4928-4030-8872 v2
Submitted for Board consideration:
___________________________________
Gregory Wade
Chief Executive Officer
ATTACHMENTS:
A. Resolution No. 2026-009
CLEAN ENERGY ALLIANCE
RESOLUTION NO. 2026-009
A RESOLUTION OF THE BOARD OF DIRECTORS OF THE CLEAN ENERGY ALLIANCE
AUTHORIZING TELECONFERENCING TO BE USED AT REGULAR MEETINGS WHEREAS, on October 3, 2025, the Governor signed into law Senate Bill 707 (“SB 707”) amending California Government Code § 54950 et seq. and permitting members of a multijurisdictional body, as defined therein, to conduct teleconference meetings pursuant to California Government Code § 54953.8.7, so long as certain procedural and substantive requirements are met, including that the body must adopt a resolution authorizing the use of teleconferencing at its meetings pursuant to that section; and WHEREAS, the Clean Energy Alliance (“CEA”) is a multijurisdictional body as defined by SB 707 and wishes to provide for the use of teleconferencing at the regular meetings of its Board of Directors (“Board”) and Community Advisory Committee (“CAC”) pursuant to California Government Code section 54953.8.7; and
WHEREAS, in order to conduct a teleconference meeting pursuant to California Government Code § 54953.8.7, all of the following must be met: At least a quorum of the Board or CAC must participate from one or more physical locations that are open to the public and within the boundaries of the territory over which CEA exercises jurisdiction; a Director or Member who participates in a meeting remotely shall not receive compensation for that meeting; a Director or Member who participates in a meeting remotely must be identified on the agenda, be at least twenty (20) miles away from any physical location of the meeting, and participate in the meeting through audio and visual technology; and each Director or Member may each attend up to two meetings per calendar year remotely.
WHEREAS, in addition to teleconference meetings held pursuant to Government Code § 54953.8.7, teleconference meetings may also be held pursuant to any teleconferencing provisions that are applicable to a meeting under the law.
NOW, THEREFORE, BE IT RESOLVED, by the Board of Directors of the Clean Energy Alliance, that commencing February 26, 2026, the Board and the CAC may conduct its regular meetings by teleconference pursuant to Government Code § 54953.8.7.
The foregoing Resolution was passed and adopted this 29th day of January, 2026, at a regular meeting of the Clean Energy Alliance, by the following vote:
AYES:
NOES:
ABSENT:
ABSTAIN:
APPROVED:
________________________________________ [VACANT], Board Chair ATTEST:
_______________________________ Ana Marie Alarcon, Clerk to the Board Attachment A
Staff Report
DATE: January 29, 2026
TO: Clean Energy Alliance Board of Directors
FROM: Greg Wade, Chief Executive Officer
ITEM 12: Clean Energy Alliance Chief Executive Officer Operational and Administrative Report RECOMMENDATION:
Receive and File the Chief Executive Officer (CEO) Operational and Administrative Report.
BACKGROUND AND DISCUSSION:
This report provides an update to the Clean Energy Alliance (CEA) Board regarding operational and administrative activity.
OPERATIONAL UPDATE
Frontwave Arena Sponsorship Agreement
Clean Energy Alliance has executed a one-year, $40,000 sponsorship agreement with Oside Arena Management, LLC for Frontwave Arena, effective January 1–December 31, 2026. The sponsorship advances CEA’s public education and outreach objectives through game night ticket allocations, a designated CEA-sponsored game, on-site booth activations, in-arena messaging, and a month-long sustainability content series. Booth activations provide direct engagement with attendees, allowing staff to educate customers on CEA programs, energy efficiency, and clean energy resources in a high-traffic community venue.
The partnership extends CEA’s regional reach through Frontwave Arena and its affiliated teams, with a combined social media following of approximately 98,700 (Frontwave Arena: 34.7K; SD Clippers: 13.9K; SD Sockers: 50.1K). The agreement includes standard public agency protections and will be administered using a program-based, non-discretionary framework aligned with CEA’s public-purpose mission and applicable law.
CEA in the Community
To provide opportunities for the customers and communities we serve to meet with CEA staff and have their questions answered, staff continues to attend many in-person community events, organize and hold community workshops and give presentations. CEA has been busy with many of these scheduled outreach efforts. Recent events and presentations that CEA participated in:
January 29, 2026
CEO Admin. Report
DATE DESCRIPTION CITY
December 6, 2025 4th Annual Community Tamalada Oceanside December 10, 2025 Solana Beach City Council Presentation Solana Beach December 12, 2025 Winterfaith Holiday Sponsor a Family Escondido January 12, 2026 California League of Cities, San Diego Division Online Upcoming events in which CEA will be participating include:
DATE DESCRIPTION CITY
February 7, 2026 Frontwave Arena, Throwback/Alumni Night Oceanside March 17, 2026 San Marcos City Council Presentation San Marcos March 25, 2026 Vista Unified STEM 2 Career Expo Vista
March 27, 2026 CEA Sponsorship Night at Frontwave Arena Oceanside April 25, 2026 Earth Day/ Dia del Niño Oceanside
Call Center Activity and Participation Statistics
The following chart reflects customer activity through December 31, 2025.
