not be restricted to insurance proceeds, if any, received by Consultant, the Authority, its officials, officers, employees, agents, or volunteers. This section shall survive any expiration or termination of this Agreement.
5.7 Entire Agreement. This Agreement contains the entire Agreement of the Parties with respect to the subject matter hereof, and supersedes all prior negotiations, understandings or agreements. This Agreement may only be modified by a writing signed by both Parties.
5.8 Governing Law. This Agreement shall be governed by the laws of the State of California. Venue shall be in Orange County, California.
5.9 Time of Essence. Time is of the essence for each and every provision of this Agreement.
5.10 Authority’s Right to Employ Other Consultants. Authority reserves right to employ other consultants in connection with this Project.
5.11 Successors and Assigns. This Agreement shall be binding on the successors and 12 assigns of the Parties.
5.12 Assignment or Transfer. Consultant shall not assign, hypothecate, or transfer, either directly or by operation of law, this Agreement or any interest herein without the prior written consent of Authority. Any attempt to do so shall be null and void, and any assignees, hypothecates or transferees shall acquire no right or interest by reason of such attempted assignment, hypothecation or transfer.
5.13 Construction; References; Captions. 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. Any term referencing time, days or period for performance shall be deemed calendar days and not work days.
All references to Consultant include all personnel, employees, agents, and subcontractors of Consultant, except as otherwise specified in this Agreement. All references to Authority include its elected officials, officers, employees, agents, and volunteers except as otherwise specified in this Agreement. The captions of the various articles and 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.
5.14 Amendment; Modification. No supplement, modification, or amendment of this Agreement shall be binding unless executed in writing and signed by both Parties.
5.15 Waiver. No waiver of any default shall constitute a waiver of any other default or breach, whether of the same or other covenant or condition. No waiver, benefit, privilege, or service voluntarily given or performed by a Party shall give the other Party any contractual rights by custom, estoppel, or otherwise.
5.16 No Third Party Beneficiaries. There are no intended third party beneficiaries of any right or obligation assumed by the Parties.
5.17 Invalidity; Severability. If any portion of this Agreement is declared invalid, illegal, or otherwise unenforceable by a court of competent jurisdiction, the remaining provisions shall continue in full force and effect.
5.18 Prohibited Interests. Consultant maintains and warrants that it has not employed nor retained any company or person, other than a bona fide employee working solely for Consultant, to solicit or secure this Agreement. Further, Consultant warrants that it has not paid nor has it agreed to pay any company or person, other than a bona fide employee working solely for Consultant, any fee, commission, percentage, brokerage fee, gift or other consideration contingent upon or resulting from the award or making of this Agreement. For breach or violation of this warranty, Authority shall have the right to rescind this Agreement without liability. For the term of this Agreement, no member, officer or employee of Authority, during the term of his or her service with Authority, shall have any direct interest in this Agreement, or obtain any present or anticipated material benefit arising therefrom.
5.19 Equal Opportunity Employment and Subcontracting. Consultant represents that it 13 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 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, Consultant shall provide equal opportunity for subcontractors to participate in subcontracting opportunities.
5.20 Labor Certification. By its signature hereunder, Consultant certifies that it is aware of the provisions of Section 3700 of the California Labor Code which requires 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.
5.21 Authority to Enter Agreement. Consultant has all requisite power and authority to conduct its business and to execute, deliver, and perform the Agreement. Each Party warrants that the individuals who have signed this Agreement have the legal power, right, and authority to make this Agreement and bind each respective Party.
5.22 Counterparts. This Agreement may be signed in counterparts, each of which shall constitute an original.
5.23 Subcontracting. Consultant shall not subcontract any portion of the work required by this Agreement, except as expressly stated herein, without prior written approval of Authority.
Subcontracts, if any, shall contain a provision making them subject to all provisions stipulated in this Agreement.
[SIGNATURES ON FOLLOWING PAGE]
14 IN WITNESS WHEREOF, the Parties have made and executed this Agreement as of the date first written above.
ORANGE COUNTY POWER
AUTHORITY
By : _________________________________
Name: _______________________________
Title: ________________________________
THE ENERGY FEDERATION, INC
By : _________________________________
Name: Paul Danehy ____________________
Title: President & CEO__________________
ATTEST:
_________________________________
Secretary, Authority Board of Directors
APPROVED AS TO FORM:
_________________________________
General Counsel
*A corporation requires the signatures of two corporate officers.
