On-Peak: 5:00 p.m. to 8:00 p.m. summer weekdays except holidays Mid-Peak: 5:00 p.m. to 8:00 p.m. winter weekdays and summer and winter weekends/holidays Off-Peak: 8:00 p.m. to 5:00 p.m. summer weekdays and weekends. 8:00 p.m. to 8:00 a.m. winter weekdays Super Off-Peak: 8:00 a.m. to 5:00 p.m. winter weekdays and weekends/holidays TOU-D-A and TOU-D-B:
On-Peak: 2:00 p.m. to 8:00 p.m. summer and winter weekdays except holidays Default 100% Green - CARE rates are the rates paid by CARE, FERA and Medical Baseline customers for 100% Green Power in communities where 100% Green Power is the preferred (default) energy product.
TOU-D-4 and TOU-D-PRIME:
Tier 1: Baseline Service
Tier 2: 100% to 400% of Baseline Service
High Usage: 400% of Baseline Servce
For TOU-D rate schedules the following definitions from SCE Schedule TOU-D (Time-of-Use Domestic) apply:
Summer: season shall commence at 12:00 a.m. on June 1 and continue until 12:00 a.m. on October 1 of each year.
Energy rates are shown in $/kWh and demand rates are shown in $/kW.
Agenda Page 269
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
DOMESTIC-C-PS Energy All_Year Generation - 2025 Vintage None $ 0.14138 DOMESTIC-C-PS Energy All_Year Power Share Credit - Tier 1 - 2025 Vintage None $ (0.04075) DOMESTIC-C-PS Energy All_Year Power Share Credit - Tier 2 - 2025 Vintage None $ (0.05323) DOMESTIC-C-PS Energy All_Year Power Share Credit - High Usage - 2025 Vintage None $ (0.05323) DOMESTIC-F-PS Energy All_Year Generation - 2025 Vintage None $ 0.14138 DOMESTIC-F-PS Energy All_Year Power Share Credit - Tier 1 - 2025 Vintage None $ (0.05290) DOMESTIC-F-PS Energy All_Year Power Share Credit - Tier 2 - 2025 Vintage None $ (0.06807) DOMESTIC-F-PS Energy All_Year Power Share Credit - High Usage - 2025 Vintage None $ (0.06807) DOMESTIC-PS Energy All_Year Generation - 2025 Vintage None $ 0.14138 DOMESTIC-PS Energy All_Year Power Share Credit - Tier 1 - 2025 Vintage None $ (0.06456) DOMESTIC-PS Energy All_Year Power Share Credit - Tier 2 - 2025 Vintage None $ (0.08306) DOMESTIC-PS Energy All_Year Power Share Credit - High Usage - 2025 Vintage None $ (0.08306) TOU-D-4-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.26850 TOU-D-4-C-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.15947 TOU-D-4-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.10132 TOU-D-4-C-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.20046 TOU-D-4-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12638 TOU-D-4-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10861 TOU-D-4-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.06309) TOU-D-4-C-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.04844) TOU-D-4-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.03392) TOU-D-4-C-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.05395) TOU-D-4-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.03729) TOU-D-4-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03248) TOU-D-4-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.26850 TOU-D-4-F-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.15947 TOU-D-4-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.10132 TOU-D-4-F-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.20046 TOU-D-4-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12638 TOU-D-4-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10861 TOU-D-4-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.08010) TOU-D-4-F-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.06226) TOU-D-4-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.04459) TOU-D-4-F-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.06896) TOU-D-4-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04869) TOU-D-4-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.04285) TOU-D-4-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.26850 TOU-D-4-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.15947 TOU-D-4-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.10132 TOU-D-4-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.20046 TOU-D-4-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12638 TOU-D-4-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10861 TOU-D-4-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.09778) TOU-D-4-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.07597) TOU-D-4-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05440) TOU-D-4-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.08417) TOU-D-4-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.05942) TOU-D-4-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.05229) TOU-D-5-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.40754 TOU-D-5-C-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.22569 TOU-D-5-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09232 TOU-D-5-C-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.28301 Energy rates are shown in $/kWh.
Agenda Page 270
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
TOU-D-5-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12483 TOU-D-5-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.09894 TOU-D-5-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.08249) TOU-D-5-C-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.05805) TOU-D-5-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.03374) TOU-D-5-C-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.06575) TOU-D-5-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.03811) TOU-D-5-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03118) TOU-D-5-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.40754 TOU-D-5-F-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.22569 TOU-D-5-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09232 TOU-D-5-F-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.28301 TOU-D-5-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12483 TOU-D-5-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.09894 TOU-D-5-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.10371) TOU-D-5-F-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.07395) TOU-D-5-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.04437) TOU-D-5-F-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.08333) TOU-D-5-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04969) TOU-D-5-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.04126) TOU-D-5-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.40754 TOU-D-5-PS Energy Summer Generation - 2025 Vintage Mid-peak $ 0.22569 TOU-D-5-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09232 TOU-D-5-PS Energy Winter Generation - 2025 Vintage Mid-peak $ 0.28301 TOU-D-5-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.12483 TOU-D-5-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.09894 TOU-D-5-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.12663) TOU-D-5-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.09026) TOU-D-5-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05414) TOU-D-5-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.10173) TOU-D-5-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.06064) TOU-D-5-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.05034) TOU-D-PRIME-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-C-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09771 TOU-D-PRIME-C-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.08738 TOU-D-PRIME-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.08738 TOU-D-PRIME-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.07259) TOU-D-PRIME-C-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.04831) TOU-D-PRIME-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.03243) TOU-D-PRIME-C-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.06857) TOU-D-PRIME-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.02998) TOU-D-PRIME-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02998) TOU-D-PRIME-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-F-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09771 TOU-D-PRIME-F-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.08738 TOU-D-PRIME-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.08738 TOU-D-PRIME-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.09166) TOU-D-PRIME-F-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.06208) Energy rates are shown in $/kWh.
Agenda Page 271
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
TOU-D-PRIME-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.04278) TOU-D-PRIME-F-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.08676) TOU-D-PRIME-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.03980) TOU-D-PRIME-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03980) TOU-D-PRIME-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.09771 TOU-D-PRIME-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.08738 TOU-D-PRIME-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.08738 TOU-D-PRIME-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.11189) TOU-D-PRIME-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.07575) TOU-D-PRIME-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05220) TOU-D-PRIME-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.10590) TOU-D-PRIME-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04855) TOU-D-PRIME-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.04855) TOU-D-PRIME-SOP-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-SOP-C-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-SOP-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.12460 TOU-D-PRIME-SOP-C-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06230 TOU-D-PRIME-SOP-C-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-SOP-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.10846 TOU-D-PRIME-SOP-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.05423 TOU-D-PRIME-SOP-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.07259) TOU-D-PRIME-SOP-C-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.04831) TOU-D-PRIME-SOP-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.03781) TOU-D-PRIME-SOP-C-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02535) TOU-D-PRIME-SOP-C-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.06857) TOU-D-PRIME-SOP-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.03419) TOU-D-PRIME-SOP-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02335) TOU-D-PRIME-SOP-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-SOP-F-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-SOP-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.12460 TOU-D-PRIME-SOP-F-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06230 TOU-D-PRIME-SOP-F-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-SOP-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.10846 TOU-D-PRIME-SOP-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.05423 TOU-D-PRIME-SOP-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.09166) TOU-D-PRIME-SOP-F-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.06208) TOU-D-PRIME-SOP-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.04816) TOU-D-PRIME-SOP-F-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03570) TOU-D-PRIME-SOP-F-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.08676) TOU-D-PRIME-SOP-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04401) TOU-D-PRIME-SOP-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03317) TOU-D-PRIME-SOP-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.31160 TOU-D-PRIME-SOP-PS Energy Summer Generation - 2025 Vintage Mid-Peak $ 0.13089 TOU-D-PRIME-SOP-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.12460 TOU-D-PRIME-SOP-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06230 TOU-D-PRIME-SOP-PS Energy Winter Generation - 2025 Vintage Mid-Peak $ 0.27635 TOU-D-PRIME-SOP-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.10846 TOU-D-PRIME-SOP-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.05423 TOU-D-PRIME-SOP-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.11189) Energy rates are shown in $/kWh.
