AGENDA ITEM
Public Utilities Commission
City and County of San Francisco
DEPARTMENT Financial Services AGENDA NO. 14
MEETING DATE May 14, 2024
Calendar: Regular Calendar
Project Manager: Erin Corvinova
Adopt CleanPowerSF Rates for FY 2024-25
Summary of
Proposed
Commission Action:
Public Hearing to consider adopting schedules of rates of the San Francisco Public Utilities Commission (SFPUC) Power Enterprise for CleanPowerSF power service in San Francisco to be effective July 1, 2024. This action constitutes the Approval Action for the project for the purposes of the California Environm ental Quality Act (CEQA) pursuant to Section 31.04(h) of the San Francisco Administrative Code. The Planning Department has determined that this action is exempt from the CEQA. If the item is approved, the Commission will rely on that determination to make its decision.
Background: As required by the San Francisco Charter Section 8B.125, the SFPUC engaged an independent rate consultant, NewGen Strategies & Solutions, for the 2022 SFPUC Power Rates Study. Since the completion of this study, SFPUC has adopted and plans to continue to adopt rates for CleanPowerSF one year at a time. Each year staff will update the cost of service and rate models developed during the 2022 study with the latest cost and customer billing data . The next Cost of Service Rate Study is scheduled to be initiated in Fall of 2024 and be completed in Spring of 2026, to recommend rates beginning Fiscal Year (FY) 2026-27.
2022 SFPUC Power Rates Study
In the 2022 Power Rate Study, the consultant recommended retail rates for two years – FY 2022- 23 and FY 2023- 24. The findings for both Power business lines, Hetch Hetchy Power and CleanPowerSF , were summarized in the 2022 Power Rates Study Final Report . However, in response to increased volatility in energy markets caused by geopolitical conflict and continued supply chain disruptions from COVID-19, Staff proposed to adopt only one year of rates (FY 2022- 23), opting to continue to monitor and respond to the rapidly changing market conditions . As part of the recommendations of the study, CleanPowerSF sought to move forward with a new reserves policy to build up reserves higher than the other SFPUC enterprises. This higher Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
reserve policy was established to help buffer CleanPowerSF from unexpected surges in expenditures, like the power market price volatility experienced over the last few years.
On May 24, 2022, the SFPUC Commission adopted CleanPowerSF FY 2022-23 rates in Resolution 22-0094.
CleanPowerSF FY 2023-24 Rate Setting
For FY 2023- 24, s taff updated the 10-year financial plan with FY 2023-24 operating and capital expenditures and evaluated revenues required to continue to build a fund balance consistent with the Days- Cash-On-Hand target set by the Fund Balance Reserve Policy . These updated revenue requirements recommended an 15% total increase in rates revenue, as compared to the prior year.
Staff then leveraged the financial models from the 2022 Rate Study to functionalize revenue requirements, allocate costs to customer classes, and calculate rates. Because some cost line items increased faster than others, and because of changes in usage and enrollment in each rate schedule, rate increases for individual customer classes can be higher or lower than the overall 15% revenue increase.
On May 9, 2023, the SFPUC Commission adopted CleanPowerSF FY 2023-24 rates in Resolution 23-0101.
CleanPowerSF FY 2024-25 Rate Setting
The FY 2024- 25 rates set ting analysis followed a very similar methodology as in FY 2023- 24. This process was a cross -agency effort, with the Business Services’ Financial Planning team serving as the project lead and primary point of contact for the SFPUC. Power staff were heavily
involved in data collection and rates
recommendations, while Communications provided public outreach.
Staff updated the revenue requirement for FY 2024- 25 with operating and capital expenditures from the Commission- adopted FY 2024-25 to FY 2033-34 10-Year Financial Plan, which incorporated the adopted FY 2024-25 Operating Budget and FY 2024-25 to FY 2034-34 10-Year Capital Plan. Detailed line items making u p the revenue requirement are included in Attachment 1. FY 2024- 25 CleanPowerSF Revenue Requirement.
Staff leveraged analysis from the FY 2022 Power Rate Study and the subsequent adjustments made in the FY 20 23-24 Power Rate update Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
for the functionalizatio n of revenue requirement s, allocation to customer classes, development of unit costs, and ultimately the recommended schedule of rate tariffs. To calculate the updated cost allocations to each customer class, staff used the latest full year of billing data that was available from December 2022 through November 2023 . Detailed line items of the revenue requirement distribution process are included in Attachment 2. FY 2024- 25 CleanPowerSF Cost Functionalization, Classification, and Allocation.
In designing rates, Staff analyzed the bill impact of the proposed FY 2024-25 rates to CleanPowerSF customers, compared CleanPowerSF customers’ bills to those of PG&E, evaluated the revenue projection to ensure that revenue requirement was met, and considered the impact of proposed rates on the projected Days -Cash-On-Hand relative to the Fund Balance Reserve Policy.
Revenue Requirement
The CleanPowerSF revenue requirement from retail sales for FY 2024-25 is estimated to be approximately $ 431 million. Costs include purchases of renewable energy, shaped energy, capacity, wholesale energy market costs, contingency, growth in cash reserves, and operating and other costs.
Total p ower supply costs make up the biggest share ( 84.1%) of revenue requirement for CleanPowerSF in FY 2023-24. Operating and other costs ( 9.3%) include SFPUC labor, operations , and capital spending. Anticipated contributions to internal reserves (growth in days cash on hand) make up about 6.6% of total revenue requirements.
The total rate revenue requirements have increased by $61.9 million (17%) since last year’s rate adjustment. Compared to projections in the FY 2023-24 rate update, costs allocated to the power supply function and customer-related expenditures have increased by $55.5 million (16%) and $6.3 million (26%), respectively. The large increase in power supply costs partially stem s from the increased volume of power purchases to serve increased customer demand. However, volatility of power supply prices has continued; while prices have dropped from their peaks in FY 2022- 23, they remain elevated from their pre-pandemic levels. Both prices and higher loads have increased purchased power supply costs by $23 million. In addition, resource adequacy costs continue to grow, with a forecasted increase of $ 3 million in FY 2024- 25 as compared to the current year.
CleanPowerSF’s budgeted contingency to cover unexpected overages in supply costs is set to $30.5 million to address further potential price Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
volatility.
Energy Demand and Usage
Billing data for December 2022 through November 2023 was used in the cost-of-service model to update the calculation of how different customer classes drive costs of the power sys tem. Overall, power usage has increased since the FY 2023 -24 Rate Update, but the increases are not equivalent across all customer classes. For example, residential usage has declined slightly ( -0.6%) despite a modest increase in customers, whereas Large Commercial has more than doubled (113.4%) thanks to the addition of a few high demand customers.
Table 1 summarizes CleanPowerSF customers’ projected energy usage for major customer classes for FY 2024 -25 and the relative change since the FY 2023-24 Rate Update.
Table 1. Count of customers and total energy used by each customer class and the percent change in usage from the FY 2023-24 Rate Update.
Customer Class No. of
Customers
Total Usage for
Customer Class
(MWh/Yr)
Residential 359,146 1,243,201 (-0.6%)
Small General Service 27,263 403,821 (-5.1%)
Medium General Service –
Low Demand 2,11 344,114 (-1.0%)
Medium General Service –
High Demand 7,339 650,284 (7.7%)
Large General Service &
Agriculture 115 582,363 (113.4%)
Outdoor Lighting 203 1,300 (-11.9%)
Total 396,189 3,225,085 (11.1%)
Rate Design
Current Rate Structure
The default product offered by CleanPowerSF is the “Green” energy product, which contains a minimum of 60% California Renewable Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
Portfolio Standard -eligible renewable energy and is more than 90% greenhouse gas free. CleanPowerSF also offers a “ SuperGreen” product that is 100% California Renewable Portfolio Standard- eligible renewable energy as a premium product. The SuperGreen produ ct is sold as a voluntary rate rider, which is added to the standard Green energy product rate.
Proposed CleanPowerSF FY 2024-25 Rates
Following cost allocation updates in the Cost-of-Service model staff observed that the 1 2% rate adjustments that were pro posed in the 10- year Financial Plan would result in bills for the average residential customer exceeding those of customers being served by PG&E . As a result, staff recommend reducing the top line rate increase to 8.5% to allow CleanPowerSF to continue to provide competitive rates that are lower than PG&E for all customers and maintain the cost -of-service principals that have been established over the previous two years. The lower rate adjustment is made possible by reducing the growth in cash reserves in FY 2024- 25. To compensate, a larger rate adjustment will be required in FY 2025- 26 to meet the 180 Days Cash on Hand Financial Policy target.
Table 2 summarizes the proposed effective CleanPowerSF Green generation rates by customer class. The detailed rate tariff schedule is included in the attached commission resolution.
CleanPowerSF generation charges only m ake up a portion of the customer’s total bill, with PG&E delivery charges and other fees making up the majority of the monthly bill. A verage CleanPowerSF customers on residential rate schedules will see about 6.4% increase in total bill, and average custom ers on key commercial rate schedules will see about -0.7%-4.7% increase in total bill.
Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
Table 2. Proposed Effective Green Rates for FY 2024-25
Customer Class FY 2024-25
Green Rates
% Generation
Rate Change
Residential $0.15169 12.0%
Small General
Service $0.13480 10.1%
Medium General
Service – Low
Demand
$0.13022 9.7%
Medium General
Service – High
Demand
$0.12731 7.9%
Large General
Service $0.10129 -4.9%
Agriculture $0.10184 -5.5%
Outdoor Lighting $0.13937 11.0%
Customer Bill Comparison
When comparing total bills, CleanPowerSF generation rates , Power Charge Indifference Adjustment (PCIA), and Franchise Fee Surcharge (FFS) are included in the generation component of a CleanPowerSF customer’s bill; similarly, comparable PG&E generation rates and PCIA make up the generation component of a PG&E generation customer’s bill.1 The delivery component of a customer’s bill will be the same whether the customer receives their generation service from CleanPowerSF or PG&E.
Staff compared CleanPowerSF customer bills with proposed FY 2024- 25 rates to those of PG&E as of April 2024. Except for three rate schedules – E-EV and E-EV2 (Residential Time -Of-Use Service for Plug-In Electric Vehicle Customers )2 and LS-1 (Street, Highway, and Outdoor Area Lighting)3 – CleanPowerSF customers were projected to
1 The PCIA is charged to all customers to collect the above market costs of energy purchased by PG&E. The FFS is charged to collect the franchise fees paid by PG&E to local governments for the use of streets. 2 EV has two schedules: EV-A and EV-B. The E-EV-B schedule is open to residential customers with separately metered battery electric vehicle (BEV) or plug-in hybrid electric vehicle (PHEV) recharging outlet. EV-2, a different electric vehicle rate schedule from EV, is currently open to customers with whole house service where the residential usage and the electric vehicle charging usage is metered together. There is also a legacy EV -A schedule, with the same rates and time-of-use periods as EV-B, where customers may have either type of meter. 3 CleanPowerSF rate LS-1 applies to PG&E rate schedules SL-1, SL-2, SL-3, and OL-1.
Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
have lower total bills with proposed CleanPowerSF FY 202 4-25 generation rates for average customers than comparable PG&E current rates.
To support the City’s climate action goals, Staff proposes rebalancing4 these three rate schedules to ensure that the average bill for a customer in this rate class is lower than what they would pay under current PG&E rates . Rates have been rebalanced within the residential customer class to keep the effective rate of the customer class to cost of service.
After rebalancing, CleanPowerSF customers with the proposed CleanPowerSF FY 202 4-25 generation rates are projected to on average have equivalent or lower total bills compared to current PG&E rates as of April 2024.
SuperGreen Premium
SuperGreen rates were also evaluated in the 2022 Study and deemed to meet cost of service. Staff propose s to keep SuperGreen residential rates at the current premium of $0.010/kWh and commercial rates at $0.005/kWh.
Rate Time Period
As mentioned earlier, continued volatility in energy markets caused by geopolitical conflict is leading to significant risk in power procurement costs and is the main reason for proposing an annual rate for CleanPowerSF customers for FY 2024- 25. As CleanPowerSF’s new reserves policy focuses on building sufficient reserves, the proposed single year of rate increases will allow CleanPowerSF to monitor and respond to rapidly changing market conditions for FY 2025-26.
Public Outreach and Education
SFPUC staff engaged customers and the genera l public on the Power Rates Study through a variety of public meetings.
4 Rebalancing rates is a process of rate design by which the portion of revenue requirement reduced from changing rates of a rate schedule is calculated and absorbed by other rate schedules.
Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
The agency’s Rate Fairness Board has been the primary public venue where CleanPowerSF’s FY 2024- 25 rate-setting methodology, objectives, and preliminary analysis have been discussed in a series of meetings On March 1, and March 22, 2024. The proposed results of FY 2024-25 rates were presented to Rate Fairness Board members on Wednesday, April 10, 2023.
Additionally, staff has provided rate payers with additional information about the proposed rate adjustments. A dedicated power rates landing page at SFPUC.org/powerrates has been established with news of upcoming public events, the commission hearing notice, links to presentations, and once adopted the final rates . A phone number where this information can be obtained is also included. This website has been promoted through on bill messages, multilingual rate notice bill inserts, e-newsletters, and direct mail postcards. Staff also held a webinar on residential rates and the rate study process on May 1.
Public Hearing Notice
Pursuant to Charter Section 16.112, a Notice of Public Hearing on the establishment of a schedule of rates was published in the official newspaper on April 21, 24, 25, 26, and 28, 202 4, and posted on the SFPUC website and at the San Francisco Public Library, for a public hearing on May 14th, with possible Commission action on this date.
