CleanPowerSF Sfpuc Commission
May 9, 2023

Services of the San Francisco Public Utilities Commission Adopt CleanPowerSF
Fiscal Year 2023-24 Retail Rates
1 Yee Nwe (Ma Yee) H. Yap
Principal Revenue/Rates Analyst
May 9, 2023

Agenda

1. CleanPowerSF Rates Landscape

2. FY 2023-24 Rates Setting

3. Revenue Requirement

4. Cost of Service Rates

5. Proposed CleanPowerSF Generation (Green) Rates

6. Bill Impact

7. Temporary Rates for New Rate Schedule

8. New Rate Schedule Methodology
2 CleanPowerSF Rates Landscape
• SF City Charter requirement
• rates study at least every five years by independent consultant • 2022 Power Rates Study
• CleanPowerSF’s first rates study
• adopted FY 2022-23 cost of service (COS) rates in May 2022 • Key outcomes of rates study
• ensure financial sustainability: program’s COS, no longer follow PG&E • prioritize customer needs
• support City’s climate action goals
• CleanPowerSF FY 2022-23 rates decreased from FY 2021-22 rates 3 FY 2023-24 Rates Setting
• Revenue Requirement
• Commission adopted 10-Year Financial Plan
• Cost Functionalization, Classification, and Allocation • Leverage 2022 SFPUC Power Rates Study
• Update FY 2023-24 power supply costs
• Update with FY 2021-22 weighted energy price per customer class • Rate Design
• Analyze FY 2023-24 bill impact for CleanPowerSF customers • Compare bills of CleanPowerSF customers to PG&E customers • Analyze rate schedules for rebalancing
4 Revenue Requirement
5 Power supply is the biggest driver!
Revenue requirement shown is prior to excluding other revenues such as wholesale and interest income, projected to be about $3 million total in FY 2023-24. Total retail revenue requirement in FY 2023-24, after excluding other revenues, is $369 million.

Cost of Service Rates
• 15% rate increase for CleanPowerSF generation rates
proposed in Commission-adopted 10-Year Financial Plan
6 Proposed CleanPowerSF Generation
(Green) Rates
Customer Class
FY 2023-24
Green Rates ($/kWh)
% Gen Rate
Change
Residential $0.13748 16%
Small General Service $0.12431 13%
Medium General Service –
Low Demand $0.12099 7%
Medium General Service –
High Demand $0.11936 17%
Large General Service $0.10586 6%
Agriculture $0.09065 8%
Street Lighting $0.12559 21%
Traffic Control $0.12559 14%
7 • All average CleanPowerSF customers (except Streetlights) are projected to have lower total bills than comparable current (effective March 2023) PG&E rates.

Bill Impact: Residential (E-TOU-C)
Assumes 270 kWh monthly usage on default E-TOU-C rate schedule. Customers’ bills on time-of use rates can vary significantly based on usage patterns. 8 PG&E Delivery Charge,
$54
PG&E Delivery Charge,
$54
PG&E Delivery Charge,
$54
PCIA/FFS, $1 PCIA/FFS, $1 PCIA/FFS, $4
CleanPowerSF
Generation Charge, $32
CleanPowerSF
Generation Charge, $37
PG&E Generation
Charge, $37
CleanPowerSF
Customer Savings, $8
CleanPowerSF Customer
Savings, $3
$87 $92 $95
$-
$20
$40
$60
$80
$100
CleanPowerSF FYE 2023 CleanPowerSF Proposed FYE
2024
PG&E Current
PG&E Delivery Charge PCIA/FFS
CleanPowerSF Generation Charge PG&E Generation Charge
CleanPowerSF Customer Savings

Bill Impact: Small Commercial (B-1)
Assumes 1304 kWh monthly usage. Customers’ bills on time-of use rates can vary significantly based on usage patterns.
9 PG&E Delivery
Charge, $271
PG&E Delivery
Charge, $271
PG&E Delivery
Charge, $271
PCIA + FFS, $5 PCIA + FFS, $5 PCIA + FFS, $16
CleanPowerSF Generation
Charge, $143
CleanPowerSF
Generation Charge, $160
PG&E Generation
Charge, $178
CleanPowerSF Customer
Savings, $46
CleanPowerSF Customer
Savings, $29
$419 $436 $465
$-
$50
$100
$150
$200
$250
$300
$350
$400
$450
$500
CleanPowerSF FYE
2023
CleanPowerSF
Proposed FYE 2024
PG&E Current
PG&E Delivery Charge PCIA + FFS
CleanPowerSF Generation Charge PG&E Generation Charge
CleanPowerSF Customer Savings