Agenda Page 272
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
TOU-D-PRIME-SOP-PS Energy Summer Power Share Credit - 2025 Vintage Mid-peak $ (0.07575) TOU-D-PRIME-SOP-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05758) TOU-D-PRIME-SOP-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.04512) TOU-D-PRIME-SOP-PS Energy Winter Power Share Credit - 2025 Vintage Mid-peak $ (0.10590) TOU-D-PRIME-SOP-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.05277) TOU-D-PRIME-SOP-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.04192) TOU-D-A-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.28603 TOU-D-A-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13755 TOU-D-A-C-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.10607 TOU-D-A-C-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.18251 TOU-D-A-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11215 TOU-D-A-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10780 TOU-D-A-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.09314) TOU-D-A-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05519) TOU-D-A-C-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01169) TOU-D-A-C-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.05382) TOU-D-A-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04248) TOU-D-A-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01135) TOU-D-A-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.28603 TOU-D-A-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13755 TOU-D-A-F-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.10607 TOU-D-A-F-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.18251 TOU-D-A-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11215 TOU-D-A-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10780 TOU-D-A-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.11661) TOU-D-A-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.07044) TOU-D-A-F-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01759) TOU-D-A-F-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.06879) TOU-D-A-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.05500) TOU-D-A-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01717) TOU-D-A-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.28603 TOU-D-A-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13755 TOU-D-A-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.10607 TOU-D-A-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.18251 TOU-D-A-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11215 TOU-D-A-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.10780 TOU-D-A-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.14231) TOU-D-A-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.08595) TOU-D-A-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02148) TOU-D-A-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.08396) TOU-D-A-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.06711) TOU-D-A-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02097) TOU-D-B-C-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.41338 TOU-D-B-C-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13751 TOU-D-B-C-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06974 TOU-D-B-C-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.17709 TOU-D-B-C-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11216 TOU-D-B-C-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.07063 TOU-D-B-C-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.08639) TOU-D-B-C-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.03920) TOU-D-B-C-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01894) TOU-D-B-C-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.05464) Energy rates are shown in $/kWh.
Agenda Page 273
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
TOU-D-B-C-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.03579) TOU-D-B-C-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.01906) TOU-D-B-F-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.41338 TOU-D-B-F-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13751 TOU-D-B-F-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06974 TOU-D-B-F-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.17709 TOU-D-B-F-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11216 TOU-D-B-F-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.07063 TOU-D-B-F-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.10846) TOU-D-B-F-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.05101) TOU-D-B-F-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02638) TOU-D-B-F-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.06979) TOU-D-B-F-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.04687) TOU-D-B-F-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.02652) TOU-D-B-PS Energy Summer Generation - 2025 Vintage On-Peak $ 0.41338 TOU-D-B-PS Energy Summer Generation - 2025 Vintage Off-Peak $ 0.13751 TOU-D-B-PS Energy Summer Generation - 2025 Vintage Super Off-Peak $ 0.06974 TOU-D-B-PS Energy Winter Generation - 2025 Vintage On-Peak $ 0.17709 TOU-D-B-PS Energy Winter Generation - 2025 Vintage Off-Peak $ 0.11216 TOU-D-B-PS Energy Winter Generation - 2025 Vintage Super Off-Peak $ 0.07063 TOU-D-B-PS Energy Summer Power Share Credit - 2025 Vintage On-Peak $ (0.13243) TOU-D-B-PS Energy Summer Power Share Credit - 2025 Vintage Off-Peak $ (0.06226) TOU-D-B-PS Energy Summer Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03218) TOU-D-B-PS Energy Winter Power Share Credit - 2025 Vintage On-Peak $ (0.08517) TOU-D-B-PS Energy Winter Power Share Credit - 2025 Vintage Off-Peak $ (0.05719) TOU-D-B-PS Energy Winter Power Share Credit - 2025 Vintage Super Off-Peak $ (0.03236) Energy rates are shown in $/kWh.
Agenda Page 274
Exhibit B to Resolution 25-06-088
Phase 7 Power Share Rates Effective July 1, 2025
CPA RATE TYPE SEASON CHARGE TYPE TOU PERIOD RATE
Notes
For all rate schedules, seasons are defined as follows:
For Domestic, D-CARE and D-FERA rates the following definitions from SCE Schedule D (Domestic Service) apply:
C refers CARE-discounted rates and F refers to FERA-discounted rates as defined in SCE Schedule TOU-D.
Super Off-Peak: 8:00 a.m. to 4:00 p.m. all year, every day Super Off-Peak: 10:00 p.m. to 8:00 a.m. all year, every day Off-Peak: All other hours – all year, every day
For TOU-D-PRIME-SOP, the following definitions apply:
On-Peak: 4:00 p.m. to 9:00 p.m. summer weekdays except holidays Mid-Peak: 4:00 p.m. to 9:00 p.m. winter weekdays and summer and winter weekends/holidays Off-Peak: 9:00 p.m. to 8:00 a.m. all year, every day
On-Peak: 2:00 p.m. to 8:00 p.m. summer and winter weekdays except holidays TOU-D-4 and TOU-D-PRIME:
On-Peak: 4:00 p.m. to 9:00 p.m. summer weekdays except holidays Mid-Peak: 4:00 p.m. to 9:00 p.m. winter weekdays and summer and winter weekends/holidays Off-Peak: 9:00 p.m. to 4:00 p.m. summer weekdays and weekends. 9:00 p.m. to 8:00 a.m. winter weekdays and weekends/holidays Super Off-Peak: 8:00 a.m. to 4:00 p.m. winter weekdays and weekends/holidays TOU-D-5:
On-Peak: 5:00 p.m. to 8:00 p.m. summer weekdays except holidays Mid-Peak: 5:00 p.m. to 8:00 p.m. winter weekdays and summer and winter weekends/holidays Off-Peak: 8:00 p.m. to 5:00 p.m. summer weekdays and weekends. 8:00 p.m. to 8:00 a.m. winter weekdays and weekends/holidays Super Off-Peak: 8:00 a.m. to 5:00 p.m. winter weekdays and weekends/holidays TOU-D-A and TOU-D-B:
For TOU-D rate schedules the following definitions from SCE Schedule TOU-D (Time-of-Use Domestic) apply:
Summer: season shall commence at 12:00 a.m. on June 1 and continue until 12:00 a.m. on October 1 of each year.
Winter: season shall commence at 12:00 a.m. on October 1 of each year and continue until 12:00 a.m. on June 1 of the following year.
Tier 1: Baseline Service
Tier 2: 100% to 400% of Baseline Service
High Usage: 400% of Baseline Servce
Energy rates are shown in $/kWh.
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RESO NO. 25-06-089
RESOLUTION NO. 25-06-089
A RESOLUTION OF THE BOARD OF DIRECTORS OF THE
CLEAN POWER ALLIANCE OF SOUTHERN CALIFORNIA
TO APPROVE AN AMENDMENT TO PEAK MANAGEMENT
PRICING TARIFF
THE BOARD OF DIRECTORS OF THE CLEAN POWER ALLIANCE OF SOUTHERN CALIFORNIA DOES HEREBY FIND, RESOLVE, AND ORDER AS FOLLOWS:
WHEREAS, the Clean Power Alliance of Southern California (formerly known as Los Angeles Community Choice Energy Authority) (“Clean Power Alliance” or “CPA”) was formed on June 27, 2017;
WHEREAS, on June 6, 2019, the Board authorized rates for the implementation of event-based Peak Management Pricing demand response rate options for eligible non-residential customers, similar to the Southern California Edison (SCE) Critical Peak Pricing program for bundled SCE customers;
WHEREAS, on December 5, 2024, after considering the staff report and the record related to the Peak Management Pricing Tariff at a duly-noticed public meeting, the Board, through adoption of Resolution 24-12-077, approved a Peak Management Pricing Tariff to expand availability of the Peak Management Pricing program to include eligible residential customers as well as other adjustments to the program’s terms and conditions; and
WHEREAS, CPA staff has proposed amending the Peak Management Pricing Tariff to clarify the definition of certain terms and rate eligibility for enrollment in the program.