Board of Supervisors Review
Pursuant to Charter Section 8B.125, Commission action adopting rates and charges is subject to
rejection by the BOS within 30 days of
submission to the BOS . Absent BOS rejection, these proposed CleanPowerSF rates will become effective July 1, 2024, and will remain effective until revised.
Environmental
Review:
On April 30, 2024, the San Francisco Planning Department determined the Project to be statutor ily exempt from environmental review under the CEQA section 21080(b)(8) and the CEQA Guidelines s ection 15273 ( Rates, Tolls, Fares and Charges) (Case Number 2024- 003770ENV) related to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or other charges . The exemption determination can be found here:
https://sfpuc.sharefile.com/public/share/web-
sce04897f2bc845538abaf67ad17461c6
This action constitutes the Approval Action for the project for the purposes of the CEQA pursuant to San Francisco Administrative Code Public Hearing: Adopt CleanPowerSF Rates for FY 2024-25 Commission Meeting Date: May 14, 2024
section 31.04(h)..
Attachments: 1. FY 2024-25 CleanPowerSF Revenue Requirement
2. FY 2024-25 CleanPowerSF Cost Functionalization,
Classification, and Allocation
PUBLIC UTILITIES COMMISSION
City and County of San Francisco
RESOLUTION NO: ____________________
WHEREAS, In accordance with Section 8B.125 of the Charter of the City and County of San Francisco, the Commission retained an independent rate consultant, NewGen Strategies & Solutions, to conduct the 2022 SFPUC Power Rates Study; and WHEREAS, The rate consultant recommended FY 2022-23 and FY 2023 -24 tariffs for CleanPowerSF in the 2022 Power Rates Study Final Report; and WHEREAS, Staff proposed for the Commission to adopt only one year of FY 2022-23 tariffs for CleanPowerSF at the conclusion of the 2022 SFPUC Power Rates Study to adapt to increased volatility in energy markets caused by geopolitical conflict and continued supply chain disruptions from COVID-19; and
WHEREAS, The Commission adopted FY 2022- 23 CleanPowerSF Tariffs in Resolution 22-0094 on May 24, 2022; and
WHEREAS, Staff updated the financial analysis using tools developed in the 2022 SFPUC Power Rates Study , and proposed FY 2023- 24 CleanPowerSF Tariffs for existing schedules based on analysis of CleanPowerSF’s cost of providing service to its customers for the fiscal year; and
WHEREAS, The Commission adopted FY 2023- 24 CleanPowerSF Tariffs in Resolution 23-0101 on May 9, 2023; and
WHEREAS, Staff further updated the financial analysis using tools developed in the 2022 SFPUC Power Rates Study, and proposed FY 2024- 25 CleanPowerSF Tariffs for exis ting schedules based on analysis of CleanPowerSF’s cost of providing service to its customers for the fiscal year; and
WHEREAS, PG&E offers a new rate schedule occasionally after California Public Utilities Commission approval; and
WHEREAS, Upon PG&E’s implementation of a new rate schedule, Staff will continue the practice of set ting CleanPowerSF generation rates by: (1) calculating ratios of PG&E’s generation rate components for the new rate schedule to PG&E’s default rate schedule in the applicable customer class and (2) applying the resulting ratios to CleanPowerSF’s comparable default generation rate schedule in the subject customer class; and WHEREAS, The Rate Fairness Board reviewed the findings and recommendations of staff for FY 2023-24 CleanPowerSF Tariffs on April 10, 2024, and April 29, 2024; and
WHEREAS, The General Manager find s that CleanPowerSF revenues under existing rates will be insufficient to meet revenue requirements of CleanPowerSF program’s 10-Year Financial Plan, and recommen d adjustments to CleanPowerSF rates applicable effective on July 1, 2024; and
WHEREAS, Pursuant to Charter Section 16.112, a Notice of hearing on the proposal to adopt a schedule of rates was published in the official newspaper on April 21, 24, 25, 26, and 28, 2024, and posted on the SFPUC website and at the San Francisco Public Library, as required, for a public hearing on May 14, 2024; and
WHEREAS, Pursuant to the published notice of the intention of the Public Utilities Commission to adopt revised Schedules of CleanPowerSF Rates and Charges to be charged by the Power Enterprise for electric generation service in San Francisco, public meetin gs were held at Rates Fairness Board meetings on March 22, 2024, April 10, 2024, and April 29, 2024, where members of the public were given an opportunity to express their views on the process and revised Schedules of CleanPowerSF Rates; and
WHEREAS, On April 30, 2024, the San Francisco Planning Department determined the Project to be statutorily exempt from environmental review under the CEQA section 21080(b)(8) and the CEQA Guidelines s ection 15273 (Rates, Tolls, Fares and Charges) (Case Number 2024- 003770ENV) related to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or other charges; and
WHEREAS, This Commission hereby finds that adoption of this resolution will establish rates for the purpose of (1) meeting operating expenses, including employee wage rates and fringe benefits; (2) purchasing or leasing supplies, equipment, or materials; (3) meeting financial reserve needs and requirements, and (4) obtaining funds for capital projects necessary to maintain service within existing service areas; and
WHEREAS, Charter section 8B.125 requires the Commission to set rates and charges, subject to rejection by the Board of Supervisors, within 30 days of submission; now, therefore be it
RESOLVED, This Commission hereby adopts the CleanPowerSF Tariffs in the below sections to all CleanPowerSF customers to be effective on July 1, 2024; and be it
Section 1 - Authority and General Purpose
This Resolution is adopted pursuant to Section 8B.125 of the Charter of the City and County of San Francisco for the purpose of establishing an orderly system for the imposition and collection of charges for the operating, maintenance, replacement, debt service and other costs incurred by CleanPowerSF in providing power supply to residential and commercial customers.
Section 2 – Billing Rates for CleanPowerSF
The following Schedules of CleanPowerSF Rates apply to all CleanPowerSF customers. A customer’s CleanPowerSF rate is determined by the rate schedule they sign up for with Pacific Gas & Electric (PG&E); therefore, applicability and eligibility for all rate schedules is determined by PG&E.
“Holidays” for the purpose of the below rate schedules are New Year’s Day, President’s Day, Memorial Day, Independence Day, Labor Day, Veterans Day, Thanksgiving Day, and Christmas Day. The dates will be those on which the holidays are legally observed.
Residential
Schedule E-1: Residential Services
Applies to PG&E rate schedules E-1, E-1-L, EM, EM-L, ES, ES-L, ESR, ESR-L, ET, and ET-L.
Rate Component FY 24-25 Rate
All Energy $0.15169 /kWh
Schedule E-TOU-C: Residential Time-of-Use
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21697/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.15263/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.15825/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.14017/kWh All other hours
Schedule E-TOU-D: Residential Time-of-Use Peak Pricing 5-8pm (Non-Holiday Weekends) Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.24292/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.12131/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.19556/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.15492/kWh All other hours including holidays Schedule E-ELEC: Residential Time-of-Use (Electric Home) Service for Customers with Qualifying Electric Technologies
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.32437/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.21022/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.15828/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.13764/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.11464/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.09927/kWh All other hours
Schedule E-EV: Residential Time-of-Use for Plug-In Electric Vehicle Customers Applies to PG&E rate schedules EV-A and EV-B. Schedule EV-A is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.43508/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.22107/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.15189/kWh All other hours
Winter Energy Charge November 1—April 30
Peak $0.14580/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.10874/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.10874/kWh All other hours
Schedule E-EV-2: Residential Time-of-Use for Plug-In Electric Vehicle Customers Applies to PG&E rate schedule EV2.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.24675/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.19096/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.13962/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.17577/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.16020/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.13090/kWh All other hours
Schedule E-TOU-B: Residential Time-of-Use Service
Schedule E-TOU-B is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.31117/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.15830/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.17951/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.13131/kWh All other hours including holidays Residential SuperGreen Premium
Residential customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 23-24 Rate
SuperGreen $0.01000/kWh
Small General Service
Schedule B-1: Small General Service
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.20246/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.14948/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.12708/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.14300/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.12565/kWh All other hours
Super Off-Peak $0.10798/kWh 9:00am to 2:00pm, every day in March—May Schedule B-1-ST: Small General Service with Storage
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19888/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.15509/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.11822/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.14671/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.13398/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.11129/kWh All other hours
Super Off-Peak $0.09436/kWh 9:00am to 2:00pm, every day in March—May
Schedule B-6: Small General Time-of-Use Service
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21385/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.13388/kWh All other hours
Winter Energy Charge
October 1—May 31
Peak $0.14247/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.12330/kWh All other hours
Super Off-Peak $0.10485/kWh 9:00am to 2:00pm, every day in March—May Schedule A-1-A: Small General Service
Schedule A-1-A is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge $0.15783/kWh May 1—October 31
Winter Energy Charge $0.11383/kWh November 1—April 30
Schedule A-1-B: Small General Service
Schedule A-1-B is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.16429/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.16429/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.13671/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.12997/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.12933/kWh All other hours including holidays
Schedule A-6: Small General Time-of-Use Service
Schedule A-6 is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.22225/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.17002/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.13601/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.12608/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.12533/kWh All other hours including holidays Small Commercial SuperGreen Premium
Small Commercial customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Medium General Service – Low Demand (75-500 kW)
Schedule B-10: Medium General Demand Metered Service
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.21110/kWh
Primary $0.19401/kWh
Transmission $0.17028/kWh
Part-Peak
2:00pm to 4:00pm and 9:00pm to 11:00pm, every
day
Secondary $0.15061/kWh
Primary $0.13685/kWh
Transmission $0.11464/kWh
Off-Peak
All other hours
Secondary $0.11867/kWh
Primary $0.10661/kWh
Transmission $0.08515/kWh
Winter Energy Charge
October 1—May 31
Peak
4:00pm to 9:00pm, every day
Secondary $0.15418/kWh
Primary $0.14043/kWh
Transmission $0.11826/kWh
Off-Peak
All other hours
Secondary $0.11938/kWh
Primary $0.10746/kWh
Transmission $0.08605/kWh
Super Off-Peak
9:00am to 2:00pm, every day in March—May
Secondary $0.08375/kWh
Primary $0.07182/kWh
Transmission $0.05041/kWh
Schedule A-10-A: Medium General Demand-Metered Service, Non-Time-of-Use Service A-10-A is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Secondary $0.14073/kWh
Primary $0.12488/kWh
Transmission $0.10544/kWh
Winter Energy Charge
November 1—April 30
Secondary $0.11966/kWh
Primary $0.10665/kWh
Transmission $0.08887/kWh
Schedule A-10-B: Medium General Demand-Metered Service, Time-of-Use Service Schedule A-10-B is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.15573/kWh
Primary $0.14009/kWh
Transmission $0.12163/kWh
Part-Peak
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.15573/kWh
Primary $0.14009/kWh
Transmission $0.12163/kWh
Off-Peak
All other hours including holidays
Secondary $0.12948/kWh
Primary $0.11527/kWh
Transmission $0.09747/kWh
Winter Energy Charge
November 1-April 30
Part-Peak
8:30am to 9:30pm, Monday through Friday (except
holidays)
Secondary $0.12179/kWh
Primary $0.10801/kWh
Transmission $0.09038/kWh
Rate Component FY 24-25 Rate Time of Use
Off-Peak
All other hours including holidays
Secondary $0.12110/kWh
Primary $0.10736/kWh
Transmission $0.08973/kWh
Medium General Service – Low Demand SuperGreen Premium
Medium General Service – Low Demand customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Medium General Service – High Demand (500-1000 kW)
Schedule B-19: Medium General Demand-Metered Time-of-Use Service Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.16485/kWh
Primary $0.14408/kWh
Transmission $0.13084/kWh
Part-Peak - Energy 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.12496/kWh
Primary $0.11372/kWh
Transmission $0.11808/kWh
Off-Peak - Energy All other hours
Secondary $0.09676/kWh
Primary $0.08732/kWh
Transmission $0.09089/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $27.74/kW
Primary $23.77/kW
Transmission $18.72/kW
Part-Peak - Demand 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $4.03/kW
Primary $3.47/kW
Transmission $4.68/kW
Winter Energy Charge October 1—May 31
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.13951/kWh
Primary $0.12762/kWh
Transmission $0.13255/kWh
Off-Peak - Energy All other hours
Secondary $0.09664/kWh
Primary $0.08750/kWh
Rate Component FY 24-25 Rate Time of Use
Transmission $0.09125/kWh
Super Off-Peak - Energy 9:00am to 2:00pm, every day in March—May Secondary $0.03912/kWh
Primary $0.03040/kWh
Transmission $0.03051/kWh
Winter Demand Charge October 1—May 31
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $3.30/kW
Primary $2.43/kW
Transmission $1.80/kW
Schedule B-19-R/B-19-S: Medium General Demand-Metered Time-of-Use Service, Generation/Storage
Applies to customers on Option R or Option S of PG&E rate schedule B-19.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.28110/kWh
Primary $0.25741/kWh
Transmission $0.22403/kWh
Part-Peak 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.14528/kWh
Primary $0.13365/kWh
Transmission $0.14239/kWh
Off-Peak All other hours
Secondary $0.10670/kWh
Primary $0.09819/kWh
Transmission $0.10015/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.14902/kWh
Primary $0.13602/kWh
Transmission $0.13412/kWh
Off-Peak All other hours
Secondary $0.10664/kWh
Primary $0.09830/kWh
Transmission $0.10037/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.07075/kWh
Primary $0.06241/kWh
Transmission $0.06449/kWh
Schedule E-19: Medium General Demand-Metered Time-of-Use Service Schedule E-19 is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak - Energy 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $0.11313/kWh
Primary $0.09943/kWh
Transmission $0.08873/kWh
Part-Peak - Energy
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.11313/kWh
Primary $0.09943/kWh
Transmission $0.08873/kWh
Off-Peak - Energy
9:30pm to 8:30am, Monday through Friday (except
holidays)
All day, Saturday through Sunday and holidays
Secondary $0.10630/kWh
Primary $0.09290/kWh
Transmission $0.08226/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $9.47/kW
Primary $8.22/kW
Transmission $9.08/kW
Part-Peak - Demand
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $9.47/kW
Primary $8.22/kW
Transmission $9.08/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.10335/kWh
Primary $0.09007/kWh
Transmission $0.07949/kWh
Rate Component FY 24-25 Rate Time of Use
Off-Peak - Energy
9:30pm to 8:30 am, Monday through Friday (except
holidays)
All day, Saturday through Sunday and holidays
Secondary $0.10253/kWh
Primary $0.08931/kWh
Transmission $0.07873/kWh
Medium General Service – High Demand SuperGreen Premium Medium General Service – High Demand customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh.