Temporary Rates for New Rate Schedule
CleanPowerSF suite of rate schedules matches PG&E
• New rates arise; e.g., Residential Electric Home (E-ELEC) 10 Proposal
What?
• Allow General Manager to implement new rate schedule
• Set temporary rates using a formulaic “new rate schedule methodology” until next comprehensive rate-setting process When?
• PG&E offers a new rate schedule
Why?
• Use Staff, Commission, and Public time efficiently
• Provide alternative power supply with cleaner energy
• Support the City’s climate action goal
• Prevent potential opt-outs
New Rate Schedule Methodology
11 How?
Set temporary rates of the new rate schedule to
CleanPowerSF’s applicable customer class rate
Step 1
Calculate ratios of PG&E’s generation rates of the new rate schedule to PG&E’s default rate schedule in the applicable customer class
Step 2
Apply resulting ratios in Step 1 to CleanPowerSF’s comparable default rate schedule in the same customer class to set CleanPowerSF new rate schedule’s generation rates
New Rate Schedule Methodology:

Prior Use Example
12 • Adopted E-ELEC rates in Resolution 23-0015 on
J
anuary 10, 2023
• Applied time-of-use ratio of PG&E’s residential E-
ELEC rates and its standard Electric E-1 rate to
CleanPowerSF’s standard E-1 rate
PG&E E-ELEC rates / PG&E E-1 rate = E-ELEC Ratio
CleanPowerSF E-1 rate x E-ELEC Ratio = CleanPowerSF E-ELEC rates Thank You

Rate Fairness Board Memo
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.
525 Golden Gate Avenue, 13th Floor
San Francisco, CA 94102
T 415.554.3155
F 415.554.3161
TTY 415.554.3488
May 01, 2023
San Francisco Public Utilities Commission
525 Golden Gate Avenue, 13th Floor
San Francisco, CA 94102
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 Staff’s proposed retail electricity rates for Clean Power SF for the period July 1, 2023 to Jue 30, 2024:

1. We note that the rates for the SFPUC’s retail electricity service saw major changes last year, as a result of the first independent cost-of- service study for Power Enterprise. These changes included:
a. separate rate-setting for Hetch Hetchy and Clean Power SF; b. trending all rates toward Cost of Service, subject to reasonable caps on annual increases;
c. new tiers for residential service and different summer v. winter block sizes; and
d. a new all-electric rate schedule and a pilot EV-only rate.

2. The Staff’s proposal last year was for rates for a 1-year period, given the then-current volatility and uncertainty in California’s electricity market. The RFB recommended approval of those rates at that time.

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. Once again, given some continued volatility in California’s electricity markets, the Staff has proposed new retail rates for only a one-year period. This approach seems reasonable given the circumstances, and it has served the SFPUC and its customers well in the past year. This one-year rate proposal again seems prudent and reasonable, Overall, the Staff's current rate proposal is mostly ministerial: adjusting rates to account for current and expected costs, while meeting the twin goals 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.

The Staff has also requested a limited delegated authority to be used in cases when PG&E develops a new rate schedule and the corresponding new Clean Power SF rate would be voluntary, While we recognize the administrative convenience of this authority, we recommend that Staff endeavor in all cases to bring new rates and rate schedules before the RFB and the Commission in a timely manner.

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:

Ken Hinton, Budget & Revenue Analyst, Controller's Office Trisha McMahon, Budget & Planning Manager, City Administrator's Office Vishal Trivedi, Financial Analyst, Controller's Office of Public Finance

AGENDA ITEM
Public Utilities Commission
City and County of San Francisco
DEPARTMENT Financial Services AGENDA NO. 10
MEETING DATE May 9, 2023
APPROVAL:

COMMISSION
SECRETARY Donna Hood
Calendar: Regular Calendar
Project Manager: Yee Nwe (Ma Yee) H Yap
Adopt CleanPowerSF Rates for FY 2023-24
Summary of
Proposed
Commission Action:

Public Hearing to consider (1) 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, 2023; and (2) adopt a mechanism to set temporary rates for new rate schedules to be applied when the Califor nia Public Utilities Commission approves one for P acific Gas and E lectric Company (PG&E), and to use a new rate schedule methodology for the initial rate based on ratios to the CleanPowerSF default rate schedule in the applicable customer class until the next CleanPowerSF rate sett ing process. This action constitutes the Approval Action for the project for the purposes of the California Environmental Quality Act (CEQA) pursuant to Section 31.04(h) of the San Francisco Administrative Code. The Planning Depar tment 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: 2022 SFPUC Power Rates Study
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 (Study).