One signature shall be that of the Chairman of Board, the President or any Vice President, and the second signature (on the attest line) shall be that of the Secretary, any Assistant Secretary, the Chief Financial Officer or any Assistant Treasurer of such corporation.
If the above persons are not the intended signators, evidence of signature authority shall be provided to Authority.
Joseph M. Mosca
Interim Chief Executive Officer
______________________ J hM M
_________________________________
Secretary, Authority Board of Directors
PPROVED AS TO FORM
_____________________
eneral Counsel
Paul Danehy July 7, 2023
Exhibit A
15 EXHIBIT A
SCOPE OF SERVICES
Vendor will create and manage a geo-targeted, Utility-branded online marketplace platform with a dedicated URL address, hosted by a service furnished and operated by Vendor to support OCPA objectives linked to overall program strategy of rebate processing, energy savings generation, and customer engagement. OCPA will retain all rights to the dedicated URL address.
The Residential Product Marketplace Platform will include at a minimum but not be limited to the following categories: smart thermostats, power strips, smart plugs, LED bulbs, and home energy monitors.
The branding will include the OCPA logo and brand colors, subject to OCPA approval before launch.
Consumer-facing information and services on the site will include:
x Product listing for products in the selected categories for sale through the online marketplace. x Rebate or incentive information from OCPA’s programs, with a customer eligibility authentication functionality that will allow rebate to be applied to purchases for eligible measures through the online marketplace.
x Search of all currently available products based on product name, brand, product features, affordability and other categories deemed necessary by OCPA. x Mobile and tablet compatible versions of website (responsive design), accessed through the customer’s mobile web browser.
x Additional product categories may also be listed, subject to OCPA approval. x Quality testing before platform implementation and performance checks will be performed on a pre-described basis.
x Allow space for advertising other OCPA programs.
DIGITAL ADVERTISING CAMPAIGN
Vendor will create and implement a digital marketing/advertising program to acquire OCPA customers for the incentivized products. OCPA will have the right to review and approve all advertising templates and/or materials developed by Vendor prior to implementation. Vendor will:
x Place keyword advertisements in search results and on websites using behavioral as well as context targeting.
x Create and maintain keyword list and ads.
x Create banner ads for online use utilizing OCPA’s logo and brand colors.
INCENTIVE DESIGN
Exhibit A
16 Vendor will participate in the design and marketing of new types of incentives, as approved by OCPA.
Vendor will:
x Assist with the determination of target market for new incentives using product analytics. Vendor will share its methodology with OCPA upon request.
x Assist with the calculation of potential savings to help OCPA determine the cost-effectiveness of program updates.
x Implement new, temporary or seasonal program updates or categories using criteria provided by OCPA.
x Ensure purchase limits of new, temporary or seasonal products will remain consistent with program terms and conditions.
Provide OCPA with metrics relating to program participation through Vendor’s reporting platform.
ONLINE PURCHASING
Vendor will establish a transactional eCommerce marketplace, allowing validated customers with an active service account to purchase OCPA approved products with an instant rebate applied at the time of purchase. This direct-sales application will include:
x Purchased products through this direct-sales application will follow previously described validation process for incentives.
x Purchase limits of approved products will remain consistent with program terms and conditions. x A dedicated toll-free telephone number and email address to provide customer support relating to product returns or other inquiries regarding their purchases.
CUSTOMER SUPPORT SERVICES
Vendor will establish customer support services, including an email address and a toll-free telephone number, to assist customers with the incentive process. Vendor will provide:
x Customer support on all business days in the year, excluding major holidays. x Live phone support during regular business hours for inbound calls from customers regarding questions on products.
x A dedicated email address for customers with questions on products or other general inquiries regarding their incentives or accounts.
x Customer surveys sent to each customer on a recurring basis . x Follow up email communications with customers to encourage future energy efficient purchases. x Metrics of telephone calls or emails received. Additional metrics may be requested by OCPA.
REPORTING AND INVOICING
Vendor will provide OCPA with an online dashboard that will allow OCPA to monitor the progress of the program and will periodically meet with OCPA to assess progress and make program adjustments if necessary.