NOW THEREFORE, BE IT DETERMINED, ORDERED, AND RESOLVED, BY
THE BOARD OF DIRECTORS OF THE CLEAN POWER ALLIANCE OF SOUTHERN CALIFORNIA THAT:
1. The Amended Peak Management Pricing Tariff as presented in Exhibit A, attached hereto and incorporated herein, is hereby approved effective July 1, 2025.
2. The Peak Management Pricing Tariff or this amendment is not subject to the California Environmental Quality Act (“CEQA”) and, therefore, an environmental review is not required pursuant to Section 21080(b)(8) of the California Public Resources Code and Sections 15273(a) and 15061(b)(3) of the CEQA Guidelines, California Code of Regulations, Title 14, Chapter 3 because CEQA does not apply to the establishment, modification, restructuring, or approval of tariffs or charges established by public agencies for purposes such as those set forth herein.
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RESO NO. 25-06-089
APPROVED AND ADOPTED this 5th day of June 2025.
Deborah Klein Lopez, Chair
ATTEST:
Gabriela Monzon, Board Secretary
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CPA Amended PMP Tariff Adopted December 5, 2024June 5, 2025 - Effective January July 1, 2025Page 1 of 4
Peak Management Pricing (PMP) Tariff
Clean Power Alliance’s Peak Management Pricing (“PMP”) Tariff (“PMP Tariff” or “PMP program”) is an event-based rate option that provides bill credits to participating customers in the summer during on-peak non-event hours, and incremental bill charges for on-peak electricity usage during PMP events.
A. APPLICABILITY
The PMP Tariff is available to CPA residential and non-residential customers who meet the eligibility criteria detailed in the Terms and Conditions below. To participate in the PMP program eligible customers must submit a completed PMP Enrollment Form1.
B. RATES, CREDITS, AND SURCHARGES
Accounts enrolled in the PMP program will continue to be billed in accordance with the account’s otherwise applicable CPA and SCE tariffs, rates, and policies (“OAT”).
Participating customers will receive bill credits from CPA during the summer months (June-September) in the form of monthly on-peak energy credits for accounts on non-demand rates (residential and small business customers), or monthly on-peak demand credits for accounts on demand rates (most commercial, agriculture and pumping, and industrial customers). During PMP events, participating customers will be billed an incremental surcharge on energy consumed from 4 p.m. to 9 p.m. See Terms and Conditions for details on how the summer credits and event surcharges are calculated and applied.
CPA will call no more than fifteen (15) PMP events per calendar year, which will be limited to non-holiday weekdays. These events typically occur on the hottest days of the summer when electricity prices are high. Customers will be notified via email or text at least 24 hours in advance of an event so that they can prepare to reduce their energy use between 4 p.m. and 9 p.m. on the following day. Events may occur on consecutive days but will not exceed three per week except in the event of a Grid Emergency as defined in the Terms and Conditions.
B. TERMS AND CONDITIONS
1. Customer eligibility. The PMP Tariff is available to customers with accounts that meet the following criteria:
a. Eligible residential accounts must be actively receiving service from CPA and on a TOU-D-4, TOU-D-5, TOU-D-PRIME, TOU-D-PRIME-SOP, TOU-D-A, TOU-D-B, or TOU-D-T rate schedule2;
b. Eligible non-residential accounts must be actively receiving service from CPA on a TOU-GS-1-E, TOU-GS-1-ES, TOU-GS-2-D, TOU-GS-3-D, TOU-8-D, TOU-PA-2-D, or TOU-PA-3-D rate schedule; c. Eligible accounts must have an interval meter or a Southern California Edison (SCE) SmartConnect meter installed and in use;
d. Eligible accounts may not be enrolled in the CPA Power Response program or other CPA, SCE, or third-party demand response programs. 1 The PMP Enrollment Form is available at www.cleanpoweralliance.org\pmp-program. 2 Includes accounts on CARE, FERA, Medical Baseline, and/or Power Share versions of these rate schedules.
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CPA Amended PMP Tariff Adopted December 5, 2024June 5, 2025 - Effective January July 1, 2025Page 2 of 4
2. Ineligible rates, tariffs, or programs. Accounts enrolled in the following rates, tariffs, or programs are not eligible to enroll in the PMP Tariff:
a. Residential accounts on Domestic (tiered), D-CARE, DM or DMS rate schedules; b. Non-residential accounts on TOU-1-GS-D, lighting, traffic control, WTR, or other non-residential rate schedules not listed in section B.1.b.; c. Accounts not served by an interval or SCE SmartConnect meter; and d. Accounts enrolled in the CPA Power Response program or other CPA, SCE, or third-party demand response programs.
3. Customer enrollment and term. To participate in the PMP Program the customer or an authorized representative must submit a completed PMP Enrollment Form5 requesting enrollment of the designated account(s) in the program and agreeing to the PMP Tariff’s Terms and Conditions. Participation in the PMP Program for enrolled service accounts will commence within two billing periods after enrollment in the PMP Program is confirmed.
Customers may disenroll in the program at any time by calling or emailing CPA Customer Service. If a customer switches their account to a different rate schedule, the account’s enrollment in PMP will be maintained provided that the new rate schedule meets PMP eligibility requirements. If CPA discontinues the PMP Program for any reason, participating customers will be notified and the account(s) will be returned to CPA’s OAT.
4. PMP Events. CPA may, at its discretion, call a PMP Event any non-holiday weekday.
Events will only occur from 4 p.m. to 9 p.m. A maximum of fifteen (15) PMP events may be called during a calendar year. Events may occur on consecutive days but will not exceed three per week except in the case of a Grid Emergency as defined below. PMP Events will be called based on any one of the following criteria:
1) California Independent System Operator (CAISO) Energy Emergency Alert (EEA) Watch Notice,
2) California Independent System Operator (CAISO) Flex Alert, 3) Forecasts of extreme or unusual temperature conditions impacting system demand, or
4) Day-ahead load and/or price forecasts.
A Grid Emergency occurs when the California Independent System Operator (“CAISO”) (a) declares an Energy Emergency Alert (EEA) 2 or greater; (b) when CAISO declares an event threatening or limiting transmission grid capability including line or transformer overloads; (c) when a state of emergency related to a sudden and severe energy shortage is declared pursuant to California Government Code section 8565, et seq.; or (d) other event or action that can result in a sudden and severe energy shortage to California’s electricity grid.
5. PMP Event Notification. CPA will provide event notifications to participating customers via email or text message, as designated by the customer in the customer’s enrollment form, no later than 4 p.m. the business day before a PMP event. Customers are responsible for monitoring event notifications and providing CPA with correct email addresses or phone numbers to receive text notifications (carrier fees may apply).
Updates to the event notification contact(s) must be provided by emailing 5 Available at www.cleanpoweralliance.org\pmp-program.
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CPA Amended PMP Tariff Adopted December 5, 2024June 5, 2025 - Effective January July 1, 2025Page 3 of 4
[email protected] or calling Customer Service at 888-585-3788 (TTY: 323-214-1296).
6. PMP Summer Credits and Event Surcharges. PMP summer credit rates and event surcharge rates effective January July 1, 2025, are shown in the table below. Summer credit rates are applied during the summer season (June 1 to September 30) to energy usage from 4 p.m. to 9 p.m. on all non-event, non-holiday weekdays for customers on non-demand rates, and to maximum monthly on-peak demand from 4 p.m. to 9 p.m. on non-event, non-holiday weekdays for customers on demand rates. Event surcharge rates are applied to energy consumed from 4 p.m. to 9 p.m. during PMP events. PMP credits and surcharges will not be applied to exported generation.
All CPA rates including PMP rates are adopted by the CPA Board of Directors at duly noticed public meetings of the Clean Power Alliance Board of Directors and are subject to change.7 Current PMP rates are posted at www.cleanpoweralliance.org\pmp-program.