The consultant recommended retail rates for two years – FY 2022-23 and FY 2023-24 – in the 2022 Power Rates Study Final Report for both Power business lines, Hetch Hetchy Power and CleanPowerSF at the completion of the Study in Spring 2022. However, Staff proposed to adopt only one year of rates (FY 2022-23) for CleanPowerSF to adapt to increased volatility in energy markets caused by geopolitical conflict and continued supply chain disruptions from COVID -19.

Moreover, one of the major goals of the S tudy was to support CleanPowerSF’s new reserves policy to build up sufficient reserves .

Staff proposed a single -fiscal year of rates adoption to allow CleanPowerSF to monitor and respond to rapidly changing market conditions for FY 2023-24.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

On May 24, 2022, the SFPUC Commission adopted CleanPowerSF FY 2022-23 rates in Resolution 22-0094.

CleanPowerSF FY 2023-24 Rate Setting
FY 2023-24 rates setting 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.

Communications and External Affairs also provided direction on communication strategies, as well as outr each efforts to elected officials and the public.

Staff updated the revenue requirement for FY 2023- 24 with operating and capital expenditures from the Commission-adopted FY 2023-24 to FY 2032-33 10- Year Financial Plan, which incorporated the adopted FY 2023-24 Operating Budget and FY 2023-24 to FY 2032-33 10-Year Capital Plan. Staff also evaluated needed fund balance in the CleanPowerSF revenue requirement to get on a path to meet the Days- Cash-On-Hand target consistent with the Fund Balance Reserve Policy. Detailed line items making up the revenue requirement are included in Attachment 1. FY 2023-24 CleanPowerSF Revenue Requirement.

Staff leveraged analysis from the most recent Study for distribution of revenue requirement in the functionalization, classification, and allocation processes. Staff, however, reevaluated power supply costs in FY 2023-24 for an updated classification of power supply costs into energy and capacity. Staff also updated the weighted energy price per customer class by using the most recent FY 2021-22 C alifornia Independent System Operator hourly prices and CleanPowerSF hourly loads for the allocation of energy cost to customer classes. For effective cost-of-service rates by customer class, Staff further adapted FY 2023-24 energy sales volumes from the Commission-adopted FY 2023-24 to FY 2032- 33 10- Year Financial Plan to project revenue contributions from customer classes. Detailed line items of the revenue requirement distribution process are included in Attachment 2. FY 2023-24 CleanPowerSF Cost Functionalization, Classification, and Allocation.

In designing rates, Staff analyzed the bill impact to CleanPowerSF customers of the proposed FY 2023-24 rates, compared CleanPowerSF customers’ bills to those of PG&E , and evaluated revenue projection to ensure that revenue requirement was met.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

Revenue Requirement
The CleanPowerSF revenue requirement from retail sales for FY 2023-24 is estimated to be approximately $369 million. Costs include purchases of renewable energy, shaped energy 1, capacity, wholesale energy market costs, contingency, and operating and other costs.

Total power supply costs make up the biggest share ( 83%) of revenue requirement for CleanPowerSF in FY 2023-24. Operating and other costs (17%) include labor, operations , and capital spending.

Anticipated contributions to internal reserves are also included in the operating and other costs category. When including only operating and capital expenditures, total power supply costs make up about 91%, while other operating and capital costs make up the remaining 9%.

Compared to projections at the time of the Study, FY 2022- 23 and FY 2023-24 power supply costs have significantly increased by $22 million and $67 million, respectively. Since completion of the Study, volatility of P ower supply prices has continued and
increased by
approximately 60%.

Energy Demand and Usage
The Study found that while the peak energy demand for
CleanPowerSF customers occur s in December, peak demand for CleanPowerSF is relatively constant throughout the year.

As for energy sales volumes , Staff updated FY 2023- 24 projections from the Commission -adopted FY 2023- 24 to FY 2032- 33 10- Year Financial Plan to project revenue contributions from customer classes.