Exhibit A
17 x Vendor will provide data through a suite of standard marketplace dashboards available on EFI’s reporting platform.
x Information collected through the online dashboards may include total number of impressions, sessions, users, products viewed, average pages per session, incentives redeemed, among other metrics. Additional metrics may be established by OCPA. x Vendor will provide quarterly business reviews to discuss progress and results of the online platform, program performance metrics and customer surveys. 18 EXHIBIT B
COMPENSATION BILLING RATES
19 Consultant shall be paid an amount not to exceed $400,000 for the term of the agreement, including service fees, extended rebates, customer support fees, and program set-up.
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 9.3
-------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Jacquie Henderson, Director of Communications & External Affairs Steven Halligan, Regulatory and Legislative Manager
Approved by: Joe Mosca, Chief Executive Officer
Subject: BASIC SERVICES CHARGE IMPLEMENTATION BY SOUTHERN
CALIFORNIA EDISON
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------
STRATEGIC GOALS
☐ Enrich & Grow the OCPA Community:
☐ Prioritize Fiscal Sustainability & Affordability:
☐ Design & Deploy Community-Aligned Customer Programs:
☐ Energize Our Community with Renewable Energy:
☐ Raise Awareness of Community Energy & Advocate for Our Customers:
☒ Not Applicable: To raise awareness of an important issue that will impact all electric customers in Southern California Edison territory
RECOMMENDED ACTION
Receive and file.
BACKGROUND
Assembly Bill (AB) 205, enacted in June 2022, required the California Public Utilities Commission (CPUC) to establish an income-graduated fixed charge (IGFC) on residential electricity bills with the goal of promoting electrification while reducing electricity bills for low-income customers. The overall goal is to shift fixed grid costs into the fixed portion of the bill so that customers who electrify are not penalized with sharply higher volumetric rates. While this change applies only to the transmission and distribution portion of the electricity bill, which is the responsibility of Southern California Edison (SCE) and not Orange County Power Authority (OCPA), it will affect all customers. OCPA remains responsible only for the generation portion of the bill, which is not impacted by this change.
AB 205 required that the fixed charge have at least three graduated income thresholds, such that low-income ratepayers would realize a lower average monthly bill without making any changes in usage.
In May 2024, after a stakeholder process, the CPUC adopted Decision 24 -05-028 establishing a three-tiered monthly fixed charge with no income verification requirements.
Beginning in November 2025, SCE customers will see a change in the delivery section of their electric bill. It will include a Base Services Charge (BSC) as a separate line item, replacing the current Basic Charge. This change will affect residential customers, including those with solar. The Base Services Charge will have no impact on OCPA generation costs for customers. The Base Services Charge applies only to the delivery portion of the bill, which is under SCE and CPUC jurisdiction. OCPA has no authority over the BSC and does not receive revenue from it.
ANALYSIS AND DISCUSSION
The Base Services Charge will appear as a separate line item on the delivery side of customer bills and will be identical for OCPA customers and SCE bundled customers. There will be no changes to generation rates, Wildfire Fund Change, Climate Credit, or other fixed charges. Volumetric energy delivery charges will decrease approximately 10% (5-7 cents/kWh). These changes do not affect a customer’s rate plan or participation in California Alternative Rates for Energy (CARE), Family Electric Rate Assistance (FERA) or Medical Baseline programs.
Customers will start seeing the BSC on bills issued on or after November 15, 2025. Bills received between November 15 and December 15, 2025 will include a prorated BSC amount based on the number of days in the billing period that fall on or after November 15, 2025.
Below are the approximate BSC amounts that will automatically be applied to customer bills:
• CARE customers: $6 per month
• FERA customers: $12 per month
• Customers in qualified deed-restricted affordable housing (DRAH): $12 per month • Customers not enrolled in CARE, FERA, or living in qualifying DRAH: $24 per month SCE sent notices in English and Spanish to all affected customers in mid-August 2025. They created customized notices for CARE, FERA, and solar customers. More information on this program is available at sce.com/BaseServicesCharge, where customers can also find resources to determine eligibility for a discounted BSC and monthly bill discounts through income-qualified programs.
OCPA is prepared to respond to customer questions and concerns and has provided our call center with talking points and additional information.