Call volumes to CEA’s Call Center increased 15% from November 2025 to December 2025. The most common call topics for all customers (commercial and residential) were related to Billing inquiries, Net Energy Metering, and General Info.
The total number of calls received, response times, and call duration through December 31, 2025, were as follows:
942
753 719
540
420
516
643 678 693
738
449
517
0 100
200
300
400
500
600
700
800
900
1000
Jan-25 Feb-25 Mar-25 Apr-25 May-25 Jun-25 Jul-25 Aug-25 Sep-25 Oct-25 Nov-25 Dec-25 Total Calls Calls Connected to Agents
January 29, 2026
CEO Admin. Report
Call Center Monthly Summary – December 2025
Stats by Month Dec Nov Oct Sept Total
Total Calls 517 449 738 693 33,847
Total Calls Connected to
Agents 513 449 742 689 33,207
Average Seconds to Answer 0:00:06 0:00:06 0:00:08 0:00:14 Average Call Duration 0:09:27 0:10:08 0:10:19 0:09:33
The following table reflects enrollments in CEA’s power supply products by City. As of December 31, 2025, CEA has a total of 256,024 enrolled customer accounts as follows:
Member
City
Eligible
Accounts
Clean Impact –
50%
Renewable
Clean Impact
Plus - 75%
Carbon Free
Green Impact
– 100%
Renewable
Participation
Rate
Carlsbad 55,240 167 49386 655 91%
Del Mar 3,011 7 2748 71 94%
Escondido 57,298 162 53413 69 94%
Oceanside 74,491 209 69074 103 93%
San Marcos 37,957 118 35229 73 93%
Solana
Beach 7,839 15 6978 155 91%
Vista 39,574 84 36979 329 94%
TOTAL 275,410 762 253,807 1,455 93%
Solar Plus and Battery Bonus Update
As of January 13, Solar Plus has 23 active applicants and eight operational participants, or participants who have completed installation and received Permission to Operate for their solar and battery systems.
Battery Bonus currently has no active applicants or operational participants. Solar Plus Connect and Battery Bonus Connect have 34 and 58 active applicants, respectively.
The table on the following page includes a breakdown of active and completed projects by program and member city. Active projects include any applicants currently in the pipeline and completed projects include any applicants with projects that are complete and have received Permission to Operate. Battery Bonus Connect has 38 installations complete, pending Permission to Operate.
January 29, 2026
CEO Admin. Report
Member
City
Solar Plus Solar Plus Connect Battery Bonus Battery Bonus Connect
Status Active Complete Active Complete Active Complete Active Complete Carlsbad 5 1 3 0 0 0 10 0
Del Mar 0 0 1 0 0 0 1 0
Escondido 6 4 13 0 0 0 11 0
Oceanside 4 1 6 0 0 0 15 0
San Marcos 4 1 3 0 0 0 8 0
Solana
Beach
2 0 1 0 0 0 1 0
Vista 2 1 7 0 0 0 12 0
TOTAL 23 8 34 0 0 0 58 0
Solar Plus Connect Self-Generation Incentive Program (SGIP) funding remains at $1,053,458 in either approved or submitted for approval. Battery Bonus Connect currently has a total of $1,174,853 in SGIP funding either approved or submitted for approval. Funding through SGIP for Solar Plus Connect and Battery Bonus Connect continues to be open for waitlist applications only. A breakdown of SGIP funding by member cities is included in the following table.
Member City Solar Plus Connect Battery Bonus Connect
Carlsbad $91,080 $217,800
Del Mar $30,360 $19,800
Escondido $408,480 $257,400
Oceanside $188,520 $382,823
San Marcos $90,685 $198,000
Solana Beach $29,485 $39,600
Vista $214,848 $274,854
TOTAL $1,053,458 $1,174,853
PeakSmart Savers Update
As of January 13, 2026, the PeakSmart Savers program has 48 active participants. Recent marketing efforts include a marketing email sent on December 4th, a mailer sent on November 3rd and ongoing in-person outreach at community events. The email and mailer targeted customers previously enrolled in SDGE’s similar program, TOU-DR-P.
To date, in-person outreach has been the most effective in capturing signups. Of the 48 current participants, in-person outreach accounts for 25% of signups followed by mailers at 21% and emails at 10%. The remaining enrollments come from social media, other sources or were untracked.
On December 30, 2025, CEA published updated terms and conditions, which extend bill protection for an additional year through December 31, 2026 and specify that PeakSmart Days will only occur on weekdays and will exclude weekends and holidays. Previously, bill protection was set to end on December 30, 2025, with a 12-month guarantee for customers enrolled before that date. After the 12-month period, CEA will compare actual charges to what participants would have paid without having been enrolled in PeakSmart January 29, 2026
CEO Admin. Report
Savers. If the charges are higher, CEA will issue a check refund of the difference by mail. The revised terms and conditions extend this bill protection through December 2026.