The following table summarizes CleanPowerSF customers’ projected energy usage for major customer classes for FY 2023-24.

Customer Class No. of
Customers
Total Usage for
Customer Class
(MWh/Yr)
Residential 357,359 1,250,347
Small Commercial 27,127 425,734

1 Shaped energy is additional energy to supplement an intermittent resource to fulfill a predictable delivery quantity and schedule.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

Medium Commercial 2,108 347,581
Medium Commercial High 7,302 603,806
Large Commercial 115 272,876
Outdoor Lighting 202 1,476
Total 394,213 2,901,820

Rate Design
Current Rate Structure
CleanPowerSF rate schedules are grouped by customer class into the following categories:
• Residential
• Small commercial
• Medium commercial – low demand (up to 499 kW)
• Medium commercial – high demand
• Large commercial
• Outdoor lighting
The default product offered by CleanPowerSF is the “Green” energy product, which contains a minimum of 50% California Renewable Portfolio Standa rd-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 and greenhouse gas free as a premium product. The SuperGreen product is sold as a voluntary rate rider, which is added to the standard Green energy product rate.

Proposed CleanPowerSF FY 2023-24 Rates
In the Study, the consultant averaged revenue requirement ($302.4 million) and calculated an effective cost of service rate per customer class for the period. T he Study rate plan move d existing FY 2021-22 rates toward cost of service from the
existing effective rate for the
class by approximately 50% in FY 2022-23 to provide a smooth transition for customers while ensuring the program was building its reserve, then to the averaged cost of service rates in FY 2023-24.

CleanPowerSF generation rates decreased in FY 2022-23 by about 8% for residential customers and by a range of 11% -15% for commercial customers.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

At the time of the Study, CleanPowerSF generation rates were anticipated to further decrease in FY 2023- 24 by about 9% for residential customers and by a range of 13% -18% for commercial customers. However, to adapt to the fast -changing energy markets and costs driven by the continued volatile power supply market , a rate decrease for next fiscal year is no longer sustainable . After a revised analysis, Staff is proposing CleanPowerSF generation rates for FY 2023-24 t hat increase by about 15% system wide from FY 2022-23 rates. This aligns with the adopted rate change proposal in the 10-Year Financial Plan, balancing financial sustainability of the CleanPowerSF program with impact on customer bills . The wide swing in rates needed from the time of the Study is primarily driven by the volatile nature of the power supply market due to the changing environment caused by geopolitical conflict.

The following table shows proposed effective CleanPowerSF Green generation rates by customer class. Because CleanPowerSF generation charges only make up a portion of the customer’s total bill, a verage customers on residential rate schedules will see about 4% -7% increase in total bill, and average customers on key com mercial rate schedules will see about 3%-8% increase in total bill.

Customer Class FY 2023-24
Green Rates
% Generation
Rate Change
Residential $0.13748 16%
Small General
Service $0.12431 13%
Medium General
Service - Low $0.12099 7%
Medium General
Service - High $0.11936 17%
Large General
Service $0.10586 6%
Agriculture $0.09065 8%
Street Lighting $0.12559 21%
Traffic Control $0.12559 14%

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

Customer Bill Comparison
Staff compared CleanPowerSF customer bills with proposed FY 2023- 24 rates to those of PG&E. Except for two rate schedules – Streetlights and E-EV: Residential Rates for Electric Vehicle Owners 2 – CleanPowerSF customers are projected to have lower total bi lls with proposed CleanPowerSF FY 2023- 24 generation rates for average customers than comparable PG&E current rates (effective March 2023).

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 rate s and PCIA make up the generation component of a PG&E generation customer’s bill.3 The delivery component of a customer’s bill will be the same whether the customer receives their generation service from CleanPowerSF or PG&E.

To support the City’s climate action goals, Staff proposes rebalancing4 the residential rate schedule, E- EV: Residential Rates for Electric Vehicle Owners. Prior to rebalancing, an average CleanPowerSF E-EV customer would have experienced a total bill about 6% higher than a PG&E customer. After rebalancing of rates, an average CleanPowerSF E-EV customer would see a revised total bill about 0.4% lower than a PG&E customer. 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 on average are projected to have lower total bills with the proposed CleanPowerSF FY 2023-24 generation rates compared to PG&E rates (effective March 2023) , except for streetlights which will have about a 1% higher bill.