Peak Management Pricing (PMP) Rates*
Rate Schedule Event Surcharge Summer Incentive
Credit
Residential Rates**
TOU-D-4, TOU-D-5, TOU-D-PRIME, TOU-D-PRIME-SOP, TOU-D-A, TOU-D-B, TOU-D-T $1.00/kWh $0.18963/kWh Non-residential Rates
TOU-GS-1-E, TOU-GS-1-ES $1.00/kWh $0.17054/kWh
TOU-GS-2-D $1.00/kWh $8.56/kW
TOU-GS-3-D $1.00/kWh $9.44/kW
TOU-8-SEC-D
TOU-8-PRI-D
TOU-8-SUB-D
$1.00/kWh
$10.28/kW
$10.65/kW
$10.55/kW
TOU-PA-2-D, TOU-PA-2-D5 $1.00/kWh $7.10/kW
TOU-PA-3-D, TOU-PA-3-D5 $1.00/kWh $7.73/kW
* Summer credits are applied to energy usage in kWh from 4 p.m. - 9 p.m. on non-event non-holiday weekdays from June 1 to September 30 for all residential rates and for TOU-GS-1 and TOU-GS-1-ES rates, and to maximum monthly on-peak demand in kW from 4 p.m. to 9 p.m. on non-event non-holiday weekdays from June 1 to September 30 for all other non-residential rates. Event surcharges are applied to all energy usage from 4 p.m. - 9 p.m. during PMP events. Effective January 1, 2025. Rates subject to change. See www.cleanpoweralliance.org\pmp-program for current rates. ** Includes accounts on CARE, FERA, Medical Baseline, and/or Power Share versions of these rate schedules.
7. Billing. Participating accounts will be billed monthly at their normal CPA OAT. Applicable PMP summer credits and event surcharges will appear as separate line items on the account’s monthly invoices. Credits will be applied only to on-peak usage during the summer season (June 1 – September 30). All applicable CPA generation charges and event surcharges must be paid as billed.
7 Board agendas are available at: https://cleanpoweralliance.org/get-involved/agendas-minutes/.
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CPA Amended PMP Tariff Adopted December 5, 2024June 5, 2025 - Effective January July 1, 2025Page 4 of 4
8. Bill Protection. Customers enrolled in PMP will receive a one-time Bill Protection credit if the customer was billed an amount greater than they would have been billed under their CPA OAT without PMP, for up to the first 12 months of enrollment in the PMP program. If a customer disenrolls from the PMP program or terminates CPA service for any reason before the end of their first 12 months in the program, or if CPA terminates the PMP program for any reason, Bill Protection will end on the account’s next regularly scheduled billing date.
CPA will calculate the Bill Protection credit after the earlier of 1) the end of the first 12 months of the account’s enrollment in the program; 2) the end of the account’s enrollment in the program; or 3) the termination of CPA service to the account. The Bill Protection credit will equal the positive sum, if any, of total PMP event surcharges and the total PMP summer credits bill over the duration of the Bill Protection period. If customers are eligible for a PMP Bill Protection credit, this credit will be applied within two billing periods following the end of the Bill Protection period.
9. Reservation of Rights. CPA reserves the right to modify, suspend, or terminate, one or more components of or all of the PMP Tariff at a duly noticed public meeting of CPA’s Board of Directors. By enrolling or remaining enrolled in the PMP Tariff, the customer acknowledges and accepts CPA’s reservation of rights.
10. LIMITATION OF LIABILITY. FOR ANY ACT OR OMISSION IN THE PERFORMANCE
OF THIS TARIFF, THE SOLE AND EXCLUSIVE REMEDY SHALL BE THE AMOUNT OF DIRECT DAMAGE ACTUALLY INCURRED. IN NO EVENT SHALL ANY PARTY
SUBJECT TO THIS TARIFFF BE LIABLE FOR ANY INDIRECT, SPECIAL,
CONSEQUENTIAL, PUNITIVE OR EXEMPLARY DAMAGES, INCLUDING LOST PROFITS, BUSINESS INTERRUPTION DAMAGES, OR TO ATTORNEY’S FEES WHETHER IN CONTRACT, TORT, OR STRICT LIABILITY.
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Staff Report – Agenda Item 12
To: Board of Directors
From: Jennifer Stevenson, Financial Planning and Analysis Manager Reviewed by: David McNeil, Chief Financial Officer
Approved By: Ted Bardacke, Chief Executive Officer
Subject: Proposed Fiscal Year 2025/2026 Budget
Date: June 5, 2025
RECOMMENDATION
Approve the Proposed Fiscal Year (FY) 2025/26 Budget (Attachment 2), as recommended by the Finance Committee.
BACKGROUND
Each year CPA develops an annual budget to govern the receipt of revenues, the incurrence of expenses, and capital expenditures made during the upcoming fiscal year.
The Proposed FY 2025/26 Budget is provided in Attachment 2.
The Proposed FY 2025/26 Budget incorporates the budget priorities presented to, and rate-setting approach approved by, the Board at its May 1, 2025, meeting.
SUMMARY
The FY 2025/26 Proposed Budget reflects lower energy costs, a lower contribution to Reserves, and higher interest income, while providing room for higher operating expenses. These key elements were considered in the rate setting approach approved by the Board in May and enable CPA to reduce revenue through lower rates, while
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Board of Directors Item 12
covering costs and achieving the target Reserve balance and liquidity goals outlined in the Reserve Policy.
Other key takeaways:
• Lower energy costs are driven by lower energy market prices and lower-cost long-term power purchase and energy storage agreements which in many instances are replacing higher cost, short-term contracts.
• Higher operating expenses primarily reflect investments in staffing, customer programs, and marketing and communications.
• Higher interest income results from higher investable assets which are managed in accordance with CPA’s Board-approved Investment Policy. • The projected increase in net position is expected to bring CPA’s Reserve percentage to 50% by June 30, 2026 with a days liquidity on hand level of 189 days, consistent with CPA’s Board approved Reserve Policy, and well prepared to respond to market, policy, regulatory, and competitiveness volatility in the future.
DISCUSSION
The Proposed Budget sets forth changes to the following budget line items:
Revenue – electricity net (-$262,613,000; 17% decrease): Budgeted electricity revenues are based on estimates of customer electricity usage and the cost of service to procure generation for customers. Budgeted revenues reflect a year-over-year increase in budgeted load of 0.1%; increases in load from new community enrollments and increased customer electrification is offset by decreases from customer solar additions and refinements in CPA’s load forecast modeling. Budgeted revenues include an allowance for bad debt equal to 2.0% of revenues or $26.9 million. Revenues are budgeted to be lower than the prior year’s budget, reflecting the rate approach approved by the Board on May 1, 2025, which extends and amplifies the interim rate decrease implemented on March 1, 2025.
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Board of Directors Item 12
Other revenue (+$1,575,000; 54% increase): Other revenue includes operating revenue from sources other than retail electricity sales. Other revenue includes funding from the California Public Utilities Commission (CPUC) to support the Power Share program and a projection for funding through the Southern California Equitable Building Decarbonization grant. Other Revenue partially offsets the increase in expenses budgeted this FY in the Customer Programs, Staffing, Mailers, and Communications budget line items.
Cost of energy (-$185,851,000; 13% decrease): Cost of energy includes expenses associated with the purchase of system energy, renewable energy, Resource Adequacy, and charges by the California Independent System Operator (CAISO) for load and services performed by the CAISO. CAISO charges for load are based on electricity consumed by CPA customers and related line losses and prices at the Default Load Aggregation Point (DLAP). Credits for energy generation scheduled into the CAISO market and revenues arising from Congestion Revenue Rights (CRRs) are netted from the cost of energy. CRRs are financial instruments created by the CAISO which enable load serving entities, such as CPA, to manage price differences between wholesale energy delivery locations and retail use points. CAISO credits for energy generation are based on wholesale energy deliveries and Locational Margin Prices (LMPs). The budgeted cost of energy is projected to decrease year-over-year due to decreases in renewable energy and Resource Adequacy market costs, as well as the impact of 328 MW of renewable energy and 420 MW of storage that began commercial operation under long term PPAs in FY 2024/25 and FY 2025/26 replacing, in many cases, higher cost, short term contracts. The cost of energy budget includes a contingency equal to 7.1% of projected cost of energy.
Staffing (+$3,770,000; 16% increase): Staffing costs include salaries and benefits payable in accordance with CPA’s Board-approved Employee Handbook, and salary grades and ranges approved by the Board on February 6, 2025. 57% of the increase is driven by the full-year impact of FY 2024/25 new hires, merit increases, a cost-of-living adjustment (COLA), and retention incentives. 43% of the increase is due to 7 new
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Board of Directors Item 12
positions and 4 potential unallocated mid-year hires. CPA is continuing with its retention program incentive through FY 2025/26, based on the Board’s direction at its September 7, 2023, board meeting.