CEA has not declared a PeakSmart Day since October 29, 2025, which aligns with expectations as demand is typically lower during winter and PeakSmart Days are reserved for high-demand days.
Member City PeakSmart Savers Participants
Carlsbad 10
Del Mar 1
Escondido 6
Oceanside 16
San Marcos 1
Solana Beach 0
Vista 14
TOTAL 48
Bill Calculator Tool Launch
As of January 12, 2026, CEA has launched its new Bill Comparison Calculator. This calculator is a self-service, digital resource on the CEA website to help customers understand their energy bills and easily compare their costs. The calculator provides a clear, side-by-side comparison of CEA’s three energy options versus San Diego Gas & Electric. The calculators’ inputs are customizable to provide individualized results based on customer usage, separated by Winter and Summer Usage and times of use. This tool is available for most residential and commercial rates.
Oversight Committee (ROC)
The next quarterly Risk Oversight Committee (ROC) meeting is scheduled for March 5, 2026.
Risk Contracts $50,000 - $100,000 entered into by Chief Executive Officer
VENDOR DESCRIPTION AMOUNT
None.
FISCAL IMPACT:
There is no fiscal impact with this action.
Submitted for Board consideration:
___________________________________
Gregory Wade
Chief Executive Officer
ATTACHMENTS: None.
Staff Report
DATE: January 29, 2026
TO: Clean Energy Alliance Board of Directors
FROM: Gregory Wade, Chief Executive Officer
ITEM 13: Receive Regulatory Update from Keyes & Fox
RECOMMENDATION:
Receive the Regulatory Update from Keyes & Fox.
BACKGROUND AND DISCUSSION:
Clean Energy Alliance (CEA) contracts with Keyes & Fox for Regulatory Advocacy related activities. Each month Keyes & Fox provides an update to the CEA Board on key items of interest. This month’s update will focus on the Power Charge Indifference Adjustments (PCIA) Order Instituting Rulemaking (OIR) and Final Energy Resource Recovery Account (ERRA) rates.
FISCAL IMPACT:
There is no fiscal impact from this action.
Submitted for Board consideration:
___________________________________
Gregory Wade
Chief Executive Officer
ATTACHMENTS:
A. Keyes & Fox Regulatory Report
1 Clean Energy Alliance
Regulatory Monitoring Report
To: Clean Energy Alliance (CEA) Board of Directors
From:
Tim Lindl, Partner, Keyes & Fox LLP
Jacob Schlesinger, Partner, Keyes & Fox LLP
Jason Hoyle, Director of Research, EQ Research LLC
Subject: Monthly Regulatory Memo
Date: January 20, 2026
Keyes & Fox LLP and EQ Research LLC are pleased to provide CEA’s Board of Directors with this informational memo describing recent developments in key California regulatory and compliance-related updates from the California Public Utilities Commission (CPUC). Additional information is available in CEA’s Digest of Regulatory Updates.
IRP Rulemaking (R.25-06-019)
• On January 16, the CPUC issued a Ruling setting the IRP filing requirements for LSEs. The deadline for filing individual LSE IRPs is June 1. Comments on IRP filings are due July 15. LSEs are required to use the provided narrative and quantitative templates to submit at least one portfolio that conforms to a 25 million metric ton (MMT) GHG emissions limit in 2035 and a limit of 8 MMT by 2045, and LSEs may submit an additional portfolio that goes beyond the required GHG emissions limits. • On January 14, the CPUC issued a Proposed Decision requiring 2029-2032 electric resource procurements and transmitting portfolios for the 2026-2027 Transmission Planning Process (TPP). The Proposed Decision may be as heard as soon as the February 26 Commission meeting. Comments on the PD are due February 3 and reply comments are due February 9. The new procurement is intended to target resources that are eligible for the expiring federal tax credits.
• The Proposed Decision requires additional statewide mid-term reliability (MTR) procurement of 2,000 MW by 2030 and 4,000 MW by 2032 for a total of 6,000 MW of net qualifying capacity (NQC), of which CEA’s obligation is 25 MW by 2030 and 50 MW by 2032 for a total of 75 MW (Attachment A). Eligible resources are subject to the same standards as in previous MTR procurements, such as being RPS-eligible and online after January 1, 2020, and the rules regarding baseline swaps, waivers, and obligation swaps are also extended.
Energy storage resources are limited to no more than half of each tranche’s NQC. Compliance will be assessed separately for each tranche requirement.
Resource Adequacy Rulemaking (R.25-10-003)
• On December 12, the Assigned Commissioner issued a Scoping Memo and Ruling dividing the 2027-2028 Resource Adequacy (RA) proceeding into two tracks. Track 1 will consider immediate priority issues such as hourly resource/obligation transactability, accreditation and accounting methodologies for long-duration storage resources, unforced capacity outages for thermal resources, and solar and wind resources, and is expected to conclude by early July 2026.