FISCAL IMPACT
None
ATTACHMENT
None
ORANGE COUNTY POWER AUTHORITY
Staff Report – Item 10
--------------------------------------------------------------------------------------------------------------------- To: Orange County Power Authority Board of Directors
From: Joe Mosca, Chief Executive Officer
Subject: CHIEF EXECUTIVE OFFICER’S REPORT
Date: November 10, 2025
--------------------------------------------------------------------------------------------------------------------- Irvine Capital Loan Early Repayment Progress
On October 13, 2025, the Board approved the early paydown of the Irvine Capital Loan in accordance with the recommended Option 1 repayment schedule. The Board requested that the first principal repayment of $250,000, together with accrued interest, totaling approximately $900,000, be accelerated and completed as soon as practicable. To implement this direction, staff consulted with U.S. Bank, which confirmed that a formal consent is required for the early repayment, along with a one-time DSCR waiver for Q2 2026, as the early repayment of principal and interest is expected to result in a DSCR below 1.40 for that quarter. The estimated legal and bank fees for this action are approximately $15,000.
On the evening of October 30, 2025, U.S. Bank confirmed that its credit department approved the consent and one-time DSCR waiver for Q2 2026. On October 31, 2025, Chapman and Cutler, the law firm appointed by U.S. Bank, circulated the initial draft of the Consent and Waiver Agreement for OCPA’s legal review. Staff anticipates finalizing the agreement by November 7, 2025, with the first principal and interest payment to the City of Irvine expected during the week of November 10, 2025.
2024 Power Content Label Mailer – Mailing Soon to All Customers Staff, in consultation with the Marketing & Communications Committee, have finalized the 2024 Power Content Label mailer that will be distributed to all customers before the end of the year. A copy of the latest draft is attached to this report for visibility. Staff are looking into beginning production of the mailer on November 12, or shortly thereafter.
Green Prepayment Bonds
On October 13, 2025, the Board authorized staff to continue evaluating and preparing for a potential Green Prepayment Bond transaction, including the engagement of PFM as municipal advisor and Chapman and Cutler as prepay counsel. On October 23, 2025, staff issued an RFP to identify a prepay counterparty bank, with proposals due on November 7, 2025, followed by an evaluation period. The commencement of work is expected on November 28, 2025.
PFM, the selected counterparty, and staff will then collaborate to develop the potential prepay transaction. In December 2025, staff will provide an update on the selected counterparty bank and proposed prepay transaction structure, and seek Board approval to join CCCFA. In January 2026, staff will seek Board approval of the final prepay deal agreements to finalize and execute all prepay transaction documents by the end of the first quarter 2026.
This phased approach allows sufficient time for Board engagement, market preparation, and careful structuring to maximize customer savings while minimizing financial and operational risks.
Revenue Deferral Transfer
As planned in the FY2025/26 Budget, OCPA will utilize the $45 million in previously deferred revenue from FY2023/24 - $15 million in FY2024/25 and $30 million in FY2025/26 - to help offset the anticipated revenue shortfall. This shortfall is primarily driven by the continuation of the 2024 rate design in 2025 and the City of Irvine’s shift from 100% Renewable Choice to Basic Choice. This strategic use of deferred revenue aligns with the Board-approved Rate Stabilization Policy and serves as a key financial tool to support long-term rate stability and affordability. By proactively reallocating these funds, OCPA strengthens its ability to manage financial risks, stabilize rates, and protect customers from market volatility.
Communications & External Affairs Updates
Communications
This week, the UC Irvine Office of the Provost for Teaching and Learning – and the Division of Undergraduate Education – published an article about the UCI ANTreprenuer Center receiving a Community Impact Award at OCPA’s anniversary event. OCPA participated in a press event in Costa Mesa championing the need for clean energy and California’s continued action toward a carbon-neutral electric grid. The press event was hosted by the national, Washington-based Climate Action Campaign and is one of a series of press events taking place across the country, urging federal support of clean energy development.
The Asian Business Association Orange County presented OCPA with the 2025 Energy Visionary Award at their annual gala last week.
The Orange County Register published OCPA’s news release announcing that the 2025 Calpine Grant is open for applications. It is included in the Status Update column, which can be found here.
The 2025-2026 edition of Meet the Mayors is now available, and OCPA has an ad on the back cover (page 16): https://schoolnewsrollcall.com/wp-content/uploads/2025/10/Meet-the-OC-Mayors_2025-2026.pdf. This was a top advertising priority for us, given the readership and distribution.