The FY 2025/26 budgeted staffing costs increase is composed of the following:
$594,000 of these staffing expenses are reimbursable via CPUC Power Share customer program funding, and Southern California Equitable Building Decarbonization grant funding administered by the County of Los Angeles.
Technical services (+$529,000; 27% increase): Technical services comprise professional services for scheduling coordination, short- and long-term energy contracting, risk and portfolio management, and support for customer programs where engineering or other technical expertise is required. Scheduling coordinators provide a variety of services including scheduling generating and storage assets and customer energy use into the CAISO markets, managing CRR purchases and sales, validating CAISO invoices, and providing risk management and energy contract management software. Increases are primarily driven by an expectation that Scheduling Coordinator costs will increase after the expiry of CPA’s current Scheduling Coordinator contract in late 2025.
FY 2025/26 budgeted technical services expenses are composed of the following:
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Board of Directors Item 12
Legal services (+$453,000; 42% increase): Legal services support CPA’s contracting, including energy contracting for short- and long-term energy, resource adequacy, and non-energy contracting, including banking, finance, and local programs. Legal services also include support for specific regulatory proceedings (e.g., SCE’s ERRA Applications, SCE General Rate Case, and other compliance obligations), employment matters, governance, and general liability management. The budget increase is primarily due to the new Innovation Request for Offers process, the CPUC’s anticipated decision on the PCIA and related impact, and researching and addressing potential risk considerations associated with asset ownership. The majority of the budget in this section is provided by the firms listed in the following table:
Legal Service Major Providers
Energy Contracting Hall Energy Law
Clean Energy Counsel
Keyes & Fox
Perkins Coie
Regulatory Compliance and CPUC Proceeding
Advocacy
Braun Blaising & Wynne
Keyes & Fox
Braun, Blaising & Wynne
BRB Law LLP
Customer Programs Support Shute Mihaly & Weinberger
Banking and Finance Chapman
Employment Law and Compliance Jackson Lewis
General Liability and Governance Actium
Colantuono, Highsmith & Whatley
Coleman Frost
Polsinelli
Other services (+$545,000; 24% increase): Other services represent professional services not budgeted under Technical or Legal services and includes costs associated with energy compliance auditing, financial audits and audit support, rate setting, lobbying
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Board of Directors Item 12
services, non-technical assistance for local programs, and staff support services including recruitment, payroll, and benefits administration, IT support, and labor compliance.
The proposed budget increase is due primarily to budgeting for consulting services to support the procurement of new software to support and enhance CPA’s financial systems, as well as consultants to support FY 2025/26’s regulatory applications.
FY 2025/26 budgeted other services expenses are composed of the following:
Communications and marketing services (+$2,097,000; 53% increase):
Communications and marketing related services include costs associated with customer outreach, marketing, branding, website management, translation, advertising, special events, and sponsorships. The increase in communications and marketing expenses reflects investments in activities and consultants to support customer acquisition for CPA’s customer programs through advertising, sponsorship, social media, and branding efforts.
FY 2025/26 budgeted communications expenses and offsetting revenue (the latter recorded in the Other Revenue budget line item) are composed of the following:
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Board of Directors Item 12
65% of the communications and marketing budget is directed towards supporting Programs initiatives. The proposed increase in Special Events is to procure and deploy a Mobile Education Unit at community events throughout CPA’s service territory.
Customer notices and mailing services (583,000; 69% increase): This budget item supports communications with CPA’s customers, most of which are required by the CPUC. Costs include printing and postage and are increasing primarily due to new community enrollments in FY 2025/26 and an increase in Program-related mailings.
FY 2025/26 budgeted customer notices and mailing services are composed of the following:
Billing data management services (+$238,000; 2% increase): Billing data manager costs are based on the number of customer meters served by CPA and monthly per-meter rates charged by CPA’s billing data manager, Calpine Energy Services. Increased costs reflect a 2.5% inflation escalator on per-meter charges included in the Calpine contract approved by the Board on April 1, 2021, and the impact of the three new community enrollments beginning October 2025.
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Board of Directors Item 12
Service fees – SCE (+$154,000; 7% increase): Service fees are charged by SCE for a variety of customer billing and administrative services. The increase in service fees results from adding contingencies to cover unforeseen costs from SCE, as well as the increase in customer accounts due to three new community additions beginning in October 2025.
Customer Programs (+$1,217,000; 9% increase): Customer programs represent direct costs associated with providing energy programs to CPA customers and other related services. Direct costs include both incentives for participation and payments to third parties for program implementation. The FY 2025/26 customer programs budget supports the CPA Power Share program (expenses and above-market energy costs are reimbursable from CPUC), CPA’s EV charger rebate program which provides matching funds for electric vehicle charger incentives administered by the Center for Sustainable Energy/CALeVIP program, ongoing Power Response, Power Ready, Reach Code programs, Energized Communities, Sun Storage Rebate, Energy Advisor, Instant AC Savings program, Solar and Battery Access program, EV SmartCharge program, Hard to reach EV Technical Assistance, Low Income Efficient Cooling (Landlord) program, and a new Wildfire Recovery program.
FY 2025/26 budgeted customer programs expenses are composed of the following:
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Board of Directors Item 12
The smaller increase in Customer Programs expenses as compared to previous years’ results from lower-than-expected administrative costs and improved expense timing projections for some existing programs, offset by greater investments in other programs.
Finance and interest expense (+$531,000; 82% increase): Finance and interest expenses represent fees, borrowing interest, and letter of credit costs associated with CPA’s loan facility. Finance and interest expenses include a contingency to allow for borrowing or posting letters of credit.
Interest income (+$17,065,000; 180% increase): Interest income represents income earned on funds in Certificates of Deposits and savings accounts held by River City Bank, on US Treasury note investments, and on funds held in other investment accounts including the California Asset Management Program (CAMP) and the Local Agency Investment Fund (LAIF). CPA invests funds and earns interest income pursuant to its Investment Policy which prioritizes the safety and liquidity of investments and investment returns. The increase in interest income arises from a larger pool of funds available for investment.
Capital outlay (+$13,000; 4% increase): Expenditures associated with capital outlay will support and accommodate equipment purchases and office improvements as they age and need to be replaced.
ATTACHMENTS
1. Proposed FY 2025/26 Budget Presentation
2. Proposed FY 2025/26 Budget
Agenda Page 290
Proposed FY 2025/26 Budget
June 5, 2025
Agenda Page 291
Recommendation:
Approve Proposed Fiscal Year (FY) 2025/26 Budget as recommended by the Finance Committee (Attachment 2 to this Item)
Agenda Page 292
FY 2025/26 Budget Process
3 January – April 2025 (Staff) – FY 2025/26 Goal Setting, Departmental Budgeting, Rate Design Planning, Energy Cost Projections & Consolidated Budget Planning (ongoing) April 17, 2025 (Executive Committee) – Budget Priorities April 23, 2025 (Finance Committee) – Budget Priorities & Draft FY 2025/26 Budget May 1, 2025 (Board) – Budget Priorities
May 15, 2025 (Community Advisory Committee) – Draft FY 2025/26 Budget May 15, 2025 (Executive Committee) – Draft FY 2025/26 Budget May 28, 2025 (Finance Committee) – Proposed FY 2025/26 Budget June 5, 2025 (Board) – Proposed FY 2025/26 Budget
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Revenue Requirement
Electric utilities and load serving entities, including CPA, commonly base rates according to a “revenue requirement”
CPA’s FY 2025/26 budget reflects a decreased revenue requirement as a result of overall lower costs and a lower contribution to the net position (reserves) CPA’s current financial position allows for a responsible reduction in revenue while continuing to maintain sound fiscal health. This prudent revenue reduction is reflected in the rate setting approach approved by the Board in May 2025
Changes in revenue have distinct implications for different types of organizations In the private sector declining revenues and net income can be a cause for concern as they often mean lower profits and/or growth
For a not-for-profit public utility, declining revenues, which are often a result of lower customer rates, can be a positive outcome, as long as the entity has healthy reserves and liquidity, as is the case with CPA’s current condition and reflected in the proposed FY 2025/26 budget 4 Budgeting Context
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FY 2025/26 Budget Overview
5 The FY 2025/26 Proposed Budget reflects:
Lower energy costs ($1.21 billion; year-over-year decrease of $186 million or 13%) Lower contribution to Reserves ($65.1 million; year-over-year decrease of $68.2 million or 51%) Higher interest income ($26.7 million; year-over-year increase of $17.1 million or 180%) Higher operating expenses ($77.1 million; year-over-year increase of $9.6 million or 14%) Lower revenues ($1.32 billion; year-over-year decrease of $263 million or 17%) These key elements were considered in the rate setting approach approved by the Board in May and enable CPA to reduce revenue and cover costs, while still achieving the target Reserve balance and liquidity goals outlined in the Reserve Policy.