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Large General Service
Schedule B-20: Service to Customers with Maximum Demands of 1000 Kilowatts or More Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.12091/kWh
Primary $0.11792/kWh
Transmission $0.09917/kWh
Part-Peak - Energy
2:00pm to 4:00pm and 9:00pm to 11:00pm,
every day
Secondary $0.09327/kWh
Primary $0.08855/kWh
Transmission $0.08106/kWh
Off-Peak - Energy
All other hours
Secondary $0.07145/kWh
Primary $0.06805/kWh
Transmission $0.06083/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $26.97/kW
Primary $29.73/kW
Transmission $33.64/kW
Part-Peak - Demand
2:00pm to 4:00pm and 9:00pm to 11:00pm,
every day
Secondary $3.92/kW
Primary $4.08/kW
Transmission $8.01/kW
Winter Energy Charge October 1—May 31
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.10445/kWh
Primary $0.09922/kWh
Transmission $0.09830/kWh
Off-Peak - Energy
All other hours
Secondary $0.07128/kWh
Primary $0.06811/kWh
Transmission $0.05717/kWh
Super Off-Peak - Energy
9:00am to 2:00pm, every day in March—May
Rate Component FY 24-25 Rate Time of Use
Secondary $0.02683/kWh
Primary $0.02395/kWh
Transmission $0.01609/kWh
Winter Demand Charge October 1—May 31
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $3.45/kW
Primary $3.42/kW
Transmission $4.49/kW
Schedule B-20-R/B-20-S: Service to Customers with Maximum Demands of 1000 Kilowatts or More, Solar/Storage
Applies to customers on Option R or Option S of PG&E rate schedule B-20.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.23885/kWh
Primary $0.23780/kWh
Transmission $0.24717/kWh
Part-Peak 2:00pm to 4:00pm & 9:00pm to 11:00pm, every day Secondary $0.12048/kWh
Primary $0.11942/kWh
Transmission $0.13346/kWh
Off-Peak All other hours
Secondary $0.08707/kWh
Primary $0.08753/kWh
Transmission $0.08529/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.12594/kWh
Primary $0.12438/kWh
Transmission $0.13332/kWh
Off-Peak All other hours
Secondary $0.08695/kWh
Primary $0.08757/kWh
Transmission $0.08248/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.05507/kWh
Primary $0.05474/kWh
Transmission $0.05105/kWh
Schedule E-20: Service to Customers with Maximum Demands of 1000 Kilowatts or More Schedule E-20 is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak - Energy 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $0.08582/kWh
Primary $0.08284/kWh
Transmission $0.07116/kWh
Part-Peak - Energy 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.08582/kWh
Primary $0.08284/kWh
Transmission $0.07116/kWh
Off-Peak - Energy All other hours
Secondary $0.08043/kWh
Primary $0.07759/kWh
Transmission $0.06600/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $8.80/kW
Primary $9.40/kW
Transmission $11.20/kW
Part-Park - Demand 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $8.80/kW
Primary $9.40/kW
Transmission $11.20/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07807/kWh
Primary $0.07535/kWh
Transmission $0.06379/kWh
Off-Peak - Energy 9:30pm to 8:30am, Monday through Friday, All day, Saturday through Sunday and holidays
Rate Component FY 24-25 Rate Time of Use
Secondary $0.07743/kWh
Primary $0.07743/kWh
Transmission $0.06318/kWh
Large Commercial SuperGreen Premium
Large Commercial served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Business Electric Vehicles
Schedule BEV-1: Business Electric Vehicles Secondary Voltage Rate Component FY 24-25 Rate Time of Use
Peak Energy Charge $0.26421/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.08948/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.06518/kWh All other hours Schedule BEV-2-S Business Electric Vehicles Secondary Voltage Rate Component FY 24-25 Rate Time of Use
Peak Energy Charge $0.27936/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.08555/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.06135/kWh All other hours Schedule BEV-2-P Business Electric Vehicles Primary or Transmission Voltage Rate Component FY 24-25 Rate Time of Use
Peak Energy Charge $0.27994/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.08591/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.06195/kWh All other hours Business Electric Vehicles SuperGreen Premium
Business Electric Vehicles served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Agriculture
Schedule AG-A: Time-of-Use Agricultural Power
Applies to PG&E rate schedules AG-A1 and AG-A2.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.22898/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.11329/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11008/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08452/kWh All other hours
Schedule AG-B: Time-of-Use Agricultural Power
Rate Component FY 24-25 Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21813/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.11267/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.10810/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08565/kWh All other hours
Schedule AG-C: Time-of-Use Agricultural Power
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.10993/kWh 5:00pm to 8:00pm, every day Off-Peak - Energy $0.08230/kWh All other hours
Summer Demand Charge June 1—September 30
Peak - Demand $9.40/kW 5:00pm to 8:00pm, every day
Winter Energy Charge October 1—May 31
Peak $0.09621/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.07229/kWh All other hours
Schedule AG-F-A: Flexible Off-Peak Time-of-Use Agricultural Power Customers on this tariff schedule can choose one of three options for their off-peak time-of-use period: Option 1) Wednesday and Thursday; Option 2) Saturday and Sunday, or Option 3) Monday and Friday. Applies to customers on all three peak time-of-use periods.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.20315/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.12574/kWh All hours, Option 1, 2 or 3
Winter Energy Charge
October 1—May 31
Peak $0.11551/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.08895/kWh All hours, Option 1, 2 or 3
Schedule AG-F-B: Flexible Off-Peak Time-of-Use Agricultural Power Customers on this tariff schedule can choose one of three options for their off-peak time-of-use period: Option 1) Wednesday and Thursday; Option 2) Saturday and Sunday, or Option 3) Monday and Friday. Applies to customers on all three peak time-of-use periods.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19135/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.12123/kWh All other hours, Option 1, 2 or 3 Winter Energy Charge
October 1—May 31
Peak $0.11082/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.08803/kWh All other hours, Option 1, 2 or 3
Schedule AG-F-C: Flexible Off-Peak Time-of-Use Agricultural Power Customers on this tariff schedule can choose one of three options for their off-peak time-of-use period: Option 1) Wednesday and Thursday; Option 2) Saturday and Sunday, or Option 3) Monday and Friday. Applies to customers on all three peak time-of-use periods.
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.10697/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.08371/kWh All other hours, Option 1, 2 or 3 Summer Demand Charge June 1—September 30
Peak - Demand $9.40/kW
Winter Energy Charge October 1—May 31
Peak - Energy $0.09580/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.07530/kWh All other hours, Option 1, 2 or 3 Agriculture SuperGreen Premium
Agriculture customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Lighting and Traffic Controls
Schedule LS-1: Street, Highway, and Outdoor Area Lighting Applies to PG&E rate schedules SL-1, SL-2, SL-3, and OL-1.
Rate Component FY 24-25 Rate
All Energy $0.13472/kWh
Schedule TC-1: Traffic Control Service
Rate Component FY 24-25 Rate
All Energy $0.13937/kWh
Schedule A-15: Direct-Current Lighting Service
Schedule A-15 is a legacy rate that is closed to new customers.
Rate Component FY 24-25 Rate Time of Use
Summer Energy $0.13927/kWh June 1-September 30
Winter Energy $0.11889/kWh October 1-May 31
Lighting & Traffic Control SuperGreen Premium
Lighting and Traffic customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 24-25 Rate
SuperGreen $0.00500/kWh
Standby Charges
Standby rates apply to Full Standby customers. All partial standby customers are billed at their Otherwise Applicable Schedule (OAS) rate. SuperGreen premium charged at OAS rate premium.
Schedule SB: Standby Service
Rate Component FY 24-25 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.11277/kWh
Primary $0.11277/kWh
Transmission $0.09792/kWh
Part-Peak 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.09966/kWh
Primary $0.09966/kWh
Transmission $0.08530/kWh
Off-Peak All other hours
Secondary $0.08508/kWh
Primary $0.08508/kWh
Transmission $0.07125/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.12594/kWh
Primary $0.12594/kWh
Transmission $0.13332/kWh
Off-Peak All other hours
Secondary $0.08631/kWh
Primary $0.08631/kWh
Transmission $0.08248/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.03921/kWh
Primary $0.03921/kWh
Transmission $0.02593/kWh
Reservation Charge Year-Round
Secondary $0.38/kW
Primary $0.38/kW
Transmission $0.22/kW
Section 3 – Net Energy Metering Tariff
Applicability
This Schedule Net Energy Metering (NEM-CleanPowerSF) is applicable to enrolled CleanPowerSF customers who use a Renewable Electrical Generation Facility.
To be eligible, the CleanPowerSF customer must satisfy the requirements of, and take electricity service on, a Pacific Gas and Electric Company’s (PG&E) net energy metering Electric Tariff Schedule, including NEM, NEM25, or other NEM programs (PG&E NEM), including PG&E’s Electric Schedule Net Billing Tariff (NBT); and install a Renewable Electrical Generation Facility.
This Schedule is available on a first-come, first-served basis to eligible CleanPowerSF customers that provide PG&E with a completed PG&E NEM or NBT Application and comply with all PG&E NEM or NBT requirements of the applicable NEM or NBT Tariff, including the following PG&E Electric Schedules: NEMV or NEM2V (Virtual Net Energy Metering), NEMVMASH or NEM2VMSH (Virtual Net Energy Metering for Multifamily Affordable Housing), NEM2VSOM (Virtual Net Energy Metering Solar on Multifamily Affordable Housing (SOMAH) Properties), NEMA or NEM2A (customer-generator with a Load Aggregation Arrangement), Multiple Tariff facilities as described by PG&E Electric Schedule NEM and NEM2 and other NEM electric schedules.
PG&E NEM Tariffs and Electric Schedule NBT Terms and Conditions Apply. CleanPowerSF NEM customers are also subject to the terms, conditions, and billing procedures of PG&E for services other than electric generation.
If CleanPowerSF adopts a successor tariff, CleanPowerSF customers taking service on PG&E NBT will be transitioned to the applicable successor tariff.
Territory
This schedule is available throughout the City and County of San Francisco Definitions
“Annual True-up Period”
The twelve-month period commencing in May of each year.
5 For more information see PG&E’s NEM tariffs by selecting the “Electric Rate Schedules” link at:
https://www.pge.com/tariffs/index.page
“Net Electricity Consumer”
NEM-CleanPowerSF customer that produces less electricity from its Renewable Electrical Generation Facility during an Annual True-up Period than is delivered by CleanPowerSF to the customer during the same period.
“Net Electricity Generator”
A NEM-CleanPowerSF customer that produces more electricity from its Renewable Electrical Generation Facility during an Annual True-up Period than is delivered by CleanPowerSF to the customer during the same period.
“Renewable Electrical Generation Facility”
A facility that generates electricity from a renewable source listed in California Public Resources Code Section 25741(a)(1)
6 and that is:
1. Located on the customer’s owned, rented, or leased premises;
2. Equal to or less than 1 MW (AC) in design capacity;
3. Interconnected for parallel operation with the PG&E distribution system; and
4. Sized principally to offset part or all the customer’s own on-site electrical requirements.
Rates, Billing and Annual True-Up Process
Rates and Monthly Billing for CleanPowerSF Service
1. Each NEM-CleanPowerSF customer will receive a monthly billing statement reflecting net electricity consumption/production, charges incurred, credits generated during the current billing period, and remaining credits from previous billing cycles. The monetary value of any excess production during a monthly billing cycle shall be calculated as follows:
a. For Customers on a Flat Rate Tariff: If during a monthly billing cycle, the quantity of electricity produced by the customer’s Renewable Electrical Generation Facility and delivered to CleanPowerSF is greater than the quantity of electricity delivered to t he customer by CleanPowerSF, the customer will receive a bill credit for the excess kilowatt-hours (kWh) produced. The value of the excess kWh produced shall be calculated according to the electricity usage charges of the customer’s otherwise applicable rate schedule.
b. For Customers on a Time of Use (“TOU”) Tariff: If during any TOU period, the quantity of electricity produced by the customer’s Renewable Electrical Generation Facility and delivered to CleanPowerSF is greater than the quantity of electricity delivered to the customer by CleanPowerSF, the value of the excess kWh produced shall be calculated based on the applicable TOU rate when the excess kWh were
6 An eligible facility is one that generates electricity by using one of the following methods: biomass; solar thermal; solar photovoltaic; wind; geothermal; fuel cells using renewable fuels; qualifying small hydroelectric generation; digester gas; municipal solid waste conversion; landfill gas; ocean wave; ocean thermal; or tidal current.
produced. If the value of excess kWhs produced exceeds the sum of CleanPowerSF electric generation charges, across all applicable TOU periods during the billing cycle, the customer will receive a bill credit in the amount of the excess value.