The Community Advisory Committee has an at-large vacancy. The application has been published to the OCPA website and will be promoted on social media next week. If you have any candidates in mind, please let me know or send them the application directly. OCPA sent out its October newsletter to over 5,000 Orange County community members.
Community Engagement
OCPA partnered with IKEA in Costa Mesa and the UCI Climate and Urban Sustainability Program (CUSP) to hold a partner and networking event on Wednesday. 125 people registered for the event, which included a panel discussion featuring OCPA’s Chair, Sonne, and Selene Lawrence of the City of Irvine. Tristan Miller of California’s Green Business Program facilitated the panel.
Staff attended the Fountain Valley State of the Schools event, where we learned more about the schools in the city – 7 elementary schools and three middle schools. We are interested in Schoolboard Trustees, FV Schools Foundation members, and administrators. Staff also attended the CSUF/OCBC 31st Annual Economic Forecast Conference to learn the forecast on a federal level (positive from predictions of minimal impact from tariffs and limited inflation growth) and a state level (less positive for the impact of federal policies that cut healthcare and Medicaid, and depletion of the workforce due to immigration issues). Looking at California, the main challenge is housing unaffordability.
The impact of California's high gas prices was discussed, and included a report that California has increased drilling to address the issue. The full program report is attached with the Energy section on pages 54 and 55.
OCPA attended the Black Chamber of Commerce Annual Conference and engaged with multiple city and state leaders and sustainability community leaders. Staff, including our newest intern Leva Rohani, tabled at the Newport Mesa Career Fair. It was a crowded event where we engaged students about cleantech careers, and Leva shared her story of transitioning to a “meaningful environmental major”. We learned that Coastline ROP has a new concentration, “Climate and Sustainability,” and OCPA was invited to meet with the students.
We also attended the CSU Fullerton Energy and Sustainability Summit, which included good insights. OCPA attempts to partner and/or support this event annually, but has, to date, not been able to break in as SCE hosts it. We will continue working to be included in this conversation.
I was one of the keynote speakers at the Climate Youth Summit, hosted at UCI by the Irvine Conference of International & Transnational Youth (ICITY). It was truly inspiring to engage in discussions about climate action with young students who are all so enthusiastic and committed to doing everything they can to combat climate change. OCPA participated in one of the year's most significant events—the Irvine Global Village Festival. We engaged with hundreds of residents and acquired over 200 newsletter sign-ups, 58 Instagram followers, and 100 Facebook followers. We also engaged with a number of community members who live in member cities but opted out of service and are considering joining, and customers interested in OCPA programs. Staff attended the UCI Wetland-Wildlife Interface Climate Action Network (WUICAN) Earthrise Climate Action Festival. We connected with conservation organizations, including Crystal Cove Conservancy, Irvine Ranch Conservancy, and Laguna Beach Pacific Marine Mammal Center. We will be following up with UCI’s WEICAN to learn about future partnership events.
The Sustain SoCal Energy Event took place this October. I spoke on a panel to roughly 200 attendees about the value of CCAs and the future of VPPs. We discussed CCAs as vital resources for their ability to be nimble and impactfully champion affordability in transmission and distribution.
The Irvine Green Business organization hosted a recognition event, where OCPA was awarded an Innovator Green Business Award.
Last week, OCPA participated in the Irvine Diwali Festival that drew strong community participation and provided a valuable platform for direct engagement with Irvine residents.
Through OCPA’s booth and materials, we were able to answer questions, distribute educational resources, and highlight our renewable energy options.
External Affairs
We have begun reaching out to Fountain Valley businesses ahead of the shift to OCPA service, with high-load and mission-aligned commercial customers receiving the first calls.
We aim to meet with the OC Sanitation District before the end of the year for a soft introduction.
Staff presented an OCPA 101 overview at the Fullerton Community Center, where we walked customers through the fundamentals of OCPA. There were only around six customers, but the group was very interactive and asked questions about billing and solar compatibility.
OCPA was the featured speaker at this week’s Mayor’s Breakfast in Fountain Valley. We shared an update on OCPA, which was livestreamed to Facebook, emphasizing the community support we’ve provided to the city thus far and the programs' support we provide to member cities.
Director of Communications and External Affairs, Jacquie Henderson, met with the head of the Santa Ana Chamber of Commerce and will be welcomed onto their Board of Directors this month to represent OCPA. This is an excellent opportunity to stay plugged into the business community in one of OC’s most significant cities, which is on OCPA’s radar for future membership.