Agenda Page 295
Energy Costs
6 13% reduction in energy costs reflect:
328 MW of renewable energy and 420 MW of storage that began commercial operation under long term PPAs in FY 2024/25 and FY 2025/26 replacing, in many cases, higher cost, short term contracts
A decrease in market prices for resource adequacy and renewables A contingency equal to 7.1% of projected energy costs
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Operating Expense Highlights
74% of the Operating Expense increase is due to budget priorities in:
Staffing: Year-over-year increase of 16%
o Increase reflects full year impacts of FY 2024/25 new hires, COLA, merit, retention incentives, 7 new positions, and 4 potential unallocated mid-year hires (see slide 15 for details). $594K is reimbursable by grant and program funding (included in Other Revenues) Communications: Year-over-year increase of 53%
o Increase supports customer program acquisition through website enhancements, market research and CBO-led outreach efforts, as well as branding efforts to improve CPA brand recognition and awareness, and a turnkey Mobile Education Unit. 65% of the total Marketing and Communications budget is intended to support Programs
Customer Programs: Year-over-year increase of 9%
o The smaller increase in Customer Programs expenses as compared to previous years’ results from lower than expected administrative costs and improved expense timing projections for some existing programs, offset by greater investments in other programs 7 Agenda Page 297
Non-Operating Revenue and Reserves
8 Interest income is projected to increase by 180% year-over-year due to a larger pool of funds available for investment
CPA invests funds and earns interest income pursuant to its Investment Policy which prioritizes the safety and liquidity of investments and investment returns
The budgeted increase in the net position is anticipated to bring CPA’s reserve percentage to 50% by June 30, 2026, achieving the target balance as outlined in the Reserve Policy1 Days liquidity on hand (DLOH)2 would increase to 189 days consistent with the Reserve Policy 1 Reserves are the sum of the Net Position and Fiscal Stabilization Fund (also known as balance sheet equity) and are not equivalent to, nor held as, cash 2 DLOH is equal to the sum of cash, investments and available line of credit divided by average daily expenses Agenda Page 298
Total Revenue
9 Net electricity revenue’s 17% decrease reflects:
The Board approved FY 2025/26 rate approach3
A year-over-year increase in budgeted load of 0.1%; increases in load from new community enrollments and increased customer electrification is offset by decreases from customer solar additions and refinements in CPA’s load forecast modeling
A bad debt expense budgeted at 2.0% of revenue or $26.9 million which is relatively flat to the 1.9% of revenue included in the FY 2024/25 Budget
3 FY 2025/26 Rate Approach approved by the Board May 1, 2025: Strengthened Reserve approach resulting in targets of Lean -2%, Clean 0%, 100% Green +6% compared to Residential/Small Business SCE base rates as of June 1, 2025. Targets are based on total bill comparisons on a representative 2018 PCIA vintage rate schedules, average customer usage, and load profiles for each specified rate class. Individual customer comparisons vary by specific rate schedule and customer usage.
Agenda Page 299
The FY 2025/26 Proposed Budget reflects:
Lower energy costs ($1.21 billion; year-over-year decrease of $186 million or 13%) Lower contribution to Reserves ($65.1 million; year-over-year decrease of $68.2 million or 51%) Higher interest income ($26.7 million; year-over-year increase of $17.1 million or 180%) Higher operating expenses ($77.1 million; year-over-year increase of $9.6 million or 14%) Lower revenues ($1.32 billion; year-over-year decrease of $263 million or 17%) The budgeted increase in net position is anticipated to achieve CPA’s Reserve Policy target of 50% by June 30, 2026, with a days’ liquidity on hand level of 189 days CPA financial metrics continue to compare favorably with peer CCAs and are consistent with CPA’s “A-” credit rating
10 Summary
Agenda Page 300
Recommendation:
Approve Proposed FY 2025/26 Budget as recommended by the Finance Committee (Attachment 2 to this Item)
Agenda Page 301
Questions?
Agenda Page 302
Select CCA Metrics and Comparisons
13 CPA’s metrics for total operating expenses and staffing costs compare favorably with industry averages Agenda Page 303
Reserve Policy Targets
CPA Reserve Policy
“CPA shall grow reserves to maintain a minimum reserve target equal to 30% of total operating budget expenditures, with a goal of increasing the reserve to a maximum reserve target of 50% of total operating budget expenditures. Reserves shall not exceed 60% of total operating budget expenditures. Reserves shall support the goal of securing 120 days liquidity on hand.” 14 Agenda Page 304
Current Staff Headcount + Proposed Positions
(updated for Proposed Budget)
Department Current Positions Proposed New Positions Total Executive (including Board Office) 7 0 7
Legal 3 0 3
Coms & Marketing 11 2 13
Customer Care 4 0 4
Customer Programs 9 1 10
Data & Systems 7 1 8
Finance (including Accounting, FP&A, Load Forecasting, Risk Management, Strategic Initiatives, Treasury)
13 (two open)
2 15
Government Affairs 5 0 5
Operations (including Non-Energy Procurement, Strategic Accounts) 3 0 3 People & Culture/Admin 5
(one open)
0 5
Power Supply 16
(one open)
0 16
Rates & Strategy 3 1 4
Regulatory Affairs 4 0 4
Unallocated (mid-year hires based on need) - Up to 4 TBD Total 90 7-11 97-101
15 Agenda Page 305
A B C D E F
FY 2024/25
Budget
FY 2025/26
Budget
Budget
Difference ($)
Budget
Difference (%)
% of
Revenue
Revenue - Electricity net 1,582,354,000 1,319,741,000 (262,613,000) -17% Transfer from Fiscal Stabilization Fund - - - 0%
Other revenue 2,939,000 4,514,000 1,575,000 54%
TOTAL REVENUE 1,585,293,000 1,324,255,000 (261,037,000) -16% TOTAL ENERGY COSTS 1,393,295,000 1,207,444,000 (185,851,000) -13% 91% NET ENERGY REVENUE 191,998,000 116,811,000 (75,186,000) -39%
OPERATING EXPENSES
Staffing 24,076,000 27,846,000 3,770,000 16% 2.1%
Technical services 1,936,000 2,465,000 529,000 27% 0.2% Legal services 1,089,000 1,542,000 453,000 42% 0.1%
Other services 2,257,000 2,802,000 545,000 24% 0.2%
Communications and marketing services 3,982,000 6,079,000 2,097,000 53% 0.5% Customer notices and mailing services 842,000 1,425,000 583,000 69% 0.1% Billing data management services 12,041,000 12,279,000 238,000 2% 0.9% Service fees - SCE 2,250,000 2,404,000 154,000 7% 0.2%
Customer programs 13,208,000 14,425,000 1,217,000 9% 1.1% General and administration 5,828,000 5,836,000 8,000 0% 0.4% TOTAL OPERATING EXPENSES 67,509,000 77,103,000 9,594,000 14% 6% OPERATING INCOME 124,489,000 39,708,000 (84,781,000) -68% Finance and interest expense 645,000 1,176,000 531,000 82% TOTAL NON OPERATING EXPENSES 645,000 1,176,000 531,000 82% Interest Income 9,503,000 26,568,000 17,065,000 180%
TOTAL NON OPERATING REVENUE 9,503,000 26,568,000 17,065,000 180% NON OPERATING REVENUE (EXPENSE) 8,858,000 25,392,000 16,534,000 187% CHANGE IN NET POSITION 133,347,000 65,100,000 (68,247,000) -51% 3% NET POSITION BEGINNING OF PERIOD 327,654,232 461,001,232 133,347,000 41% NET POSITION END OF PERIOD 461,001,232 526,101,232 65,100,000 14% FISCAL STABILIZATION FUND 135,000,000 135,000,000 - 0%
RESERVES END OF PERIOD (Net Position + FSF) 596,001,232 661,101,232 65,100,000 11% Other Uses
Capital Outlay 325,000 338,000 13,000 4%
Depreciation & Amortization (794,000) (617,000) 177,000 -22% CHANGE IN FUND BALANCE 133,816,000 65,379,000 (68,437,000) -51% Note: Funds may not sum precisely due to rounding
CLEAN POWER ALLIANCE of SOUTHERN CALIFORNIA
Fiscal Year 2025/2026 Budget
PROPOSED
Agenda Page 306
Management Report
To: Board of Directors
Subject: Management Report
Date: June 5, 2025
Federal Policy Update
Staff will provide a verbal overview of the negotiations in Washington DC on the future of clean energy tax credits.