2 E-EV has two schedules: E-EV-A and E-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. E- EV-2, a different electric vehicle rate schedule from E-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 E -EV- A schedule, with the same rates and time-of-use periods as E-EV-B, where customers may have either type of meter. 3 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. 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 2023-24 Commission Meeting Date: May 9, 2023

SuperGreen Premium
SuperGreen rates were also evaluated in the Study and deemed to meet cost of service. Staff proposes to keep SuperGreen residential rates at the current premium of $0.010/kW h and commercial rates at $0.005/kWh.

Rate Time Period
Continued volatility in ener gy 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 2023-24. 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 2024-25.

Temporary Rates fo
r New Rate Schedules
A key outcome of the Study for CleanPowerSF was to set its annual retail rates to its cost of providing service to customers and no longer follow PG&E’s multiple rate changes throughout the fiscal year as was the methodology prior to the Study. Unlike Hetch Hetchy Power however, CleanPo
werSF provides only the generation services to
customers, where PG&E remains the delivery service provider and the biller of CleanPowerSF customers. As such, CleanPowerSF ’s suite of rate schedules and rate structures match those of PG&E.

PG&E may occasionally adopt new rate schedules, such as the Electric Home (E-ELEC) rate schedule implemented in December 2022. When PG&E offers a new rate schedule, CleanPowerSF has a competitive need to implement its own companion generation rates for the new rate schedule; if it does not, then customers who wish to sign up for the new offering must opt out and return to PG&E . To avoid this, Staff recommends CleanPowerSF implement a new rate schedule and offer cost-of-service based generation rates when the California Publi c Utilities Commission authorizes PG&E to implement a
new rate
schedule to (1) provide an alternative generation service for customers, (2) prevent potential opt-outs of CleanPowerSF customers if they were to choose to sign up for the new rate schedule, and (3) support the City’s Climate Action Plan to reduce emissions by moving toward higher renewable content energy.

To streamline the process of offering CleanPowerSF generation rates when PG&E offers a new rate schedule, Staff recommends the Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

Commission adopt a mechanism to establish temporary rate s for new rate schedules based on the applicable customer class rate that has been adopted and is in effect.

The new rate schedule methodology is defined as: (1) calculating the ratios of PG&E’s generation rate components in the new rate schedule to PG&E’s default rate schedule in the applicable customer class and (2) applying the resulting ratios in Step 1 to CleanPowerSF’s comparable default generation rate in the same customer class to s et the CleanPowerSF generation rates for the new rate schedule.

The proposed methodology uses CleanPowerSF’s cost -of-service customer class rate that is in effect to set a new rate schedule that does not yet have a customer usage profile. This methodology was used for the Electric Home (E -ELEC) rate schedule, which the Commission adopted in Resolution 23-0015 on January 10, 2023.

Staff propose s this met hodology to offer temporary CleanPowerSF generation rates until the next comprehensive retail rates setting so customers have an alternative clean energy power supply provider when new rate schedules arise during the fiscal year.

Staff proposes for the Co mmission to authorize the General Manager effective July 1, 2023 to implement this temporary rate setting process.

Public Outreach and Education
SFPUC staff engaged customers and the general public on the Power Rates Study through a variety of public meetings.

The agency’s Rate Fairness Board has been the primary public venue where CleanPowerSF’s FY 2023- 24 rate -setting methodology, objectives, and preliminary analysis have been discussed. Near-final results of FY 2023- 24 rates were presented to Rate Fair ness Board
members on Tues day, April 11, 2023. SFPUC staff also presented to the agency’s Power Subcommittee of the Citizens’ Advisory Committee (CAC) on Tuesday, April 11, 2023.

Once rates are formally adopted, CleanPowerSF will communicate the rate change to customers through a variety of channels: website, email, bill message, and social media. SFPUC staff will also proactively engage key customer accounts as necessary. Residential customers will also be reminded about ava ilable discount programs and other ways to save on their monthly electricity bill.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

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 13, 14, 16, 19, and 20, 2023, and posted on the SFPUC website and at the San Francisco Public Library, for a public hearing on May 9th, with possible Commission action on this date. If approved by the Commission, these rates and charges will be subjec t to rejection by the Board of Supervisors (BOS), as provided in Charter section 8B.125, within 30 days following notification to the BOS.

Absent BOS rejection, t hese proposed CleanPowerSF rates will become effective July 1, 2023, and will remain effective until revised.