2. All CleanPowerSF charges under the customer’s otherwise applicable rate schedule shall be in effect and all charges shall be due and payable on the due date identified in each billing statement.
a. Residential and small commercial NEM -CleanPowerSF customers may elect to receive Annual Billing, under which CleanPowerSF charges for the preceding Annual True-Up Period become due once per year, after the Annual True- Up (see Section IV.B below). Eligible small commercial customers are defined as those having a maximum monthly peak demand of less than 20 kilowatts.
3. Any bill credits reflected on the customer’s bill will be carried over for use in subsequent billing period(s) during the same Annual True-up Period in which they are accrued until such credits are exhausted or reset pursuant to the “Annual True-Up and Settlement” item 2 below.
Annual True-Up and Settlement
1. On an annual basis, CleanPowerSF will determine whether a participating customer is a Net Electricity Consumer or a Net Electricity Generator during the preceding Annual True-up Period. Generally, for new customers, the Annual True -up Period for the first year will cover the period starting on the date that the customer commenced service under this NEM Schedule through the customer’s April billing cycle. For those customers for whom CleanPowerSF has insufficient usage data to implement a True Up, CleanPowerSF will perform the True Up at a subsequent Annual True -up Period when sufficient usage data is available.
2. For Net Electricity Consumers and Net Electricity Generators at the end of the Annual True-up Period, any bill credit balances remaining at that time will be reset to zero for the beginning of the next True-Up Period.
3. If the customer is a Net Electricity Generator at the end of the Annual True-up Period, the customer is eligible to receive Net Surplus Electricity Compensation for any net electricity production calculated over the prior twelve-months.
4. The Net Surplus Electricity Compensation rate for each kilowatt -hour of net electricity production during the True-up Period is:
Rate Code FY 24-25 Rate
All Energy $0.0893/kWh
5. CleanPowerSF will provide Net Electricity Generators their Net Surplus Electricity Compensation at the end of the Annual True -Up Period by bill credit that will apply to future CleanPowerSF charges. C ustomers may elect to receive their Net Surplus Electricity Compensation by check. Customers electing to receive a check must indicate their preference within 60 days of the first bill following the end of the Annual True -Up Period.
6. Per California Public Utilities Code Section 2827(h)(4)(B), aggregated NEM cust omers are “permanently ineligible to receive net surplus electricity compensation.” Thus,
CleanPowerSF aggregated NEM accounts are ineligible to receive Net Surplus Compensation
Renewable Energy Credits and Environmental Attributes
The customer will retain ownership of all RECs and environmental attributes associated with its usage of electricity produced by the eligible Renewable Electrical Generation Facility.
Termination of CleanPowerSF Service
If a NEM-CleanPowerSF customer opts-out of the CleanPowerSF program and returns to PG&E bundled service, or otherwise closes their CleanPowerSF account, that customer may request that CleanPowerSF settle any remaining net generation credits on the account, provided that the request is received within 90 calendar days of the return to PG&E service or the account closure.
For customers with remaining net bill credit balances credits, CleanPowerSF will issue a check for the amount of any net bill credit balances remaining at the time of the return to PG&E service or the account closure.
Section 4 – Definitions
For the purpose of this Resolution, the following definitions shall apply unless the context specifically dictates otherwise.
“City”
The City and County of San Francisco
“Commission”
The San Francisco Public Utilities Commission
“Customer”
Any person, firm, corporation, partnership, trust, or any other entity including, but not limited to, local, state and federal governments utilizing the services of CleanPowerSF. “Customer Class”
Customers with the same or similar usage characteristics are grouped into Customer Classes for purposes of cost allocation and rate setting.
“General Manager”
The General Manager of the Public Utilities Commission or his or her designee. “Power Charge Indifference Adjustment (PCIA)”
The Power Charge Indifference Adjustment (PCIA) is a charge to recover PG&E’s above-market costs for generation resources acquired prior to a customer’s switch to a third- party electric generation provider.
“Franchise Fee Surcharge (FFS)”
The Franchise Fee surcharge (FFS) is levied by the California Public Utilities Commission and collected by PG&E on behalf of cities and counties in PG&E’s service territory for all customers.
The money is collected through the bundled generation rate and used to pay munici palities for the purpose of using city streets.
Section 5 – New Rate Schedule Methodology
When PG&E implements a new rate schedule effective at a date prior to CleanPowerSF’s planned rates adoption, CleanPowerSF will create a temporary generation rate for the new schedule using the following methodology:
1. Calculate ratios of PG&E generation rates of the new rate schedule to that of its default rate schedule in the applicable customer class, and
2. Apply resulting ratios in Step 1 to CleanPowerSF rates of comparable default rate schedule in the applicable customer class.
The temporary rates implemented under this section will remain in effect until CleanPowerSF’s next comprehensive rate adoption.
Section 6 – Severability
If any section, subsection, subdivision, paragraph, sentence, clause or phrase of this resolution or any part hereof, is for any reason held to be unconstitutional or invalid or ineffective by any court of competent jurisdiction, such decision shall not affect the validity or effectiveness of the remaining portions of this resolution or any part hereof. The Commission hereby declares that it would have adopted each section , subsection, subdivision, paragraph, sentence, clause or phrase thereof irrespective of the fact that any one or more se ctions, subsections, subdivisions, paragraphs, sentences, clauses or phrases be declared unconstitutional or invalid or ineffective.
Section 7 – Effective Date
The rates adopted pursuant to this resolution shall be effective thirty days following approval of this resolution, unless the rates are rejected by the San Francisco Board of Supervisors pursuant to Section 8B.125 of the City's Charter, and shall remain i n effect until repealed, modified or superseded. These rates will be applied to meter readings on or after July 1, 2024.
I hereby certify that the foregoing resolution was adopted by the Public Utilities Commission at its meeting of May 14, 2024.
______________________________________
Secretary, Public Utilities Commission
San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Revenue Requirement
FYE 2025
Supply Costs
Contracted Energy Non‐Renewables 92,208,091 $
Contracted Energy Renewables
sPower Raceway 9,308,430 $
NextEra Blythe 4,971,963 $
Terragen Voyager 7,838,223 $
Terragen Oasis 9,050,600 $
EDF Maverick 8,081,062 $
Calpine Geysers (End 12/2029) 25,754,400 $
HHP Sunset (end 11/25) 34,455 $
CC Power Geothermal 228,777 $
Gonzaga Ridge Wind ‐$
Paulsell 2.0 (20 MW PV, 15 MW Storage) 2,837,920 $
‐$
Contracted Energy Renewables Total 68,105,830 $
Spot Market Energy 77,268,730 $
Resource Adequacy
Resource Adequacy Contracts 57,325,559 $
Resource Adequacy Net Short 1,951,906 $
Resource Adequacy Total 59,277,464 $
Renewable & GHG‐Free Attributes
Contracted RECs 27,733,933 $
Incremental RPS RECs ‐$
Voluntary RECs (incl. losses) ‐$
Incremental Super Green (incl. losses) ‐$
GHG‐Free Attribute Contracts 2,165,000 $
GHG‐Free Attribute Net Short 10,744,474
$
Renewable & GHG‐Free Attributes Total 40,643,407 $
Other Purchased Power & Supply Costs
CAISO Services 6,000,000 $
Scheduling Coordinator (APX Collateral) ‐$
Other Purchased Power & Supply Costs Total 6,000,000 $
Contingency 30,516,279 $
Total Supply Costs 374,019,801 $
San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Revenue Requirement
FYE 2025
Operating and Other Costs
Labor/Personnel 8,915,378 $
Services of Bureaus 7,492,430 $
Non‐Personnel Services
Professional Services 2,483,296 $
Calpine Data Manager Fees 4,994,604 $
PG&E Service Fees 1,765,769 $
Letter of Credit 471,276 $
Miscellaneous 1,221,493 $
Materials and Supplies 137,000 $
Services of Other Departments
Hetch Hetchy ‐$
City Attorney 1,200,000 $
Repro (Marketing) 639,723 $
All Other Departments 240,608 $
Working Capital Interest ‐$
Total Operating Costs 29,561,57 7$
Uncollectible 4,308,846 $
Working Capital Principal ‐$
Non‐Debt Capital Expenditures 7,673,070 $
Margin 29,250,001 $
Total Expenditures ‐ w/o Margin 415,563,294
Total Expenditures 444,813,295$
(Less) Wholesale Revenue (11,121,627) $
(Less) Interest and Other Revenue (2,807,062) $
Retail Revenue Requirement 430,884,606$
CleanPowerSF Metrics
Beginning Fund Balance 112,230,156 $
EOY Fund Balance 141,480,158 $
Days of Cash on Hand 138
San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Functionalization
FY 2025 Expenses Allocation Power Supply Customer Total Supply Costs
Contracted Energy Non‐Renewables 92,208,091 $ Power Supply 92,208,091$ ‐ $ 92,208,091$ Contracted Energy Renewables
sPower Raceway 9,308,430 $ Power Supply 9,308,430$ ‐ $ 9,308,430$ NextEra Blythe 4,971,963 $ Power Supply 4,971,963$ ‐ $ 4,971,963$ Terragen Voyager 7,838,223 $ Power Supply 7,838,223$ ‐ $ 7,838,223$ Terragen Oasis 9,050,600 $ Power Supply 9,050,600$ ‐ $ 9,050,600$ EDF Maverick 8,081,062 $ Power Supply 8,081,062$ ‐ $ 8,081,062$ Calpine Geysers (End 12/2029) 25,754,400 $ Power Supply 25,754,400$ ‐ $ 25,754,400$ HHP Sunset (end 11/25) 34,455 $ Power Supply 34,455$ ‐ $ 34,455$ CC Power Geothermal 228,777 $ Power Supply 228,777$ ‐ $ 228,777$ Paulsell 2.0 (20 MW PV, 15 MW Storage) 2,837,920 $ Power Supply 2,837,920$ ‐ $ 2,837,920$ Contracted Energy Renewables Total 68,105,830 $ 68,105,830$ ‐ $ 68,105,830$ Firming and Shaping 77,268,730 $ Power Supply 77,268,730$ ‐ $ 77,268,730$ Resource Adequacy
Resource Adequacy Contracts 57,325,559 $ Power Supply 57,325,559$ ‐ $ 57,325,559$ Resource Adequacy Net Short 1,951,906 $ Power Supply 1,951,906$ ‐ $ 1,951,906$ Resource Adequacy Total 59,277,464 $ 59,277,464$ ‐ $ 59,277,464$ Renewable & GHG‐Free Attributes
Contracted RECs 27,733,933 $ Power Supply 27,733,933$ ‐ $ 27,733,933$ GHG‐Free Attribute Contracts 2,165,000 $ Power Supply 2,165,000$ ‐ $ 2,165,000$ GHG‐Free Attribute Net Short 10,744,474 $ Power Supply 10,744,474$ ‐ $ 10,744,474$ Renewable & GHG‐Free Attributes Total 40,643,407 $ 40,643,407$ ‐ $ 40,643,407$ Other Purchased Power & Supply Costs