• Transactability under the SOD framework would allow hourly transactions for RA compliance, allowing load-serving entities (LSEs) with complimentary load curves that may experience peak load during different hours to provide excess RA resources to other LSEs for those hours. The concept would improve the overall efficiency and cost-effectiveness of existing and new RA resources by allowing one party’s unused RA capacity in some hours to be used by another party in those hours. A Energy Division report on transactability issues is expected February 6, party proposals on transactability issues are due February 20, and a transactability workshop is scheduled for February 24.
Attachment A
2 • Track 2 will consider less time-sensitive issues, including the 2028 and 2029 planning reserve margin (PRM), and is expected to conclude by June 2027. Draft PRM studies from Energy Division and parties will be due in August 2026.
SDG&E 2026 ERRA Forecast (A.25-05-012)
• On December 5, the CPUC issued D.25-12-008 adopting SDG&E’s updated 2026 revenue requirement forecast of $824.1 million, effective January 1, 2026, which is $701.8 million higher than its currently effective revenue requirement of $122.3 million. For CCA customers, a typical non-CARE residential customer using 400 kWh can expect to see a monthly bill increase of around $29.0 (30.1% increase) while a typical unbundled residential CARE customer using 400 kWh can expect to see a monthly bill increase of around $21.0 (44.2% increase).
ERRA/PCIA Reform (R.25-02-005)
• On December 26, the ALJ issued a Ruling scheduling the revised Track 2 prehearing conference for January
23. The initially scoped Track 2 included a broad list of issues that will now be addressed in a Track 3 later in 2026. The new Track 2 is focused on the emergent issue in the recent ERRA forecast proceedings of valuation of pre-2019 RECs and how that valuation is applied to IOU bundled customers and departed load customers like those of CCAs.
SDG&E Cost of Capital (A.25-03-013)
• On December 22, the CPUC issued D.25-12-043 setting the cost of capital and capital structure for the major investor-owned utilities. The Decision approved an overall rate of return for SDG&E of 7.41%. SDG&E’s approved capital structure is 45.25% debt and 54.75% equity (including 2.75% preferred equity). The approved cost of debt for SDG&E is 4.59%, cost of preferred equity is 6.22%, and cost of common equity is
9.93%.
Palomar Decarbonization (A.25-12-009)
• On December 16, SDG&E submitted an Application requesting approval for the Palomar Decarbonization Demonstration Project and recovery of about $20 million in actual and forecasted expenses between 2021 and 2036. Under the proposal the Project’s $12.2 million revenue requirement for the years 2023 through 2027 will be recovered via distribution rates beginning January 1 following a decision on the Application. The Commission previously denied SDG&E’s proposal for the Palomar Project in its 2024 rate case proceeding citing a lack of information, particularly regarding ratepayer costs. • The Palomar Project is SDG&E’s integrated hydrogen system at the Palomar Energy Center (PEC), a 588 MW combined-cycle natural gas plant, which consists of onsite hydrogen production, storage, blending into turbines, and fueling of hydrogen vehicles. According to the Application, the research, demonstration, and development Project’s purpose is to allow SDG&E to gain critical knowledge, expertise, and real-life operational experience of clean hydrogen’s role in electric system decarbonization.
Staff Report
DATE: January 29, 2026
TO: Clean Energy Alliance Board of Directors
FROM: Gregory Wade, Chief Executive Officer
ITEM 14: Public Hearing to Consider Adoption of Resolution No. 2026-009 Approving a Rate Relief Credit for Residential and Non-Residential Customers and Adoption of Resolution No. 2026-010 Reducing Agriculture Rates
RECOMMENDATION:
That the Clean Energy Alliance (CEA) Board of Directors (Board):
1) Conduct the Public Hearing: Open the Public Hearing, Receive Public Testimony, and Close the Public Hearing;
2) Adopt Resolution No. 2026-009 Approving Rate Relief Credits for Residential and Non-Residential Customers; and
3) Adopt Resolution No. 2026-010 Approving a 6.9% Rate Reduction for Agriculture Rates.
BACKGROUND AND DISCUSSION:
At the Board Meeting on November 20, 2025, staff presented information regarding the 2026 San Diego Gas & Electric (SDG&E) Energy Resource Recovery Account (ERRA) rate proceeding in which the preliminary Power Charge Indifference Adjustment (PCIA) rates were projected to increase dramatically from current levels. At that meeting, the rates were still preliminary, with final rates anticipated at the end of December 2025, with an effective date of January 1, 2026. The final 2026 PCIA rates were made official via an SDG&E Advice Letter (AL 4757-E) and, in general, continue to represent a significant increase in PCIA rates for all four vintage years (VY) in CEA’s service territory, with only moderate changes for each customer class in each VY.
The Board directed staff to return to this meeting with the final adopted 2026 SDG&E PCIA rate impacts, and a Rate Relief Credit proposal that would achieve rate parity with SDG&E for CEA’s highest PCIA vintage rate on the Clean Impact power supply product for residential rate TOU-DR1 and for the non-residential rate TOU-AS. These rates were selected due to the majority of customers being served on these rates.