OCPA presented to the Fountain Valley Women’s Club, where approximately 60 members were in attendance. The group was highly engaged throughout the presentation, with several members asking thoughtful and informed questions about OCPA’s services, enrollment options, and upcoming timelines. Several attendees expressed support for sustainability.
Staff attended the Orange County Business Council (OCBC) Government Affairs Committee’s inaugural meeting at their new office in Irvine, which featured remarks from Assemblymember Tri Ta.
OCPA attended the California Cities Conference in Long Beach this week, where we had the opportunity to hear about climate adaptation in cities, including Los Angeles, and renewable energy implementation from the City of Ventura and the City of Fresno. We also connected with a wealth of Orange County stakeholders from cities including San Juan Capistrano, Mission Viejo, Santa Ana, Lake Forrest, Laguna Woods, Buena Park, Laguna Beach, and Garden Grove. We have followed up with the connections made to share more about OCPA and the benefits to member cities.
Staff toured the first all-electric hospital in Irvine, where we were inspired by the drive and determination it took to bring this engineering marvel to fruition. We also made connections with the communications, project planning, and engineering departments and will keep in touch to collaborate in the future.
We presented to the Mission Viejo Rotary Club, attended by roughly 30 community members, including business owners, retirees, and civic leaders. The presentation generated strong engagement and a productive Q&A session focused on renewable energy and customer choice.
Customer Programs
Community Power Plan: Analysis of survey results determined 11 programs that fit OCPA member cities and their needs. An expert panel of CCA Programs staff identified the following high and medium-priority programs: 1) Direct-to-Renter Electrification and Demand Response (DR) Programs (residents/small business); 2) Comprehensive Energy Efficiency and Electrification Programs, and 3) Refrigeration Efficiency and Electrification Programs. The Executive Summary will be delivered in the coming few days, and the draft CPP will be provided to the CAC at their December meeting for feedback.
Equitable Building Decarbonization Direct Install Grant: LA County was in frequent communication last week regarding different loose ends getting tied up to begin this program. We anticipate the formal launch in November.
Energy Efficiency Kits: Of the original 1,500 inventory, we have less than 150 kits left! Residential Battery Rebate Program: 26 applications have been approved for this program. Calpine Community Benefits Grant: The annual Calpine Community Benefits Grant is now accepting applications for awards ranging from $10,000 - $27,500. This is open to member city organizations advancing energy equity, diversity, and environmental stewardship, funding projects in research, planning, education/workforce development, and environmental/social justice. We hosted an optional informational webinar this week and had approximately eight organizations in attendance interested in learning more about the grant opportunity.
Future programs: OCPA is exploring the Direct-To-Renter protocol to determine a pilot program. The concept is to offer quick, plug-in electric replacements for gas equipment that do not require landlord approval. A portable heat pump HVAC unit (such as an EcoFlow model with a window attachment) would provide around two hours of use and could be paired with a portable battery that charges during off-peak hours. During peak periods (4–9 p.m.), the battery would power the heat pump, enabling demand shifting without permanent installation.
Human Resources Updates
Recruitment
Regulatory Analyst: Our new Regulatory Analyst, Matthew Chill, started on October 16. Data Analyst: Interviews are TBD.
Power Portfolio Manager: Initial candidates have been screened, and finalists are moving to a second panel interview. Interviews will be scheduled soon. External Affairs Manager: Interviews in progress.
Events & Stakeholder Outreach
The OCPA team has attended the following events and community meetings since our last Board meeting.