CAISO Services 6,000,000 $ Power Supply 6,000,000$ ‐ $ 6,000,000$ Other Purchased Power & Supply Costs Total 6,000,000 $ 6,000,000$ ‐ $ 6,000,000$ Contingency 30,516,279 $ Power Supply 30,516,279$ ‐ $ 30,516,279$ Total Supply Costs 374,019,801 $ 374,019,801$ ‐ $ 374,019,801$ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Functionalization
FY 2025 Expenses Allocation Power Supply Customer Total Operating and Other Costs
Labor/Personnel 8,915,378 $ Labor 3,407,182$ 5,508,196$ 8,915,378$ Services of Bureaus 7,492,430 $ Labor 2,863,375$ 4,629,055$ 7,492,430$ Non‐Personnel Services
Professional Services 2,483,296 $ Prof. Services 1,818,845$ 664,451$ 2,483,296$ Calpine Data Manager Fees 4,994,604 $ Customer ‐$ 4,994,604$ 4,994,604$ PG&E Service Fees 1,765,769 $ Customer ‐$ 1,765,769$ 1,765,769$ Letter of Credit 471,276 $ Power Supply 471,276$ ‐ $ 471,276$ Miscellaneous 1,221,493 $ Rev Req 1,135,844$ 85,649$ 1,221,493$ Materials and Supplies 137,000 $ Labor 52,357$ 84,643$ 137,000$ Services of Other Departments
Hetch Hetchy ‐$ HHP Labor ‐$ ‐ $ ‐ $ City Attorney 1,200,000 $ City Attorney 792,232$ 407,768$ 1,200,000$ Repro (Marketing) 639,723 $ Customer ‐$ 639,723$ 639,723$ All Other Departments 240,608 $ Labor 91,953$ 148,655$ 240,608$ Total Operating Costs 29,561,577 $ 10,633,062$ 18,928,515$ 29,561,577$ Uncollectible 4,308,846 $ Customer ‐$ 4,308,846$ 4,308,846$ Non‐Debt Capital Expenditures 7,673,070 $ Capital 1,771,768$ 5,901,302$ 7,673,070$ Margin 29,250,001 $ Rev Req 27,199,036$ 2,050,965$ 29,250,001$ (Less) Other Revenues
Wholesale (11,121,627) $ Power Supply (11,121,627)$ ‐ $ (11,121,627)$ Interest and Other Revenues (2,807,062) $ Rev Req (2,610,235)$ (196,827)$ (2,807,062)$ Revenue Requirement from Rates 430,884,606 $ 399,891,805$ 30,992,801$ 430,884,606$ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Functionalization
FY 2025 Expenses Allocation Power Supply Customer Total Derived Allocators
384,652,863$ 18,928,515$ 403,581,378$
Total Operations & Maintenance Expense Total O&M 95% 5% 100% 385,288,787$ 29,053,014$ 414,341,801$
Revenue Requirement Rev Req 93% 7% 100%
2,572,748$ 4,159,215$ 6,731,963$
Labor Expense Labor 38% 62% 100%
557,244$ 108,007$ 665,251$
HHP Labor Expense HHP Labor 84% 16% 100%
751,226$ 386,662$ 1,137,888$
City Attorney Expense City Attorney 66% 34% 100%
179,298$ 65,500$ 244,798$
Professional Services Prof. Services 73% 27% 100%
438,377$ 1,460,120$ 1,898,497$
Capital Capital 23% 77% 100%
San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Power Supply Line Item FY 2025 Expenses
Adjustment to Move
SG‐Related Renew PPA
RA Costs
FY 2025 After
Additional
Adjustments Allocation Green Capacity
Super Green
Capacity
Green and
SuperGreen Fixed
Charges Green Energy
Super Green
Energy
SuperGreen
Firming &
Shaping
Green & SuperGreen
Other Energy Costs Total
Supply Costs
Contracted Energy Non‐Renewables 92,208,091 $ ‐ $ 92,208,091$ Green ‐$ ‐ $ ‐ $ 92,208,091$ ‐ $ ‐ $ ‐ $ 92,208,091$ Contracted Energy Renewables
sPower Raceway 9,308,430 $ (1,407,115)$ 7,901,315$ sPower SG ‐$ ‐ $ ‐ $ 6,795,131$ 1,106,184$ ‐ $ ‐ $ 7,901,315$ NextEra Blythe 4,971,963 $ (583,480)$ 4,388,483$ Blythe SG ‐$ ‐ $ ‐ $ 3,379,132$ 1,009,351$ ‐ $ ‐ $ 4,388,483$ Terragen Voyager 7,838,223 $ (896,240)$ 6,941,983$ Voyager SG ‐$ ‐ $ ‐ $ 4,373,449$ 2,568,534$ ‐ $ ‐ $ 6,941,983$ Terragen Oasis 9,050,600 $ (1,078,770)$ 7,971,830$ Oasis SG ‐$ ‐ $ ‐ $ 5,500,563$ 2,471,267$ ‐ $ ‐ $ 7,971,830$ EDF Maverick 8,081,062 $ (539,805)$ 7,541,257$ Maverick SG ‐$ ‐ $ ‐ $ 6,560,893$ 980,363$ ‐ $ ‐ $ 7,541,257$ Calpine Geysers (End 12/2029) 25,754,400 $ ‐ $ 25,754,400$ Calpine SG ‐$ ‐ $ ‐ $ 25,754,400$ ‐ $ ‐ $ ‐ $ 25,754,400$ HHP Sunset (end 11/25) 34,455 $ ‐ $ 34,455$ Sunset SG ‐$ ‐ $ ‐ $ ‐ $ 34,455$ ‐ $ ‐ $ 34,455$ CC Power Geothermal 228,777 $ ‐ $ 228,777$ Calpine SG ‐$ ‐ $ ‐ $ 228,777$ ‐ $ ‐ $ ‐ $ 228,777$ Paulsell 2.0 (20 MW PV, 15 MW Storage) 2,837,920 $ ‐ $ 2,837,920$ Crow Creek SG ‐$ ‐ $ ‐ $ 2,837,920$ ‐ $ ‐ $ ‐ $ 2,837,920$ Contracted Energy Renewables Total 68,105,830 $ (4,505,410)$ 63,600,420$ ‐ $ ‐ $ ‐ $ 55,430,265$ 8,170,155$ ‐ $ ‐ $ 63,600,420$
Firming and Shaping 77,268,730 $ ‐ $ 77,268,730$ Firm & Shape ‐$ ‐ $ ‐ $ 76,365,929$ ‐ $ 902,801$ ‐ $ 77,268,730$
Resource Adequacy
Resource Adequacy Contracts 57,325,559 $ ‐ $ 57,325,559$ Capacity Split 51,174,813$ 6,150,745$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 57,325,559$ Resource Adequacy Net Short 1,951,906 $ ‐ $ 1,951,906$ Capacity Split 1,742,476$ 209,430$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 1,951,906$ NextEra ‐ Blythe IV (10/20) (90%) +9k/mo ‐$ 583,480$ 583,480$ Capacity Split 520,876$ 62,604$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 583,480$ EDF ‐ Maverick (12/21) (100%) ‐$ 539,805$ 539,805$ Capacity Split 481,887$ 57,918$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 539,805$ sPower ‐ Raceway (100%) ‐$ 1,407,115$ 1,407,115$ Capacity Split 1,256,139$ 150,976$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 1,407,115$ Terragen Voyager (90%) ‐$ 896,240$ 896,240$ Capacity Split 800,078$ 96,162$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 896,240$ Terragen Oasis (90%) ‐$ 1,078,770$ 1,078,770$ Capacity Split 963,023$ 115,747$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 1,078,770$ Resource Adequacy Total 59,277,464 $ 4,505,410$ 63,782,874$ 56,939,291$ 6,843,583$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 63,782,874$ Renewable & GHG‐Free Attributes
Contracted RECs 27,733,933 $ ‐ $ 27,733,933$ Green ‐$ ‐ $ ‐ $ 27,733,933$ ‐ $ ‐ $ ‐ $ 27,733,933$ GHG‐Free Attribute Contracts 2,165,000 $ ‐ $ 2,165,000$ Green ‐$ ‐ $ ‐ $ 2,165,000$ ‐ $ ‐ $ ‐ $ 2,165,000$ GHG‐Free Attribute Net Short 10,744,474 $ ‐ $ 10,744,474$ Green ‐$ ‐ $ ‐ $ 10,744,474$ ‐ $ ‐ $ ‐ $ 10,744,474$ Renewable & GHG‐Free Attributes Total 40,643,407 $ ‐ $ 40,643,407$ ‐ $ ‐ $ ‐ $ 40,643,407$ ‐ $ ‐ $ ‐ $ 40,643,407$ Other Purchased Power & Supply Costs
CAISO Services 6,000,000 $ ‐ $ 6,000,000$ Other Energy ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 6,000,000$ 6,000,000$ Other Purchased Power & Supply Costs Total 6,000,000$ ‐ $ 6,000,000$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 6,000,000$ 6,000,000$ Contingency 30,516,279 $ ‐ $ 30,516,279$ PS Cont 5,058,392$ 607,972$ ‐ $ 23,510,859$ 725,823$ 80,203$ 533,030$ 30,516,279$ Total Supply Costs 374,019,801 $ ‐ $ 374,019,801$ 61,997,683$ 7,451,555$ ‐ $ 288,158,551$ 8,895,977$ 983,004$ 6,533,030$ 374,019,801$ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Power Supply Line Item FY 2025 Expenses
Adjustment to Move
SG‐Related Renew PPA
RA Costs
FY 2025 After
Additional
Adjustments Allocation Green Capacity
Super Green
Capacity
Green and
SuperGreen Fixed
Charges Green Energy
Super Green
Energy
SuperGreen
Firming &
Shaping
Green & SuperGreen
Other Energy Costs Total
Operating and Other Costs
Labor/Personnel 3,407,182 $ ‐ $ 3,407,182$ Fixed Charges ‐$ ‐ $ 3,407,182$ ‐ $ ‐ $ ‐ $ ‐ $ 3,407,182$ Services of Bureaus 2,863,375 $ ‐ $ 2,863,375$ Fixed Charges ‐$ ‐ $ 2,863,375$ ‐ $ ‐ $ ‐ $ ‐ $ 2,863,375$ Non‐Personnel Services
Professional Services 1,818,845 $ ‐ $ 1,818,845$ Fixed Charges ‐$ ‐ $ 1,818,845$ ‐ $ ‐ $ ‐ $ ‐ $ 1,818,845$ Letter of Credit 471,276 $ ‐ $ 471,276$ Fixed Charges ‐$ ‐ $ 471,276$ ‐ $ ‐ $ ‐ $ ‐ $ 471,276$ Miscellaneous 1,135,844 $ ‐ $ 1,135,844$ Fixed Charges ‐$ ‐ $ 1,135,844$ ‐ $ ‐ $ ‐ $ ‐ $ 1,135,844$ Materials and Supplies 52,357 $ ‐ $ 52,357$ Fixed Charges ‐$ ‐ $ 52,357$ ‐ $ ‐ $ ‐ $ ‐ $ 52,357$ Services of Other Departments
Hetch Hetchy ‐$ ‐ $ ‐ $ Fixed Charges ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ City Attorney 792,232 $ ‐ $ 792,232$ Fixed Charges ‐$ ‐ $ 792,232$ ‐ $ ‐ $ ‐ $ ‐ $ 792,232$ All Other Departments 91,953 $ ‐ $ 91,953$ Fixed Charges ‐$ ‐ $ 91,953$ ‐ $ ‐ $ ‐ $ ‐ $ 91,953$ Total Operating Costs 10,633,062 $ ‐ $ 10,633,062$ ‐ $ ‐ $ 10,633,062$ ‐ $ ‐ $ ‐ $ ‐ $ 10,633,062$ Uncollectible ‐$ ‐ $ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Working Capital Principal ‐$ ‐ $ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Non‐Debt Capital Expenditures 1,771,768 $ 1,771,768$ Capital ‐$ ‐ $ ‐ $ ‐ $ 1,771,768$ ‐ $ ‐ $ 1,771,768$ Margin 27,199,036 $ 27,199,036$ Rev Req 4,363,793$ 524,488$ 748,423$ 20,282,441$ 750,864$ 69,190$ 459,836$ 27,199,036$ (Less) Other Revenues
Wholesale (11,121,627) $ (11,121,627)$ Capacity Split (9,928,332)$ (1,193,295)$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ (11,121,627)$ Interest and Other Revenues (2,610,235) $ (2,610,235)$ Rev Req (418,784)$ (50,334)$ (71,825)$ (1,946,464)$ (72,059)$ (6,640)$ (44,130)$ (2,610,235)$ Revenue Requirement from Rates 399,891,805 $ ‐ $ 413,623,667$ 56,014,360$ 6,732,415$ 11,309,661$ 306,494,528$ 11,346,550$ 1,045,554$ 6,948,737$ 399,891,805$ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Power Supply Line Item FY 2025 Expenses
Adjustment to Move
SG‐Related Renew PPA
RA Costs
FY 2025 After
Additional
Adjustments Allocation Green Capacity
Super Green
Capacity
Green and
SuperGreen Fixed
Charges Green Energy
Super Green
Energy
SuperGreen
Firming &
Shaping
Green & SuperGreen
Other Energy Costs Total
Direct Allocators
100 0 0 0 0 1
Green Capacity Purchases Green Capacity 100% 0% 0% 0% 0% 0% 0% 100% 001 0 0 0 0 1
Fixed Market Charges Fixed Charges 0% 0% 100% 0% 0% 0% 0% 100% 000 1 0 0 0 1
Fixed Market Charges Green 0% 0% 0% 100% 0% 0% 0% 100%
000 0 1 0 0 1
Fixed Market Charges SuperGreen 0% 0% 0% 0% 100% 0% 0% 100% 000 0 0 0 1 1
Other Energy Costs Other Energy 0% 0% 0% 0% 0% 0% 100% 100% 3,071,317,808 369,144,359 3,440,462,167 Capacity Split Allocator Capacity Split 89% 11% 0% 0% 0% 0% 0% 100% 0 0 0 76,365,929 $ 0 902,801$ 0 77,268,730 Firming & Shaping Allocator Firm & Shape 0% 0% 0% 99% 0% 1% 0% 100% 56,939,291$ 6,843,583$ ‐ $ 264,647,692$ 8,170,155$ 902,801$ 6,000,000$ 343,503,521$ Power Supply Contigency Allocator PS Cont 17% 2% 0% 77% 2% 0% 2% 100% 0% 100% 0 0 0% 0% 0 1
Sunset SuperGreen CapacityAllocator Sunset SG Cap 0% 100% 0% 0% 0% 0% 0% 100% 100% 0% 0 0 0 0 0 1
Calpine Geyers SuperGreen Capacity Allocator Calpine SG Cap 100% 0% 0% 0% 0% 0% 0% 100% 100% 0% 0 0 0 0 0 1
Crow Creek SuperGreen Capacity Allocator Crow Creek SG Cap 100% 0% 0% 0% 0% 0% 0% 100% 89% 11% 0 0% 0% 0% 0 1
Blythe SuperGreen Capacity Allocator Blythe SG Cap 89% 11% 0% 0% 0% 0% 0% 100% 87% 13% 0 0% 0% 0% 0 1
EDF Maverick SG Allocator Maverick SG Cap 87% 13% 0% 0% 0% 0% 0% 100% 86% 14% 0 0% 0% 0% 0 1
sPower ‐ Raceway SuperGreen Capacity Allocator sPower SG Cap 86% 14% 0% 0% 0% 0% 0% 100% 63% 37% 0 0% 0% 0% 0 1
Terragen Voyager SuperGreen Capacity Allocator Voyager SG Cap 63% 37% 0% 0% 0% 0% 0% 100% 69% 31% 0 0% 0% 0% 0 1