The analysis of the bill comparisons between SDG&E’s 2026 final rates and CEA’s current rates for customers on rates TOU-DR1 and TOU-AS resulted in the following Rate Relief Credit per kilowatt-hour (kWh) to achieve the desired minimum rate parity results for the Clean Impact power supply product. If approved, the adjustments would apply for the 11-month period beginning on February 1, 2026 through December 31, 2026.
January 29, 2026
Rate Relief and Rate Adjustment
Residential Customers $0.03871 per kWh
Non-Residential Customers $0.02657 per kWh
The average bill comparisons for TOU-DR1 residential customers for the various vintage years after taking into account the proposed Rate Relief Credit are shown in the table below (negative value indicates rate savings):
Residential (Average Monthly Bill = $174.25)
Vintage Year Cities Avg Monthly Bill Variance to SDG&E for customers opted down to Clean Impact
2017 Solana Beach ($0.10) per month
2020 Carlsbad & Del Mar Parity
2022 Escondido & San Marcos ($2.16) per month
2023 Oceanside & Vista ($2.80) per month
The average bill comparisons for non-residential customers for the various vintage years after taking into account the proposed Rate Relief Credit are shown in the tables below (negative value indicates savings):
Small Commercial (Average Monthly Bill = $447.67)
Vintage Year Cities Avg Monthly Bill Variance to SDG&E for customers opted down to Clean Impact
2017 Solana Beach ($0.24) per month
2020 Carlsbad & Del Mar Parity
2022 Escondido & San Marcos ($6.38) per month
2023 Oceanside & Vista ($8.02) per month
Medium/Large Commercial (Average Monthly Bill = $9,665.38) Vintage Year Cities Avg Monthly Bill Variance to SDG&E for customers opted down to Clean Impact
2017 Solana Beach ($247.67) per month
2020 Carlsbad & Del Mar ($241.62) per month
2022 Escondido & San Marcos ($441.06) per month
2023 Oceanside & Vista ($484.10) per month
Agricultural (Average Monthly Bill = $353.82)
Vintage Year Cities Avg Monthly Bill Variance to SDG&E for customers opted down to Clean Impact
2017 Solana Beach $11.46 per month higher
2020 Carlsbad & Del Mar $11.79 per month higher
2022 Escondido & San Marcos $5.51 per month higher
2023 Oceanside & Vista $3.69 per month higher
January 29, 2026
Rate Relief and Rate Adjustment
Lighting (Average Monthly Bill from SDG&E = $351.06)
Vintage Year Cities Avg Monthly Bill Variance to SDG&E for customers opted down to Clean Impact
2017 Solana Beach ($22.15) per month
2020 Carlsbad & Del Mar ($21.95) per month
2022 Escondido & San Marcos ($27.59) per month
2023 Oceanside & Vista ($28.77) per month
As shown above, the proposed non-residential Rate Relief Credit achieves cost parity, or better, for all PCIA vintages for all non-residential customer classes with the exception of the agricultural rate class.
Agriculture Customer Class Rate Reduction
To address the disparity for the agricultural rate class, staff recommends a 6.9% rate reduction for the agriculture rate schedules. The estimated financial impact of this rate reduction is approximately $38,000 annually.
The financial impact of the proposed Rate Relief Credit, under certain opt down assumptions, are shown in the table below:
CUSTOMER CLASS OPT DOWN ASSUMPTION FINANCIAL IMPACT
Residential 30,000 customers (13% of total) $5,156,000
Small Commercial 20% of customers $1,778,000
Medium/Large Commercial 20% of customers $3,589,000
Agriculture 20% of customers $23,000
Lighting 20% of customers $46,000
TOTAL ESTIMATED FINANCIAL IMPACT $10,592,000
Financial Impact of Recommended Amounts in the fiscal year ending June 30, 2026 The table below shows the estimated financial position and days liquidity on hand as of June 30, 2026 compared to the approved Budget, and the estimated position as of December 31, 2026. As shown, CEA would still be expected to meet its overall budget even if the assumed number of Opt Down customers is realized. Through June 30, 2026, the Change in Net Position is projected to be approximately $4.0 million better than Budget even if the resolutions are adopted in full.
Budget Before Proposal After Proposal Before Proposal After Proposal Change in Net Position $ 35,862,650 $ 43,415,990 $ 39,981,217 Ending Net Position $ 50,649,916 $ 64,795,102 $ 60,360,330 $ 102,568,306 $ 92,842,129 Days Liquidity on Hand 81 88 84 135 126
Through June 30, 2026 Through December 31, 2026
Financial Projection Financial Projection
January 29, 2026
Rate Relief and Rate Adjustment
Submitted for Board consideration:
___________________________________
Gregory Wade
Chief Executive Officer
ATTACHMENTS:
A. Resolution No. 2026-009 Establishing the Rate Relief Credit B. Resolution No. 2026-010 Reducing Agriculture Rates
CLEAN ENERGY ALLIANCE
RESOLUTION NO. 2026-009
A RESOLUTION OF THE BOARD OF DIRECTORS OF THE CLEAN ENERGY ALLIANCE ESTABLISHING RATE RELIEF CREDITS EFFECTIVE FEBRUARY 1, 2026 THROUGH DECEMBER 31, 2026
WHEREAS, the Clean Energy Alliance (CEA) is a joint powers agency formed on November 4, 2019, under the Joint Exercise of Power Act, California Government Code section 6500 et seq.; and WHEREAS, Section 4.6 of the Joint Powers Authority (JPA) Agreement establishes the specific responsibility of the CEA Board of Directors to adopt retail rates for power; and WHEREAS, the CEA Board desires to establish Rate Relief Credits to address impacts of increased San Diego Gas & Electric Power Charge Indifference Adjustment rate increases; and WHEREAS, the Public Hearing Notice was published in the San Diego Union Tribune on January 19 and January 26, 2026 and posted on January 19, 2026.