Board Retreat Reminder
CPA’s annual Board Retreat will take place on June 13, from 8:30am to 2pm in the City View Penthouse of South Park Center, 1150 S Olive St, Los Angeles, California, 90015.
To date, 38 Board members representing 26 member agencies have confirmed attendance, along with eight Community Advisory Committee members. Study materials and logistical information will be distributed on June 6.
July 10 Board Meeting Logistics
Due to the proximity to the July 4 holiday, CPA’s next full Board meeting will be held on July 10, outside of the normal first Thursday of the month cadence. In addition, given the limited (though still time critical) number of expected agenda items, CPA will be expanding the number of remote locations for the July 10 Board meeting to minimize travel time within the San Gabriel Valley, South Bay, Westside, and Ventura County. If you plan to be outside of Los Angeles or Ventura Counties and need additional remote accommodation, please contact the Clerk of the Board.
Potential Expansion Studies
After a year-long pause on CPA expansion initiatives in 2024 for new cities that would start service in 2026, two cities proactively reached out to CPA about joining the Joint Powers Agreement and have approved feasibility studies for a potential 2027 service start. The two cities – Cudahy and Fillmore – each have approximately 6,000 electricity customers and Fillmore is the only jurisdiction in Ventura County that is not part of CPA
Agenda Page 307
Board of Directors Management Report
service territory. CPA staff will conduct the two feasibility studies over the summer and present the results and possible action to the Board in September.
Triennial Data Privacy Report and IT Security Audit
In April, CPA submitted its Triennial Data Privacy Report for the reporting period of 2022- 2024 to the CPUC, which included an independent audit of CPA’s data privacy and security protection policies and procedures for customer energy usage data. Concurrent with the data privacy audit, CPA also conducted a broader IT Security Audit focusing on internet-facing assets and vulnerabilities that can be exploited through cyber-attacks, internal and external vulnerability management, Microsoft 365 tenant security, and third-party vendor risk management, including the risk posed by ransomware and security incidents.
The Triennial Data Privacy Report contained no exceptions and indicated that CPA is in compliance with CPUC requirements with no findings. The IT Security Audit results showed that CPA scored significantly higher (780) than the Utilities Industry Average (720) for Data Security and Information Technology Environment and Controls. The auditor noted that “CPA continues to take cybersecurity and its obligations to protect customer data seriously demonstrating consistent effort on improvements and increasing internal expertise and staffing to more rapidly address and improve cybersecurity and related technical controls.”
Board of Directors Stipends
At its April 2025 meeting, the Board of Directors approved an amended CPA Stipend and Expense Reimbursement Policy. CPA will begin issuing stipends for attendance in August for the July Board and Committee meetings and continue a monthly cadence going forward. In the coming days, the Clerk of the Board will distribute W-9 forms. To ensure timely payment, Board members are encouraged to submit their completed W-9 forms by June 30, 2025.
Monthly Financial Performance
CPA’s net position in March increased by $10.5 million, 12.5% less than the budgeted increase of $22.6 million. March results were negatively impacted by below budget
Agenda Page 308
Board of Directors Management Report
revenues that were the result of the interim rate reduction approved by the Board in February and which took effect in March. For the year-to-date/first three quarters of the fiscal year, CPA has recorded an increase to the net position of $77.9 million, 303% higher than the budgeted net increase of $19.4 million. As a result of the March interim rate decrease, CPA expects results to be lower than budget for the remaining three months of the fiscal year; given the above budget results so far, CPA is still on track to meet its overall fiscal objectives for FY 2024/25. The monthly financial dashboard for March is contained in Item 6, the Quarterly Financial Report.
Customer Participation Rate and Opt Actions
As of May 28, 2025, CPA’s overall participation rate was 92.8%, down slightly from the
92.9% participation rate recorded in the previous month. CPA had 1,039,312 active customers at the end of May, up 193 customers compared to the end of April. Opt-outs for the month – 322 – were similar to April, which posted 344 opt-outs. New accounts (“move-ins”) were higher than closed accounts (“move-outs”) by 55 customers in the same time period. Participation rates and active accounts by member agency are provided in Attachment 1 of this report.
Customer Service Center Performance
Incoming calls to CPA’s Customer Service Center continued to in May compared to the previous month and the monthly average for the first quarter of the year, commensurate with lower overall electricity bills as a result of CPA’s March rate reduction. Through May 27, CPA received 1870 calls, compared to 2,248 calls in April and a monthly average of 3,983 in the first quarter of the year. Call center performance was steady, with 98% of calls answered within 45 seconds, compared to 99% the previous month. Average call center wait time was 5 seconds, compared to 4 seconds in April.
Contracts and Amendments Executed Under the CEO Authority A list of amendments to, and terminations of, Long-Term Power Purchase Agreements and Energy Storage Agreements executed under the CEO’s signing authority since July 2024 is provided in Attachment 2. A list of non-energy contracts executed under the CEO’s signing authority is provided in Attachment 3. This list includes all open contracts as well as all contracts, open or completed, executed in the past 12 months.