Terragen Oasis SuperGreen Capacity Allocator Oasis SG Cap 69% 31% 0% 0% 0% 0% 0% 100% 100% 0 0 0% 0% 0% 0 1
Calpine Geysers Xtension SuperGreen Capacity Allocator Calpine X SG Cap 100% 0% 0% 0% 0% 0% 0% 100% 0% 0 0 0 100% 0% 0 1
Sunset SuperGreen Allocator Sunset SG 0% 0% 0% 0% 100% 0% 0% 100% 000 1 0 0 0 1
Calpine Geyers SuperGreen Allocator Calpine SG 0% 0% 0% 100% 0% 0% 0% 100% 000 1 0 0 0 1
Crow Creek SuperGreen Allocator Crow Creek SG 0% 0% 0% 100% 0% 0% 0% 100% 0 0 0 77% 23% 0% 0 1
Blythe SuperGreen Allocator Blythe SG 0% 0% 0% 77% 23% 0% 0% 100% 0 0 0 87% 13% 0% 0 1
EDF Maverick SG Allocator Maverick SG 0% 0% 0% 87% 13% 0% 0% 100% 0 0 0 86% 14% 0% 0 1
sPower ‐ Raceway SuperGreen Allocator sPower SG 0% 0% 0% 86% 14% 0% 0% 100% 0 0 0 63% 37% 0% 0 1
Terragen Voyager SuperGreen Allocator Voyager SG 0% 0% 0% 63% 37% 0% 0% 100% 0 0 0 69% 31% 0% 0 1
Terragen Oasis SuperGreen Allocator Oasis SG 0% 0% 0% 69% 31% 0% 0% 100% 000 1 0 % 0 % 0 1
Calpine Geysers Xtension SuperGreen Allocator Calpine X SG 0% 0% 0% 100% 0% 0% 0% 100% San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Power Supply Line Item FY 2025 Expenses
Adjustment to Move
SG‐Related Renew PPA
RA Costs
FY 2025 After
Additional
Adjustments Allocation Green Capacity
Super Green
Capacity
Green and
SuperGreen Fixed
Charges Green Energy
Super Green
Energy
SuperGreen
Firming &
Shaping
Green & SuperGreen
Other Energy Costs Total
Derived Allocators
‐$ ‐ $ 10,633,062$ ‐ $ ‐ $ ‐ $ 10,633,062$ Total Operations & Maintenance Expense Total O&M 0% 0% 100% 0% 0% 0% 100% 61,997,683$ 7,451,555$ 10,633,062$ 288,158,551$ 10,667,745$ 983,004$ 6,533,030$ 386,424,631$ Revenue Requirement Rev Req 16% 2% 3% 75% 3% 0% 2% 100% ‐$ 438,377$ 0% 438,377 $ Capital Revenue Funded Capital 0% 0% 0% 0% 100% 0% 0% 100% 0 ‐1 0 58,056,552 $ 10,049,278$ 0% 0 68,105,829 $ Green/Super Green PPA Contracts Green/Super PPA 0% 0% 0% 85% 15% 0% 0% 100% San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Customer
Line Item FY 2025 Expenses Allocation
Data Management
& Service Fees
Cust. Account,
Service & Sales Energy Programs Bad Debt Total
Supply Costs
Contracted Energy Non‐Renewables ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Contracted Energy Renewables
sPower Raceway ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ NextEra Blythe ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Terragen Voyager ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Terragen Oasis ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ EDF Maverick ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Calpine Geysers (End 12/2029) ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ HHP Sunset (end 11/25) ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ CC Power Geothermal ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Paulsell 2.0 (20 MW PV, 15 MW Storage) ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Contracted Energy Renewables Total ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $
Firming and Shaping ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Resource Adequacy
Resource
Adequacy Contracts ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Resource Adequacy Net Short ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Resource Adequacy Total ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Renewable & GHG‐Free Attributes
Contracted RECs ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ GHG‐Free Attribute Contracts ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ GHG‐Free Attribute Net Short ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Renewable & GHG‐Free Attributes Total ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Other Purchased Power & Supply Costs
CAISO Services ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Other Purchased Power & Supply Costs Total ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Contingency ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Total Supply Costs ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Customer
Line Item FY 2025 Expenses Allocation
Data Management
& Service Fees
Cust. Account,
Service & Sales Energy Programs Bad Debt Total
Operating and Other Costs
Labor/Personnel 5,508,196 $ Payroll ‐$ 5,508,196$ ‐ $ ‐ $ 5,508,196$ Services of Bureaus 4,629,055 $ Cust. Accts ‐$ 4,629,055$ ‐ $ ‐ $ 4,629,055$ Non‐Personnel Services
Professional Services 664,451 $ Cust. Accts ‐$ 664,451$ ‐ $ ‐ $ 664,451$ Calpine Data Manager Fees 4,994,604 $ Data Mng. & Serv. Fee 4,994,604$ ‐ $ ‐ $ ‐ $ 4,994,604$ PG&E Service Fees 1,765,769 $ Data Mng. & Serv. Fee 1,765,769$ ‐ $ ‐ $ ‐ $ 1,765,769$ Letter of Credit ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Miscellaneous 85,649 $ Cust. Accts ‐$ 85,649$ ‐ $ ‐ $ 85,649$ Materials and Supplies 84,643 $ Cust. Accts ‐$ 84,643$ ‐ $ ‐ $ 84,643$ Services of Other Departments
Hetch Hetchy ‐$ Cust. Accts ‐$ ‐ $ ‐ $ ‐ $ ‐ $ City Attorney 407,768 $ Cust. Accts ‐$ 407,768$ ‐ $ ‐ $ 407,768$ Repro (Marketing) 639,723 $ Cust. Accts ‐$ 639,723$ ‐ $ ‐ $ 639,723$ All Other Departments 148,655 $ Cust. Accts ‐$ 148,655$ ‐ $ ‐ $ 148,655$ Total Operating Costs 18,928,515 $ 6,760,374$ 12,168,141$ ‐ $ ‐ $ 18,928,515$ Uncollectible 4,308,846 $ Bad Debt ‐$ ‐ $ ‐ $ 4,308,846$ 4,308,846$ Non‐Debt Capital Expenditures 5,901,302 $ Energy Programs ‐$ ‐ $ 5,901,302$ ‐ $ 5,901,302$ Margin 2,050,965 $ Cust. Accts ‐$ 2,050,965$ ‐ $ ‐ $ 2,050,965$ (Less) Other Revenues
Wholesale ‐$ N/A ‐$ ‐ $ ‐ $ ‐ $ ‐ $ Interest and Other Revenues (196,827) $ Rev Req (45,665) $ (82,194)$ (39,862)$ (29,106)$ (196,827)$ Revenue Requirement from Rates 30,992,801 $ 6,714,708$ 14,136,912$ 5,861,440$ 4,279,741$ 30,992,801$ San Francisco Public Utilities Commission
FY 2023‐24 CleanPowerSF Cost Classification: Customer
Line Item FY 2025 Expenses Allocation
Data Management
& Service Fees
Cust. Account,
Service & Sales Energy Programs Bad Debt Total
Direct Allocators
1 000 1
Data Management & PG&E Service Fees Data Mng. & Serv. Fee 100% 0% 0% 0% 100% 0 100 1
Customer Accounts, Service, and Sales Cust. Accts 0% 100% 0% 0% 100% 0 010 1
Energy Programs Energy Programs 0% 0% 100% 0% 100%
0 001 1
Bad Debt Bad Debt 0% 0% 0% 100% 100%
0 000 1
Direct Assign Direct 0% 0% 0% 0% 100%
Derived Allocators
6,760,374$ 12,168,141$ ‐ $ ‐ $ 18,928,515$ Total Operations & Maintenance Total O&M 36% 64% 0% 0% 100% 6,760,374$ 12,168,141$ 5,901,302$ 4,308,846$ 29,138,663$ Revenue Requirement Rev Req 23% 42% 20% 15% 100%
0 100 1
Payroll Payroll 0% 100% 0% 0% 100%
San Francisco Public Utilities Commission 15218
FY 2024‐25 CleanPowerSF Cost Allocation 2375
17593
Line Item FY 2025 Expenses Allocation Residential Small Commercial Medium Commercial Medium Commercial
High Large Commercial Street Lighting
SuperGreen
Customers Total
Power Supply
Green Capacity 56,014,360 $ 12 CP Green 24,335,405$ 7,769,543$ 6,408,049$ 10,814,586$ 6,667,795$ 18,982$ ‐ $ 56,014,360$ Super Green Capacity 6,732,415 $ SuperGreen ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 6,732,415$ 6,732,415$ Green and SuperGreen Fixed Charges 11,309,661 $ 12 CP Split 4,389,072$ 1,401,295$ 1,155,739$ 1,950,491$ 1,202,587$ 3,424$ 1,207,052$ 11,309,661$ Green Energy 306,494,528 $ Wght Price Green 131,422,463$ 41,568,140$ 34,851,543$ 62,253,610$ 36,255,167$ 143,606$ ‐ $ 306,494,528$ Super Green Energy 11,346,550 $ SuperGreen ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 11,346,550$ 11,346,550$ SuperGreen Firming & Shaping 1,045,554 $ SuperGreen ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ 1,045,554$ 1,045,554$ Green & SuperGreen Other Energy Costs 6,948,737 $ NEFL Split 2,624,491$ 852,244$ 715,773$ 1,271,359$ 736,500$ 2,805$ 745,565$ 6,948,737$ Total Power Supply 399,891,805$ 162,771,432$ 51,591,222$ 43,131,104$ 76,290,046$ 44,862,049$ 168,817$ 21,077,136$ 399,891,805$ Check ‐$
Customer
Data Management & Service Fees 6,714,708 $ Customer Split 5,954,234$ 452,113$ 34,696$ 121,247$ 1,489$ 3,441$ 147,489$ 6,714,708$ Cust. Account, Service & Sales 14,136,912 $ Wght C&O Split 10,527,908$ 799,399$ 306,735$ 2,143,813$ 26,320$ 6,084$ 326,654$ 14,136,912$ Energy Programs 5,861,440 $ Energy Programs 4,161,028$ 183,085$ 14,050$ 49,099$ 603$ 1,393$ 1,452,181$ 5,861,440$ Bad Debt 4,279,741 $ Bad Debt 2,049,155$ 785,474$ 582,163$ 851,843$ 10,458$ 646$ ‐ $ 4,279,741$ Direct Assign ‐$ n/a ‐$ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ ‐ $ Total Customer 30,992,801$ 22,692,326$ 2,220,072$ 937,645$ 3,166,002$ 38,869$ 11,564$ 1,926,324$ 30,992,801$ Check ‐$
Total Cost of Service 430,884,606 $ 185,463,757$ 53,811,293$ 44,068,748$ 79,456,048$ 44,900,918$ 180,381$ 23,003,460$ 430,884,606$ Allocation of Super Green Customer Costs
Power Supply
Super Green Capacity 6,732,415 $ 12 CP SG 550,683 $ 178,098$ 240,730$ 1,075,809$ 4,687,095$ ‐ $ ‐ $ 6,732,415$ Green and SuperGreen Fixed Charges 1,207,052 $ 12 CP SG 98,732 $ 31,931$ 43,160$ 192,881$ 840,347$ ‐ $ ‐ $ 1,207,052$ Super Green Energy 11,346,550 $ NEFL SG 898,478 $ 295,547$ 406,798$ 1,913,344$ 7,832,382$ ‐ $ ‐ $ 11,346,550$ SuperGreen Firming & Shaping 1,045,554 $ SG Firm & Shape 56,506$ 19,130$ 61,482$ 133,484$ 774,097$ 855$ ‐ $ 1,045,554$ Green & SuperGreen Other Energy Costs 745,565 $ NEFL SG 59,038 $ 19,420$ 26,730$ 125,723$ 514,654$ ‐ $ ‐ $ 745,565$ Total Power Supply 21,077,136$ 1,663,436$ 544,127$ 778,901$ 3,441,242$ 14,648,575$ 855$ ‐ $ 21,077,136$ Customer
Data Management & Service Fees 147,489 $ SG Customers 132,727$ 9,945$ 1,218$ 3,135$ 463$ ‐ $ ‐ $ 147,489$ Cust. Account, Service & Sales 326,654 $ Wght C&O SG 234,680$ 17,585$ 10,772$ 55,432$ 8,185$ ‐ $ ‐ $ 326,654$ Energy Programs 1,452,181 $ SG Customers 1,306,837$ 97,921$ 11,997$ 30,868$ 4,558$ ‐ $ ‐ $ 1,452,181$ Total Customer 1,926,324$ 1,674,245$ 125,451$ 23,987$ 89,435$ 13,206$ ‐ $ ‐ $ 1,926,324$ Total Cost of Service ‐ Green & Super Green 430,884,606$ ‐ $ 188,801,438$ 54,480,871$ 44,871,636$ 82,986,725$ 59,562,700$ 181,236$ ‐ $ 430,884,606$ Green Customers
San Francisco Public Utilities Commission 15218
FY 2024‐25 CleanPowerSF Cost Allocation 2375
17593
Line Item FY 2025 Expenses Allocation Residential Small Commercial Medium Commercial Medium Commercial
High Large Commercial Street Lighting
SuperGreen
Customers Total
Green Customers
Unbundled Cost of Service Results ‐ Green and Super Green
0.1336 0.15187 0.13491 0.13040 0.12762 0.10228 0.13937
Power Supply
Demand Related 74,056,435 $ 29,373,892$ 9,380,868$ 7,847,679$ 14,033,768$ 13,397,824$ 22,406$ ‐ $ 74,056,435$ Energy Related 325,835,370 $ 135,060,976$ 42,754,481$ 36,062,326$ 65,697,520$ 46,112,801$ 147,266$ ‐ $ 325,835,370$ Total 399,891,805 $ 164,434,868$ 52,135,348$ 43,910,004$ 79,731,288$ 59,510,624$ 169,672$ ‐ $ 399,891,805$ Percent of Total 41% 13% 11% 20% 15% 0% 0%
Percent of Class 87% 96% 98% 96% 100% 94%
Customer