NOW, THEREFORE, BE IT RESOLVED, by the Board of Directors of the Clean Energy Alliance, as follows:
Section 1. The Board of Directors of the Clean Energy Alliance hereby adopts and approves the following Rate Reduction Credits:
Residential $0.03871 per kWh
Non-Residential $0.02657 per kWh
Section 2. Rate Reduction Credits in Section 1 above shall be effective February 1, 2026 through December 31, 2026.
The foregoing Resolution was passed and adopted this 29th day of January 2026, by the following vote:
AYES:
NOES:
ABSENT:
ABSTAIN:
APPROVED:
________________________________________
[VACANT], Board Chair
ATTEST:
_______________________________
Ana Marie Alarcon, Clerk to the Board
Attachment A
CLEAN ENERGY ALLIANCE
RESOLUTION NO. 2026-010
A RESOLUTION OF THE BOARD OF DIRECTORS OF CLEAN ENERGY ALLIANCE REDUCING AGRICULTURE RATES EFFECTIVE FEBRUARY 1, 2026 THROUGH DECEMBER 31, 2026
WHEREAS, Clean Energy Alliance (CEA) is a joint powers agency formed on November 4, 2019, under the Joint Exercise of Power Act, California Government Code section 6500 et seq.; and WHEREAS, Section 4.6 of the Joint Powers Authority (JPA) Agreement establishes the specific responsibility of the CEA Board of Directors to adopt retail rates for power; and WHEREAS, on January 29, 2026, the CEA Board adopted Resolution No. 2026-009, adopting non-residential Rate Relief Credit that achieve cost parity, or better, for all PCIA vintages for all non-residential customer classes with the exception of the agricultural rate class; and WHEREAS, the CEA Board desires to reduce Agriculture rates by 6.9%; and WHEREAS, the resulting rates are attached as Exhibit A; and WHEREAS, the Public Hearing Notice was published in the San Diego Union Tribune on January 19 and January 26, 2026 and posted on January 19, 2026; and NOW, THEREFORE, BE IT RESOLVED, by the Board of Directors of the Clean Energy Alliance, as follows:
Section 1. The Board of Directors of the Clean Energy Alliance hereby adopts and approves the reduced agriculture rates reflected in Exhibit A.
Section 2. The reduced agriculture rates reflected in Exhibit A shall be effective February 1, 2026 through December 31, 2026.
Attachment B
CEA No. Resolution 2026-010
AG Rate Reduction
The foregoing Resolution was passed and adopted this 29th day of January 2026, by the following vote:
AYES:
NOES:
ABSENT:
ABSTAIN:
APPROVED:
________________________________________
[VACANT], Board Chair
ATTEST:
_______________________________
Ana Marie Alarcon, Clerk to the Board
Exhibit A
Clean Energy Alliance
Proposed Amended Agriculture Rate Schedule
Effective February 1, 2026
CCA Rate Name Season Charge Type
Time of Use
Period
per kWh New
Rate
per kWh
Current
Rate % Change
TOU-PA-S Summer Generation On-Peak 0.33354 0.35826 -6.90% TOU-PA-S Summer Generation Off-Peak 0.16498 0.17721 -6.90% TOU-PA-S Winter Generation On-Peak 0.19366 0.20801 -6.90% TOU-PA-S Winter Generation Off-Peak 0.06654 0.07147 -6.90% TOU-PA-P Summer Generation On-Peak 0.33167 0.35625 -6.90% TOU-PA-P Summer Generation Off-Peak 0.16394 0.17609 -6.90% TOU-PA-P Winter Generation On-Peak 0.19248 0.20675 -6.90% TOU-PA-P Winter Generation Off-Peak 0.06608 0.07098 -6.90% TOU-PA-2-S Summer Demand On-Peak 17.47 18.76 -6.90%