Agenda Page 309
Board of Directors Management Report
ATTACHMENTS
1. Participation Rates by Member Agency
2. Long Term PPA/ESA Amendments Executed under CEO’s Authority
3. Non-Energy Contracts Executed under CEO’s Authority
Agenda Page 310
Jurisdiction Preferred Energy Option Active Accounts Participation % Lean % Clean % 100% Green % AGOURA HILLS 100% Green 7,995
ALHAMBRA 100% Green 34,325
ARCADIA Lean 22,656
BEVERLY HILLS 100% Green 18,637
CALABASAS 100% Green 9,585
CAMARILLO 100% Green 28,861
CARSON Clean 29,459
CLAREMONT 100% Green 12,735
CULVER CITY 100% Green 19,349
DOWNEY Clean 36,878
HAWAIIAN GARDENS Clean 3,644
HAWTHORNE 100% Green 28,518
HERMOSA BEACH 100% Green 9,931
LOS ANGELES COUNTY 100% Green 293,794
MALIBU 100% Green 6,318
MANHATTAN BEACH 100% Green 15,209
MONROVIA 100% Green 16,103
MOORPARK Clean 11,402
OJAI 100% Green 3,483
OXNARD 100% Green 55,802
PARAMOUNT Clean 15,810
REDONDO BEACH 100% Green 33,366
ROLLING HILLS ESTATES 100% Green 3,515
SANTA MONICA 100% Green 55,605
SANTA PAULA 100% Green 9,366
SIERRA MADRE 100% Green 4,930
SIMI VALLEY Lean 43,452
SOUTH PASADENA 100% Green 11,587
TEMPLE CITY Lean 12,701
THOUSAND OAKS 100% Green 44,391
VENTURA 100% Green 44,827
VENTURA COUNTY 100% Green 32,891
WEST HOLLYWOOD 100% Green 26,734
WESTLAKE VILLAGE Lean 3,717
WHITTIER Clean 31,736
TOTAL
89.2% 3.7% 0.4% 95.9%
95.3% 2.1% 0.1% 97.8%
95.0% 99.8% 0.1% 0.1%
97.3% 2.3% 0.1% 97.6%
93.1% 3.4% 0.3% 96.3%
89.9% 2.2% 0.1% 97.7%
95.5% 1.6% 96.0% 2.3%
91.2% 3.4% 0.3% 96.3%
94.9% 4.3% 1.0% 94.7%
95.0% 1.7% 97.2% 1.1%
95.3% 1.5% 96.5% 2.1%
97.0% 0.9% 0.1% 99.0%
92.4% 3.0% 0.6% 96.5%
94.3% 2.4% 30.7% 66.9%
94.3% 3.2% 0.4% 96.4%
94.9% 3.3% 0.4% 96.3%
90.4% 4.3% 0.5% 95.2%
85.6% 3.3% 96.2% 0.6%
88.7% 6.1% 1.2% 92.7%
92.5% 4.0% 0.5% 95.5%
96.6% 0.3% 94.5% 5.3%
95.9% 2.6% 0.1% 97.3%
91.7% 8.1% 1.5% 90.4%
94.9% 3.5% 0.6% 95.9%
90.2% 2.5% 0.3% 97.2%
91.8% 5.8% 1.5% 92.7%
89.2% 99.7% 0.1% 0.2%
94.3% 4.0% 0.7% 95.4%
95.7% 99.8% 0.1% 0.2%
83.4% 8.1% 1.5% 90.5%
89.2% 4.9% 1.1% 94.0%
84.6% 6.9% 1.0% 92.0%
97.0% 2.6% 0.3% 97.1%
88.0% 99.5% 0.1% 0.5%
93.9% 2.0% 97.2% 0.8%
92.5%
CUSTOMER STATUS REPORT
PARTICIPATION BY CITY AND COUNTY
May 28, 2025
ACTIVE ACCOUNTS BY ENERGY PRODUCT
Energy Option Active Accounts Percentage
100% Green Power
Clean Power
Lean Power
TOTAL 100.0%
10.8%
21.0%
68.2%
1,039,312
112,437
217,641
709,234
1,039,312 92.8%
Agenda Page 311
Project Purpose Month Notes
Sunzia
Amendment to allow Sunzia the option to operate each turbine in the South Wind project area at a nameplate capacity of 3.8MW vs the originally contemplated 3.6MW
May 2025
Sunzia
Letter Agreement extending the negotiating period to address Slice of Day language in existing contract
May 2025
Cape Station 30
MW and 18 MW
Letter Agreement to the Power Purchase Agreements to update insurance requirements. The Letter Agreement applies to both the 30 MW and incremental 18 MW Cape Station agreements.
April
2025
Rexford
Amendment to the Power Purchase Agreement to update the Ultimate Parent definition after a Change in Control
February
2025
Drifter
Amendment to Energy Storage Agreement to extend the termination deadline while parties identify mutually beneficial solutions January
2025
Desert Sands II
Amendment to a Letter Agreement to the Energy Storage Agreement to extend the termination deadline while parties identify mutually beneficial solutions
December
2024
Desert Quartzite
Letter Agreement to Power Purchase Agreement to document grid charging cessation procedures
November
2024
Drifter
Amendment to Energy Storage Agreement to extend the termination deadline while parties identify mutually beneficial solutions October
2024
Desert Sands I
Amendment to Power Purchase Agreement to facilitate the transfer of the site to a backup facility contemplated in the contract, Key Energy Storage, and allow for a delay in COD in return for a price decrease September
2024
Wilmington 2
Amendment to Power Purchase Agreement to allow for additional payments of liquidated damages to extend the COD
September
2024
Dominguez
Amendment to Power Purchase Agreement to allow for additional payments of liquidated damages to extend the COD
September
2024
Desert Sands II
Amendment to a Letter Agreement to the Energy Storage Agreement to extend the termination deadline while parties identify mutually beneficial solutions
August
2024
Workman Mill
Termination of the Power Purchase Agreement for failure of Seller to meet contractual deadlines
July 2024
Dinuba Biomass
Termination of the Power Purchase Agreement for failure of Seller to meet contractual deadlines
July 2024
Drifter
Amendment to Energy Storage Agreement to extend the termination deadline while parties identify mutually beneficial solutions July 2024
Previous 12 Months
Long-Term Energy Contracts Administrative Amendments, Letter Agreements and Terminations Executed Under Chief Executive Officer's Authority
Agenda Page 312
Vendor Purpose Month NTE Amount Status Notes
EGIA
Incentive management services
renewal term
May-25 $92,510 Active
Spirit Media
Videography services for CPA teaser
video
May-25 $97,375 Active
Trinity Consultants
Third-party verification services for
2024 EPE emissions data report
May-25 $24,000 Active
BRB Law Legal services, regulatory May-25 $50,000 Active Raimi & Associates
End date extension only for Inglewood
Oil Field energy storage feasibility
study
May-25 $0 Active End date extension only
EPRI Research Participation Agreement Apr-25 $54,000 Active USGBC California
Workforce development grant for
wildfire recovery resources Apr-25 $50,000 Active
IFUS ICE Futures Platform access Apr-25 $0 Active
Redhill Group Customer Researh Services Apr-25 $34,589 Active LinkedIn Recruiting Platform Subscription Feb-25 $10,250 Active Raimi & Associates
Inglewood Oil Field energy storage
feasibility study Feb-25 $118,713 Active
Abbot, Stringham & Lynch Green-e Energy Program reporting Feb-25 $24,000 Active Wicked Bionic
Creative services for Customer
Programs Jan-25 $225,000 Active
Omni Government Relations
Renewal to lobbying services
agreement
Jan-25 $102,492 Active
Pinnacle Advocacy
Renewal to lobbying services
agreement
Jan-25 $76,652 Active
Wrike Project management software Jan-25 $20,280 Active Verve Cloud Internet service Jan-25 $20,988 Active
TRC
Amendment to PSA for reach code
technical consulting
Dec-24 $36,928 Active
Wellable Employee wellness platform Dec-24 $13,075 Active Crown Castle Fiber LLC
Office dedicated internet access
service
Nov-24 $18,600 Active
Alter Agents CPA Brand Tracker Nov-24 $44,000 Active
New Block Digital Agency Website QA services Nov-24 $25,000 Active Language Line Translation services Nov-24 $42,000 Active Green Translations Translation services Nov-24 $42,000 Active Intelligence Press Natural gas data subscription Nov-24 $7,400 Active Cindy Levine Group
Amendment to PSA for management
coaching services Nov-24 $12,500 Active
Downey Brand LLP Legal Services (CPUC mediation) Nov-24 $55,000 Active Ross Associates Management coaching services Oct-24 $16,000 Active Perkins Coie
Amendment to Legal Services
Agreement for RFO support Oct-24 $70,000 Active
Actium LLP Legal services for general liability Oct-24 $55,000 Active Windstream Services, LLC Office telephone service Sep-24 $12,924 Active Thorn Run Partners LLC Federal lobbying services Sep-24 $125,000 Active Sigman Computing Analytics platform Sep-24 $30,800 Active JustFOIA PRA request management software Sep-24 $9,835 Active Salesforce
Additional license for CRM
subscritpion
Sep-24 $3,733 Active
Helpmates HR temporary staffing services Aug-24 $24,000 Active Workable HR recruitiung paltform subscrption Aug-24 $14,028 Active DataCamp
Training subscription for Data &
Systems team
Aug-24 $1,200 Active
Non-Energy Contracts Executed Under Chief Executive Officer Authority Rolling 12 months. Open contracts shown in bold.
Agenda Page 313
Salesforce
Stakeholder relationship management
application subscription
Aug-24 $15,300 Active Renewal
Abbott, Stringham & Lynch Data security complaince services Jul-24 $18,500 Active LinkedIn LinkedIn Learning subscription Jul-24 $16,150 Active Hall Energy Law PC Energy procurement counsel Jul-24 $125,000 Active Renewal Burke, Williams, Sorenson, LLP
Legal Services Agreement (Brown Act,
public entity governance issues, and
other legal services)
Jul-24 $100,000 Active Renewal
Elite Edge Financial reporting services Jul-24 $93,600 Active Renewal SAESHE, Inc. Street teams support services Jun-24 $60,000 Active Snowflake Data cloud services Jun-24 $25,000 Active
Lazar Translating & Interpreting Translation services Jun-24 $50,000 Active Great Place to Work Institute Staff survey & certification platform May-24 $3,495 Active
Agenda Page 314