Customer 30,992,801 $ 24,366,570$ 2,345,522$ 961,632$ 3,255,437$ 52,076$ 11,564$ ‐ $ 30,992,801$ Total 30,992,801 $ 24,366,570$ 2,345,522$ 961,632$ 3,255,437$ 52,076$ 11,564$ ‐ $ 30,992,801$ Percent of Total 79% 8% 3% 11% 0% 0% 0%
Percent of Class 13% 4% 2% 4% 0% 6%
Total COS 430,884,606$ 188,801,438$ 54,480,871$ 44,871,636$ 82,986,725$ 59,562,700$ 181,236$ ‐ $ 430,884,606$ Representative COS Rates
Customer Charge 6.52 $ 5.65$ 7.17$ 37.82$ 36.97$ 37.69$ 4.75$ ‐ $ 6.52$ Demand Charge 5.07 $ 3.17$ 6.36$ 8.19$ 9.47$ 9.40$ 8.83$ 5.07$ Energy Charge 0.1010 $ 0.1086$ 0.1059$ 0.1048$ 0.1010$ 0.0792$ 0.1132$ 0.1010$ San Francisco Public Utilities Commission 15218
FY 2024‐25 CleanPowerSF Cost Allocation 2375
17593
Line Item FY 2025 Expenses Allocation Residential Small Commercial Medium Commercial Medium Commercial
High Large Commercial Street Lighting
SuperGreen
Customers Total
Green Customers
1 ‐ ‐ ‐ ‐ ‐ ‐ 1 Residential Residential 100% 0% 0% 0% 0% 0% 0% 100%
351,314 ‐ ‐ ‐ ‐ ‐ 7,831 359,146 Residential Split Residential Split 98% 0% 0% 0% 0% 0% 2% 100% 1 1
SuperGreen SuperGreen 0% 0% 0% 0% 0% 0% 100% 100%
359,146 27,263 2,119 7,339 115 203 ‐ 396,184 Number of Customers Including SuperGreen Customers 91% 7% 1% 2% 0% 0% 0% 100% 7,831 587 72 185 27 ‐ ‐ 8,702 SuperGreen Customers SG Customers 90% 7% 1% 2% 0% 0% 0% 100% 351,314 26,676 2,047 7,154 88 203 ‐ 387,482 Green Customers Green Customers 91% 7% 1% 2% 0% 0% 0% 100% 351,314 26,676 2,047 7,154 88 203 8,702 396,184 Customer Split Between Green and SuperGreen Customer Split 89% 7% 1% 2% 0% 0% 2% 100% 1,328,670,283 431,578,603 367,628,389 691,724,029 619,472,140 1,388,723 ‐ 3,440,462,167 Total Energy at Wholesale (NEFL) NEFL 39% 13% 11% 20% 18% 0% 0% 100% 29,230,746 9,615,229 13,234,622 62,248,015 254,815,747 ‐ ‐ 369,144,359 Total Energy at Wholesale (NEFL) SuperGreen NEFL SG 8% 3% 4% 17% 69% 0% 0% 100% 1,299,439,537 421,963,374 354,393,767 629,476,014 364,656,394 1,388,723 ‐ 3,071,317,808 Total Energy at Wholesale (NEFL) Green NEFL Green 42% 14% 12% 20% 12% 0% 0% 100% 1,299,439,537 421,963,374 354,393,767 629,476,014 364,656,394 1,388,723 369,144,359 3,440,462,167 Total Energy at Wholesale (NEFL) Split NEFL Split 38% 12% 10% 18% 11% 0% 11% 100% 1,243,201,270 403,821,760 344,113,970 650,284,340 582,362,800 1,300,420 ‐ 3,225,084,560 Total Energy at Retail Energy ‐Retail 39% 13% 11% 20% 18% 0% 0% 100% 27,350,428 8,996,828 12,388,103 58,518,871 239,551,066 ‐ ‐ 346,805,297 Total Energy at Retail SuperGreen Energy ‐Retail SG 8% 3% 4% 17% 69% 0% 0% 100% 1,215,850,842 394,824,932 331,725,867 591,765,469 342,811,734 1,300,420 ‐ 2,878,279,263 Total Energy at Retail Green Energy ‐Retail Green 42% 14% 12% 21% 12% 0% 0% 100% 9,272,795 1,475,445 957,966 1,481,588 1,424,606 2,538 ‐ 14,614,938 Sum of Max Demands SMD 63% 10% 7% 10% 10% 0% 0% 100%
2,550,566 814,550 681,374 1,218,149 1,161,067 1,946 ‐ 6,427,652 Coincident Peak 12 CP 40% 13% 11% 19% 18% 0% 0% 100%
56,112 18,148 24,529 109,621 477,597 ‐ ‐ 686,007 Coincident Peak SuperGreen Customers 12 CP SG 8% 3% 4% 16% 70% 0% 0% 100% 2,494,454 796,402 656,845 1,108,528 683,470 1,946 ‐ 5,741,644 Coincident Peak Green Customers 12 CP Green 43% 14% 11% 19% 12% 0% 0% 100% 2,494,454 796,402 656,845 1,108,528 683,470 1,946 686,007 6,427,652 Coincident Peak Split 12 CP Split 39% 12% 10% 17% 11% 0% 11% 100% 86,974,757 27,517,452 23,399,547 44,277,255 39,863,032 92,947 222,124,990 Weighted Market Price of Energy Wght Price 39% 12% 11% 20% 18% 0% 0% 100% 85,061,312 26,904,385 22,557,163 40,292,760 23,465,639 92,947 198,374,206 Weighted Market Price of Green Energy Wght Price Green 43% 14% 11% 20% 12% 0% 0% 100% 359,146 27,263 10,595 73,388 1,151 203 471,746 Weighted Communications & Outreach Wght C&O 76% 6% 2% 16% 0% 0% 0% 100% 7,831 587 359 1,850 273 ‐ 10,900 Weighted Communications & Outreach SuperGreen Wght C&O SG 72% 5% 3% 17% 3% 0% 0% 100% 351,314 26,676 10,236 71,539 878 203 460,846 San Francisco Public Utilities Commission 15218
FY 2024‐25 CleanPowerSF Cost Allocation 2375
17593
Line Item FY 2025 Expenses Allocation Residential Small Commercial Medium Commercial Medium Commercial
High Large Commercial Street Lighting
SuperGreen
Customers Total
Green Customers
Weighted Communications & Outreach Green Wght C&O Green 76% 6% 2% 16% 0% 0% 0% 100% 351,314 26,676 10,236 71,539 878 203 10,900 471,746 Weighted Communications & Outreach Split Wght C&O Split 74% 6% 2% 15% 0% 0% 2% 100% 1,347,740$ 59,301$ 4,551$ 15,903$ 195$ 451$ 470,356$ 1,898,497 Energy Programs Energy Programs 71% 3% 0% 1% 0% 0% 25% 100% 39,270 13,295 42,728 92,769 537,980 594 ‐ $ 726,636 SuperGreen Firming & Shaping SG Firm & Shape 5% 2% 6% 13% 74% 0% 0% 100% 8,741,819$ 3,350,879$ 2,483,544$ 3,634,013$ 44,615$ 2,757$ ‐ $ 18,257,627 Bad Debt Expense Bad Debt 48% 18% 14% 20% 0% 0% 0% 100%
OUR MISSION: To provide our customers with high-quality, efficient and reliable water, power and sewer services in a manner that values environmental and community interests and sustains the resources entrusted to our care.
MEMORANDUM
DATE: 3 May 2024
TO: San Francisco Public Utilities Commission
FROM: Rate Fairness Board
SUBJECT: Proposed retail electricity rates for Hetch Hetchy Power and CleanPowerSF for FY 2025:
Commissioners:
In accordance with Article 8B of the Charter of the City and County of San Francisco, the Rate Fairness Board (RFB) offers the following comments and recommendations regarding the SFPUC Staff’s proposed retail electricity rates for Hetch Hetchy Power and CleanPowerSF for the period July 1, 2024, to June 30, 2025:
1. We note that the rates for the SFPUC’s retail electricity service saw major changes for FY 2022-23, as a result of the first independent cost- of-service study for the Power Enterprise. These changes included:
a. Separate rate-setting for Hetch Hetchy Power and
CleanPowerSF; and
b. Trending all rates toward Cost of Service, subject to reasonable caps on annual increases.
2. As it did last year (for FY 2023-24), the Staff is proposing rates for only a 1-year period, given the ongoing volatility and uncertainty in California’s electricity market. This approach seems reasonable given the circumstances, and it has served the SFPUC and its customers well in the past 2 years. This one-year rate proposal again seems prudent and reasonable.
3. The Staff’s current proposed generation rates are based solely on SFPUC costs, and the rates are below the corresponding rates for comparable service from Pacific Gas & Electric (PG&E).
4. The Staff’s proposal continues their process of simplifying the systems’ electric rates, by consolidating and eliminating unneeded and redundant rate classes and schedules. This simplification benefits customers and the enterprise.
5. At first glance, the proposed 8.5% increase in CleanPowerSF rates may appear to excessive, but it is necessary cover the enterprise’s expected costs, and CleanPowerSF’s rates are projected to remain lower than or equal to the equivalent PG&E rates. We note that this increase is less than that originally contemplated by Staff; the reduced rate increase comes at the expense of a slower projected path toward achieving the enterprise’s operating fund balance target. This is just one more example of the trade-offs inherent in the rate-making process and accept the outcome.
6. The 12% overall rate increase for Hetch Hetchy Power is in line with the Staff’s goals, established 2 years ago, for a multi-year move toward rates based on cost of service as well as for rate simplification. We note that this increase is less than the 14% originally proposed; staff re-calculated rates according to projected customer usage patterns and proposed the lower increase.
We note that the se rate increases, while not insignificant, are necessary to cover the Enterprises’ costs and to meet financial policy goals. We would expect that taking these steps now will mean future rate changes may be smaller and even negative. In the meantime, we encourage the Staff and the Enterprises to continue the programs that help customers save on the electricity bills.
Overall, we find that the Staff’s current rate proposal is a reasoned and measured approach to well-established goals: adjusting rates to account for current and expected costs, while meeting the twin objectives of establishing rates based solely on cost of service and providing service at rates competitive with PG&E. Thus, the RFB recommends that the Commission approve the Staff’s electricity rate proposal.
We look forward to continued interaction with the Commission on future rate proceedings for water, wastewater and power.
Sincerely,
Howard Ash
Chair, Rate Fairness Board of the San Francisco Public Utilities Commission
On behalf of:
Eric Dew, Residential City Retail Customer
Trisha McMahon, Budget & Planning Manager, City Administrator’s Office Calvin Quock, Budget & Revenue Analyst, Controller’s Office Massood Samerie, Vice-Chair and City Retail Large Business Customer Vishal Trivedi, Financial Analyst, Controller’s Office of Public Finance
Services of the San Francisco Public Utilities Commission Proposed FYE 2024-25 CleanPowerSF
and Hetch Hetchy Power Rates
May 14, 2024
Erin Corvinova, Financial Planning Director
1 Agenda
Power Rates Landscape
Rates Communications
CleanPowerSF Rates
• Rate Setting Overview
• Proposed CleanPowerSF Generation Rates
• Bill Impacts
Hetch Hetchy Power Rates
• Rate Structure Overview
• Discussion about Proposed Rate Schedule Modifications • Rate Setting Overview
• Proposed Enterprise and Retail Rates
• Bill Comparisons
2 Power Rates Landscape
• 2022 Power Rates Study
• CleanPowerSF’s first and Hetch Hetchy Power’s second Charter- required rate study
• Adopted 1-2 years of rates to respond to expense volatility and uncertainty
• Key accomplishment: Set own rates based on cost of service, no longer tied to/following PG&E
• New rates needed for both CleanPowerSF and Hetch Hetchy Power for FY 2024-25
• Next rate study will be completed Spring 2026 to set rates for FY 2026-27
3 Rates Communications (Mar-May)
4 Clean
PowerSF
Hetch
Hetchy
Power
Communications Tactic Release
Date
Notes
✔ ✔ Create dedicated Power rates
landing page on SFPUC.org
March 12 All communications direct customers to one webpage:
www.sfpuc.org/powerrates
✔ ✔ On-bill message April & May On-bill notice of public rate process and link to webpage ✔ Bill insert April Multilingual rate notice in April & May bills ✔ ✔ Customer e-newsletters April 4 Provide notice of July 1, 2024 rate change and public process; link to webpage
✔ ✔ Direct mail postcard mid-April Multilingual notice of July 1, 2024 rate change and public process; link to webpage
✔ ✔ Webinar on residential rates April 29 &
May 1
Presentation on residential rates, rate process, and key dates. Recorded and available on webpage.