TOU-PA-2-S Summer Generation On-Peak 0.20464 0.21981 -6.90% TOU-PA-2-S Summer Generation Off-Peak 0.11449 0.12297 -6.90% TOU-PA-2-S Summer Generation
Super Off-Peak 0.06264 0.06728 -6.90%
TOU-PA-2-S Winter Generation On-Peak 0.22679 0.24360 -6.90% TOU-PA-2-S Winter Generation Off-Peak 0.10330 0.11096 -6.90% TOU-PA-2-S Winter Generation
Super Off-Peak 0.06742 0.07242 -6.90%
TOU-PA-2-P Summer Demand On-Peak 17.39 18.68 -6.90%
TOU-PA-2-P Summer Generation On-Peak 0.20369 0.21879 -6.90% TOU-PA-2-P Summer Generation Off-Peak 0.11394 0.12238 -6.90% TOU-PA-2-P Summer Generation
Super Off-Peak 0.06227 0.06689 -6.90%
TOU-PA-2-P Winter Generation On-Peak 0.22552 0.24223 -6.90% TOU-PA-2-P Winter Generation Off-Peak 0.10264 0.11025 -6.90% TOU-PA-2-P Winter Generation
Super Off-Peak 0.06702 0.07199 -6.90%
TOU-PA-3-S <20kW Summer Generation On-Peak 0.38939 0.41825 -6.90% TOU-PA-3-S <20kW Summer Generation Off-Peak 0.19113 0.20530 -6.90% TOU-PA-3-S <20kW Summer Generation
Super Off-Peak 0.06874 0.07383 -6.90%
TOU-PA-3-S <20kW Winter Generation On-Peak 0.17606 0.18911 -6.90% TOU-PA-3-S <20kW Winter Generation Off-Peak 0.07484 0.08039 -6.90% TOU-PA-3-S <20kW Winter Generation
Super Off-Peak 0.04543 0.04880 -6.90%
TOU-PA-3-P <20kW Summer Generation On-Peak 0.38731 0.41601 -6.90% TOU-PA-3-P <20kW Summer Generation Off-Peak 0.19001 0.20409 -6.90% TOU-PA-3-P <20kW Summer Generation
Super Off-Peak 0.06821 0.07326 -6.90%
TOU-PA-3-P <20kW Winter Generation On-Peak 0.17502 0.18799 -6.90% TOU-PA-3-P <20kW Winter Generation Off-Peak 0.07430 0.07981 -6.90% TOU-PA-3-P <20kW Winter Generation
Super Off-Peak 0.04510 0.04844 -6.90%
TOU-PA-3-S >=20kW Summer Demand On-Peak 5.60 6.01 -6.90% TOU-PA-3-S >=20kW Summer Generation On-Peak 0.39697 0.42639 -6.90% TOU-PA-3-S >=20kW Summer Generation Off-Peak 0.20054 0.21540 -6.90% TOU-PA-3-S >=20kW Summer Generation
Super Off-Peak 0.05795 0.06224 -6.90%
TOU-PA-3-S >=20kW Winter Generation On-Peak 0.16559 0.17786 -6.90% TOU-PA-3-S >=20kW Winter Generation Off-Peak 0.06899 0.07410 -6.90% TOU-PA-3-S >=20kW Winter Generation
Super Off-Peak 0.04090 0.04393 -6.90%
TOU-PA-3-P >=20kW Summer Demand On-Peak 5.57 5.98 -6.90% TOU-PA-3-P >=20kW Summer Generation On-Peak 0.39509 0.42437 -6.90% TOU-PA-3-P >=20kW Summer Generation Off-Peak 0.19956 0.21435 -6.90% TOU-PA-3-P >=20kW Summer Generation
Super Off-Peak 0.05746 0.06172 -6.90%
TOU-PA-3-P >=20kW Winter Generation On-Peak 0.16453 0.17672 -6.90% TOU-PA-3-P >=20kW Winter Generation Off-Peak 0.06837 0.07344 -6.90% TOU-PA-3-P >=20kW Winter Generation
Super Off-Peak 0.04044 0.04344 -6.90%
PA-T-1-S Summer Demand On-Peak 10.12 10.87 -6.90%
PA-T-1-S Summer Generation On-Peak 0.19774 0.21240 -6.90% PA-T-1-S Summer Generation Off-Peak 0.11149 0.11975 -6.90% PA-T-1-S Summer Generation
Super Off-Peak 0.06967 0.07483 -6.90%
PA-T-1-S Winter Generation On-Peak 0.24588 0.26410 -6.90% PA-T-1-S Winter Generation Off-Peak 0.11401 0.12246 -6.90% PA-T-1-S Winter Generation
Super Off-Peak 0.07569 0.08130 -6.90%
PA-T-1-P Summer Demand On-Peak 10.07 10.82 -6.90%
PA-T-1-P Summer Generation On-Peak 0.19658 0.21115 -6.90% PA-T-1-P Summer Generation Off-Peak 0.11077 0.11898 -6.90% PA-T-1-P Summer Generation
Super Off-Peak 0.06929 0.07443 -6.90%
PA-T-1-P Winter Generation On-Peak 0.24449 0.26261 -6.90% PA-T-1-P Winter Generation Off-Peak 0.11332 0.12172 -6.90% PA-T-1-P Winter Generation