City Event & Meetings Date Time
Irvine CA Green Business Recognition Wednesday, October 15, 2025 5:00 PM - 7:00 PM Regional 16th Annual Energy Event
(Sustain SoCal) Thursday, October 16, 2025 All day
Anaheim Black Chamber of Commerce
Banquet Thursday, October 16, 2025 5:30 PM - 11:00 PM
Buena Park Buena Park Silverado Days October 17-19 All day Fountain
Valley
B&G Club Huntington Valley
Annual Gala Saturday, October 25, 2025 N/A
Costa Mesa IKEA/UCI/OCPA "Building
Sustainable Communities" Wednesday, October 29, 2025 4:00 PM - 6:30 PM Fullerton OCBC / CSU Fullerton Economic
Forecast Conference Thursday, October 30, 2025 N/A
Fullerton Fullerton Oktoboofest Thursday, October 30, 2025 All day Fullerton Fullerton State of the Agency Tuesday, November 4, 2025 N/A We are looking forward to many opportunities to engage with the community and key stakeholders, including:
City Event & Meetings Date Time
Fullerton Veterans Day Ceremony Tuesday, November 11th 10:30 AM - 12:30 PM
Irvine Aspire Leadership Summit Thursday, November 20th 8:30 AM - 12:00 PM Orange
County FACCOC Gala and Awards Night Friday, November 21st 6:00 PM - 11:00 PM Irvine Healthy for the Holidays Saturday, November 22nd 8:30 AM - 3:30 PM Fullerton Tree Lighting Friday, December 5th 5:00 PM - 9:00 PM Buena Park Christmas Tree Lighting Friday, December 5th 6:00 PM - 8:00 PM Irvine Illuminate Irvine Saturday, December 6th 3:00 PM - 7:00 PM Fountain
Valley FV Annual Tree Lighting Saturday, December 6th 4:30 PM - 8:00 PM Fountain
Valley Holiday Decorating Contest Wednesday, December 10th TBD Fullerton First Night Wednesday, December 31st 7:00 PM - 11:59 PM Attachments:
Attachment A – Non-Power Supply Contracts In Excess of $50,000 to Under $100,000 Attachment B – OCPA 2024 Power Content Label Mailer - DRAFT 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 P.O. Box 54283
Irvine, CA 92619-4283
Together, we are creating a healthier, more resilient Orange County.
Sign up for our bi-monthly newsletter to stay in touch.
If you previously opted-out and would like to re-enroll in OCPA, give us a call at (866) 262-7693 or email us at [email protected] and we’ll walk you through it.
Powering the
Communities
We Call Home
$1.5M dedicated toward programs
to save customers money and energy
this fiscal year.
1,244 surveys collected for the
OCPA Community Power Plan, an
outline of upcoming money- and
energy-saving programs.
$300,000+ in grants awarded to nonprofit
organizations for advancing clean energy
and sustainability initiatives over three years.
$300,000+ invested in local nonprofit
organizations for community connection
and engagement over three years.
81% renewable from
68% carbon-free resources
Well above mandatory state requirements for the purchase of renewable energy.
Reduced over 2 billion lbs of CO2 emissions
since 2022, equivalent to taking over 223,000
gas-powered vehicles off the road
Reinvesting in the Community
Thank you for the privilege of being your local, not-for-profit clean energy provider.
Orange County Power Authority’s (OCPA) Power Content Label (PCL) demonstrates that OCPA continues to exceed the state’s mandatory requirements for renewable energy purchases and has also surpassed its voluntary renewable goals for each retail service offering.
Under the California Energy Commission Power Source Disclosure Program, retail suppliers, including OCPA, are required to disclose the mix of sources used to provide electricity service during the previous calendar year. The information reported in the PCL is reviewed by the California Energy Commission and must be presented according to high prescriptive regulations.
Designed to help customers
take control of their energy use,
reduce costs and ease strain on
the electricity grid. Offers eligible
customers a $1,000 rebate toward
the purchase and installation of a
home battery storage system.
Battery Storage Rebate
A one-stop shop for all available state, federal
and local rebates. The OCPA Incentive Finder
helps customers find the incentives they are
eligible for, based on their information. From
appliances to solar panels to electric vehicles,
customers can save money while making their
home and transportation greener.
Incentive Finder
What drives OCPA is purpose,
not profits. We exist to give
you an option for your energy,
support your energy-related
decisions and reinvest in the
communities we serve. As an
OCPA customer, you have
access to money-saving and
energy efficiency programs.
Visit ocpower.org/energy-programs
to learn more.
Customer Rebate Programs
More energy programs are on their way!
Watch for the OCPA Community Power Plan in early 2026.
Most customers—57.2% of retail sales—
chose 100% Renewable Choice, with
Smart Choice representing 19.1% and
Basic Choice 23.7% of sales. Therefore,
OCPA purchased an aggregate portfolio of
approximately 81% renewable energy on
behalf of its customers, with approximately
68% coming from carbon-free resources.
Basic Choice includes 44%
renewable energy, which is
determined by adding 25% RPS
Eligible Renewables plus 19%
retired unbundled RECs.