✔ Key account outreach April-May Specific notice to customer accounts experiencing rate class changes (Hetch Hetchy Power only)
Services of the San Francisco Public Utilities Commission 5 CleanPowerSF
FYE 2024-25 Rates
CleanPowerSF Rates Landscape
• 2022 Power Rates Study adopted FY 2022-23 rates
• FY 2023-24 rates set using models from rates study and updated expense and customer data
• Key goals of FY 2024-25 rates update
• Maintaining rates competitive with PG&E
• Maintaining rates that are equitable for customers (following cost of service)
• Continuing to build fund balance reserves
6 CleanPowerSF Rates Structure
• CPSF rate classes exactly match to PG&E
• ex. 7 different residential rates
• CleanPowerSF only collects the generation
portion of the bill
• CPSF customers also pay “Power Choice
Indifference Adjustment” and “Franchise
Fee Surcharges” to PG&E
• CPSF sets rates comparing to the (PG&E
generation rate) – (PCIA + FFS)
• Changes to PG&E delivery charges
impact customers but have no effect on
CleanPowerSF’s competitiveness
• CleanPowerSF current rates are below PG&E
for all customers
7 $63
$3
$35
$63
$2
$42
$101 $107
$0
$20
$40
$60
$80
$100
$120
CleanPowerSF
April 2024
PG&E
April 2024
Average Monthly Bill
CleanPowerSF vs. PG&E Average
Residential Bills (E-TOU-C)
PG&E Delivery PG&E Delivery
PCIA PG&E Generation
CleanPowerSF FY 2024-25 Rates Setting
Proposal: 8.5% overall rate increase with updated cost-of- service allocations to customer classes
• Due to cost-of-service update, each rate may increase by more or less Process
8 Revenue
Requirement
• Commission adopted 10-
Year Financial Plan with
approved operating and
capital budges
Cost
Functionalization and
Allocation
• Leverage 2022 SFPUC
Power Rates Study model
• Update FY 2024-25
expenses from Financial
Plan
• Update with Calendar Year
2023 customer usage data
Rate Design
• Keep rate structures
consistent to current rates
• Compare to PG&E current
PG&E rates for each tariff
schedule
• Analyze rate schedules for
rebalancing
CleanPowerSF Expense Forecast
9 • Increased sales FYE 2024-25 due to new commercial customer signups • Moderate growth from electrification, population growth projected • Large increase in supply costs in recent years expected to level off but not drop Total ExpensesPower Sales Volumes
$361
$520
$-
$100
$200
$300
$400
$500
$600
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
Millions
Power Supply Operations Revenue-Funded Projects
CleanPowerSF Cash Flow
($M) FYE 2024 FYE 2025 FYE 2026 FYE 2027 FYE 2028 FYE 2029 Beginning Fund Balance $ 90.1 $ 125.3 $ 150.5 $ 195.1 $ 235.7 $ 276.1 Sources
Retail Power Sales 383.2 434.8 468.7 473.9 479.4 483.2
Wholesale Sales 11.6 11.1 0.0 0.0 0.7 1.1
Other Miscellaneous Income 1.5 4.2 4.1 4.2 4.3 4.5
Total Sources $ 396.3 $ 450.1 $ 472.8 $ 478.1 $ 484.5 $ 488.8 Uses
Power Supply 328.9 385.0 386.2 394.2 399.4 403.8
Operations 30.6 39.4 41.5 42.8 44.2 45.6
Revenue-Funded Projects 1.6 0.6 0.5 0.4 0.5 0.7
Total Uses $ 361.1 $ 425.0 $ 428.3 $ 437.5 $ 444.1 $ 450.1 Net Revenues $ 35.2 $ 25.2 $ 44.5 $ 40.6 $ 40.4 $ 38.8 Ending Fund Balance $ 125.3 $ 150.5 $ 195.1 $ 235.7 $ 276.1 $ 314.9 Generation Rate Change 8.5% 6.5% 0.0% 0.0% 0.0%
Days Cash On Hand 129 140 181 218 251 283
10 • Updated slightly from 10
Year Plan with latest data
• Power supply makes up
~90% of total expenses
• Near term rate adjustments
needed to meet 180 days
cash on hand policy
objective
• Future years show 0%
adjustment until we have
more certainty on future
power costs.
10% 8% 8% 7% -5% 11%
$0.1519
$0.1349 $0.1304 $0.1276
$0.1023
$0.1394
$0.00
$0.02
$0.04
$0.06
$0.08
$0.10
$0.12
$0.14
$0.16
Residential Small General Service Medium General
Service - Low Demand
Medium General
Service -High Demand
Large General Service
& Agriculture
Outdoor Lighting
Aggregate Unit Cost ($/kWh)
Unit Costs per Customer Class
Power Supply Customer
CleanPowerSF Cost of Service Update
11 • 8.5% overall increase in rates = different increases for each customer class • Change in unit cost is a function of changes in cost allocated to customers and change in total usage
• The relative difference in COS allocations will be reflected in resulting rates CleanPowerSF Average Monthly Bill Comparison
Residential (E-TOU-C)
12 $63 $66
$3 $3
$35
$39
$63 $66
$2 $2
$42 $39
$101
$108$107 $108
$0
$20
$40
$60
$80
$100
$120
CleanPowerSF
April 2024
PG&E
April 2024
CleanPowerSF
Proposed
FYE 2025
PG&E
Projected
July 2024
Average Monthly Bill
PG&E Delivery PG&E Fees (PCIA/FFS) CleanPowerSF Generation PG&E Generation CleanPowerSF Average Monthly Bill Comparison
Small General Service (B-1)
13 $376 $389
$13 $13
$158 $174
$376 $389
$10 $10
$208 $194
$548 $577$594 $594
$0
$100
$200
$300
$400
$500
$600
$700
CleanPowerSF
April 2024
PG&E
April 2024
CleanPowerSF
Proposed
FYE 2024
PG&E
Projected
July 2024
Average Monthly Bill
PG&E Delivery PG&E Fees (PCIA/FFS) CleanPowerSF Generation PG&E Generation CleanPowerSF Average Monthly Bill Comparison
Large General Service, Sec. Volt. (B-20S)
14 $95 $98
$6 $6
$67 $65
$95 $98
$4 $4
$90 $85
$168 $170
$190 $187
$0
$20
$40
$60
$80
$100
$120
$140
$160
$180
$200
CleanPowerSF
April 2024
PG&E
April 2024
CleanPowerSF
Proposed
FYE 2024
PG&E
Projected
July 2024
Average Monthly Bill
Thousands
PG&E Delivery PG&E Fees (PCIA/FFS) CleanPowerSF Generation PG&E Generation Services of the San Francisco Public Utilities Commission Hetch Hetchy Power
FYE 2024-25 Rates
15 Hetch Hetchy Power Rates Landscape
• 2022 Power Rates Study adopted FY 2022-23 and
FY 2023-24 rates (two years)
• Key goals of FY 2024-25 rates update
• Set rates to achieve all financial policy goals
• Debt Service Coverage is main driver of rate increase • Continue rate consolidation and transition to cost of service 16 Hetch Hetchy Power Rates Structure
17 General Use
(GUSE) Rates
• General Fund
departments,
education
districts,
governmental
agencies
• Less than cost of
service
(subsidized)
• Increasing
annually by 3
cent/kWh
Tuolumne County
Rates
• Three customers
in Tuolumne
County
• Set many years
ago by contract,
currently less
than cost of
service
• Increasing
annually
beginning FY
2023-24
Hetch Hetchy
Retail Rates
• Private
customers,
mostly in
redevelopment
areas, affordable
housing
• Default rate for
new customers
• Set at cost of
service + share
of subsidy
• As of FY 2023-
24, same as
retail rates
Enterprise Rates
• Airport,
Enterprise
departments,
Port tenants
• Set at cost of
service + share
of subsidy
• As of FY 2023-
24, same as
retail rates
Hetch Hetchy Power FY 2024-25 Rates Setting
Proposal:
• 12% flat rate increase for retail rates
• $0.03/kWh effective rate increase for General Use and Tuolumne County Rates
Process
18 Revenue
Requirement
• Commission adopted
10-Year Financial Plan
with approved
operating and capital
budges
Cost
Functionalization
and Allocation
• Leverage 2022 SFPUC
Power Rates Study
model and allocations
• Did not update cost of
service per customer
class
Rate Design
• Continue rate
consolidation,
eliminating rate codes
when possible
• Make changes to rate
structure for some key
rates
Hetch Hetchy Power Expense Forecast
19 $250
$577
$-
$100
$200
$300
$400
$500
$600
$700
FYE
2024
FYE
2025
FYE
2026
FYE
2027
FYE
2028
FYE
2029
FYE
2030
FYE
2031
FYE
2032
FYE
2033
FYE
2034
Millions
Power Supply and Delivery Other Operations & Maintenance Debt Service Revenue-Funded Capital
Power supply costs are the main driver of expenditure growth 985
978
1,036
837 916
928
1,039
1,382
-
200
400
600
800
1,000
1,200
1,400
1,600Power Sales (GWh)
Actual Retail Sales Projected Retail Sales
Hetch Hetchy Power Cash Flow
($M) FYE 2024 FYE 2025 FYE 2026 FYE 2027 FYE 2028 FYE 2029 Beginning Fund Balance $ 189.3 $ 183.5 $ 157.6 $ 143.5 $ 138.0 $ 146.5 Sources
Power Sales - Retail 169.1 205.0 242.7 293.1 344.1 378.2 Power Sales - Wholesale 38.2 18.9 20.1 17.5 15.1 16.4
Gas & Steam Sales 24.7 23.7 28.3 31.4 34.5 35.9
Water Sales 2.6 2.8 3.1 3.3 3.5 3.7
Hetchy Transfer 46.3 49.2 52.1 53.6 55.6 57.3
Other Misc Income 14.9 19.5 22.6 18.8 16.2 14.7
Total Sources $ 295.8 $ 319.1 $ 369.0 $ 417.7 $ 469.0 $ 506.1 Uses
Power Supply & Delivery Charges 129.9 138.3 148.7 171.5 181.0 196.7 Other Operations & Maintenance 162.3 174.2 182.9 187.6 193.5 201.7 Debt Service 3.5 10.5 13.6 17.7 25.9 38.1
Revenue-Funded Projects 5.9 22.0 37.9 46.4 60.0 46.2
Total Uses $ 301.5 $ 345.0 $ 383.1 $ 423.2 $ 460.5 $ 482.7 Net Revenues $ (5.7) $ (26.0) $ (14.1) $ (5.5) $ 8.5 $ 23.4 Ending Fund Balance $ 183.5 $ 157.6 $ 143.5 $ 138.0 $ 146.5 $ 169.9 Retail Rate Increase 12.0% 10.0% 9.0% 9.0% 5.0%
Debt Service Coverage Target 1.10 1.10 1.10 1.10 1.10 1.10 Debt Service Coverage (Current) 1.00 0.31 2.22 3.10 3.42 2.73 Debt Service Coverage (Current w/
Fund Balance as Revenue) 2.73 2.81 3.27 3.42 3.42 2.73
20 • Near term rate adjustments
needed to meet Debt
Service Coverage
Requirements
• Future year rate
adjustments are driven by
growing power supply and
delivery charges
Hetch Hetchy Power Rate Design
Enterprise and Retail Rate Consolidation
Consolidate Identical Rates
Standardize Low-Income Discounts
• Provide standard 30% discount to all qualifying customers, no matter their rate code
Eliminate Outdated Master Meter Residential
• Move to small and large commercial rates instead
Enterprise Time-of-Use Rates: No New Enrollment
• Legacy rates allow existing customers to stay on but don’t expand enrollment in outdated rate structure
21 Hetch Hetchy Power Rate Design
Shoreside Power & Tuolumne County Rates
Shoreside Power
• Rate charged to cruise ships that
dock at SF Port facilities
• Port is customer but passes on bills
to cruise ships
• Goals of rate structure update:
• Maintain demand charges to reflect
cost of service, industry norms
• Make administration easier for Port by
simplifying forecasting of annual
effective rates passed through to ships
Tuolumne County Rates
• Rates charged to US Forest Service,
CA Dept. of Fish and
Wildlife, SFPUC employees in
housing at Moccasin
• Significantly below cost of service,
had not increased for decades
• Still a flat $/kWh structure – plan to
address in next rates study
• Increase 50% or by $0.03/kWh,
whichever is less
22 Hetch Hetchy Average Monthly Bill Comparison
Residential (R-1E, R-2E, E-TOU-C)
23 $60
$67
$85
$95
$131 $133
$-
$20
$40
$60
$80
$100
$120
$140
FYE 2024 FYE 2025
Average Monthly Bill
Hetch Hetchy Retail Low-Income Discounted Rates Hetch Hetchy Retail Rates PG&E Rates Hetch Hetchy Average Monthly Bill Comparison
Small Commercial (C-1, CG-1, B-1)
24 $284
$337
$487
$545
$775 $788
$-
$100
$200
$300
$400
$500
$600
$700
$800
$900
FYE 2024 FYE 2025
Average Monthly Bill
Hetch Hetchy General Use Rates Hetch Hetchy Retail Rates PG&E Rates Hetch Hetchy Average Monthly Bill Comparison
Industrial, Primary Voltage (I-1P, IG-1P)
25 $174,248
$208,344$211,432
$236,810
$-
$50,000
$100,000
$150,000
$200,000
$250,000
FYE 2024 FYE 2025
Average Monthly Bill
Hetch Hetchy General Use Rates Hetch Hetchy Retail Rates Services of the San Francisco Public Utilities Commission Thank you!
Questions and Discussion