Super Off-Peak 0.07526 0.08084 -6.90%
PA-T-1-T Summer Demand On-Peak 9.65 10.36 -6.90%
PA-T-1-T Summer Generation On-Peak 0.18627 0.20008 -6.90% PA-T-1-T Summer Generation Off-Peak 0.10424 0.11197 -6.90% PA-T-1-T Summer Generation
Super Off-Peak 0.06476 0.06956 -6.90%
PA-T-1-T Winter Generation On-Peak 0.23188 0.24907 -6.90% PA-T-1-T Winter Generation Off-Peak 0.10642 0.11431 -6.90% PA-T-1-T Winter Generation
Super Off-Peak 0.07003 0.07522 -6.90%
G-PA-T-1-S Summer Demand On-Peak 2.83 3.04 -6.90%
G-PA-T-1-S Summer Generation On-Peak 0.09980 0.10720 -6.90% G-PA-T-1-S Summer Generation Semi-Peak 0.09751 0.10474 -6.90% G-PA-T-1-S Summer Generation Off-Peak 0.05806 0.06236 -6.90% G-PA-T-1-S Winter Generation On-Peak 0.32172 0.34556 -6.90% G-PA-T-1-S Winter Generation Semi-Peak 0.12199 0.13103 -6.90% G-PA-T-1-S Winter Generation Off-Peak 0.12187 0.13090 -6.90% G-PA-T-1-P Summer Demand On-Peak 2.80 3.01 -6.90%
G-PA-T-1-P Summer Generation On-Peak 0.09351 0.10044 -6.90% G-PA-T-1-P Summer Generation Semi-Peak 0.09125 0.09801 -6.90% G-PA-T-1-P Summer Generation Off-Peak 0.05199 0.05584 -6.90% G-PA-T-1-P Winter Generation On-Peak 0.31989 0.34360 -6.90% G-PA-T-1-P Winter Generation Semi-Peak 0.12122 0.13020 -6.90% G-PA-T-1-P Winter Generation Off-Peak 0.12110 0.13007 -6.90% G-PA-T-1-T Summer Demand On-Peak 2.69 2.89 -6.90%
G-PA-T-1-T Summer Generation On-Peak 0.09276 0.09964 -6.90% G-PA-T-1-T Summer Generation Semi-Peak 0.09067 0.09739 -6.90% G-PA-T-1-T Summer Generation Off-Peak 0.05307 0.05700 -6.90% G-PA-T-1-T Winter Generation On-Peak 0.31774 0.34129 -6.90% G-PA-T-1-T Winter Generation Semi-Peak 0.12027 0.12918 -6.90% G-PA-T-1-T Winter Generation Off-Peak 0.12015 0.12905 -6.90% G-TOU-PA-S Summer Generation On-Peak 0.37659 0.40450 -6.90% G-TOU-PA-S Summer Generation Semi-Peak 0.14527 0.15604 -6.90% G-TOU-PA-S Summer Generation Off-Peak 0.06545 0.07030 -6.90% G-TOU-PA-S Winter Generation On-Peak 0.17912 0.19240 -6.90% G-TOU-PA-S Winter Generation Semi-Peak 0.05510 0.05918 -6.90% G-TOU-PA-S Winter Generation Off-Peak 0.05501 0.05909 -6.90% G-TOU-PA-P Summer Generation On-Peak 0.37439 0.40214 -6.90% G-TOU-PA-P Summer Generation Semi-Peak 0.14429 0.15498 -6.90% G-TOU-PA-P Summer Generation Off-Peak 0.06488 0.06969 -6.90% G-TOU-PA-P Winter Generation On-Peak 0.17790 0.19109 -6.90% G-TOU-PA-P Winter Generation Semi-Peak 0.05452 0.05856 -6.90% G-TOU-PA-P Winter Generation Off-Peak 0.05444 0.05848 -6.90% G-TOU-PA-2-S Summer Demand On-Peak 3.16 3.39 -6.90%
G-TOU-PA-2-S Summer Generation On-Peak 0.11476 0.12327 -6.90% G-TOU-PA-2-S Summer Generation Semi-Peak 0.10385 0.11155 -6.90% G-TOU-PA-2-S Summer Generation Off-Peak 0.06283 0.06749 -6.90% G-TOU-PA-2-S Winter Generation On-Peak 0.35230 0.37841 -6.90% G-TOU-PA-2-S Winter Generation Semi-Peak 0.13628 0.14638 -6.90% G-TOU-PA-2-S Winter Generation Off-Peak 0.13620 0.14629 -6.90% G-TOU-PA-2-P Summer Demand On-Peak 3.15 3.38 -6.90%
G-TOU-PA-2-P Summer Generation On-Peak 0.11419 0.12265 -6.90% G-TOU-PA-2-P Summer Generation Semi-Peak 0.10329 0.11094 -6.90% G-TOU-PA-2-P Summer Generation Off-Peak 0.06244 0.06707 -6.90% G-TOU-PA-2-P Winter Generation On-Peak 0.35034 0.37631 -6.90% G-TOU-PA-2-P Winter Generation Semi-Peak 0.13545 0.14549 -6.90% G-TOU-PA-2-P Winter Generation Off-Peak 0.13536 0.14539 -6.90%