Board of Supervisors Review
Pursuant to Charter Section 8B.125, Commission action adopting rates and charges, including provisions for future periodic adjustments, is subject to rejection by the BOS within 30 days of submission to the BOS.

Funding and Costs: There are no additional costs to adoption of the CleanPowerSF rates.

Environmental
Review:

On April 24, 2023 the San Francisco Planning Department determined the Project to be statutorily exempt from environmental review under the CEQA Section 21080(b)(8) and CEQA Guidelines Section 15273 (Rates, Tolls, Fares and Charges) ( Case Number 2023-003617ENV) related to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or other charge s. The exemption can be found here:
https://sfpuc.sharefile.com/d-s21497fdd99f44cd7a395b51983319ba5

This action constitutes the Approval Action for the project for the purposes of the California Environmental Quality Act (CEQA) pursuant to Section 31.04(h) of the San Francisco Administrative Code.

Result of Inaction: A delay or denial in approving this agenda item will result in no CleanPowerSF rate changes for customers as of July 1, 2023 and will adversely impact the SFPUC’s ability to meet projected revenue requirements for CleanPowerSF Program of the Power Enterprise.

Recommendation: SFPUC staff recommends that the Commission adopt the attached resolution.

Public Hearing: Adopt CleanPowerSF Rates for FY 2023-24 Commission Meeting Date: May 9, 2023

Attachments: 1. FY 2023-24 CleanPowerSF Revenue Requirement

2. FY 2023-24 CleanPowerSF Cost Functiona lization,
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 reco mmended 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 proposes 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, CleanPowerSF’s suite of rate schedules matches to that of Pacific Gas and Electric ( PG&E) as PG&E remains the delivery service provider and biller of CleanPowerSF customers; and
WHEREAS, PG&E offers a new rate schedule occasionally after California Public Utilities Commission approval; and
WHEREAS, Staff proposes for the Commission to establish a mechanism to temporarily implement a comparable new rate schedule for CleanPowerSF customers when PG&E offers a new rate schedule to customers so as to (1) provide an alternative generation service for customers, (2) prevent potential opt -outs of CleanPowerSF customers if they were to choose to sign up for the new rate schedule, and (3) support the City’s Climate Action Plan to reduce emissions by moving toward higher renewable content energy; and WHEREAS, Upon PG&E’s implementation of a new rate schedule, Staff proposes to set CleanPowerSF generation rates using a new rate schedule methodology: (1) calculate 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) apply 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 11, 2023; and WHEREAS, The General Manager and the Rate Fairness Board find that CleanPowerSF revenues under existing rates will be insufficient to meet revenue requirements of CleanPowerSF program’s 10- Year Financial Plan, and recommend adjustments to CleanPowerSF rates applicable effective on July 1, 2023; 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 13, 14, 16, 19, and 20, 2023, and posted on the SFPUC website and at the San Francisco Public Library, as required, for a public hearing on May 9, 2023; 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 meetings were held at Rates Fairness Board meetings on March 17, 2023 and April 11, 2023, 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 24, 2023 the San Francisco Planning Department determined the Project to be statutorily exempt from environmental review under the California Environmental Quality Act ( CEQA) s ection 21080(b)(8) and CEQA Guidelines s ection 15273 (Rates, Tolls, Fares and Charges) (Case Number 2023-003617ENV) 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 establis h 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 obtaining funds for capita l projects necessary to maintain service within existing service areas; and (4) obtaining funds necessary to maintain such intra - city transfers as are authorized by the City Charter; 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, 2023; and be it FURTHER RESOLVED, That the Commission authorizes the General Manager effective July 1, 2023 to implement a new rate schedule for CleanPowerSF when PG&E offers a new rate schedule, as approved by the California Public Utilities Commission; and be it FURTHER RESOLVED, That upon implementation of a new rate schedule for CleanPowerSF prior to a comprehensive rates -setting process, CleanPowerSF generation rates

shall be set temporarily as presented in Section 5 until the next comprehensive rates -setting process:

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 f
or 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
Charges for residential customers based on meter readings effective July 1, 2023 are as follows:

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 23-24 Rate
All Energy $0.13748 /kWh
Schedule E-TOU-C: Residential Time-of-Use
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19422/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.13662/kWh All other hours
Winter Energy Charge

October 1—May 31
Peak $0.14166/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.12547/kWh All other hours
Schedule E-TOU-D: Residential Time-of-Use Peak Pricing 5-8pm (Non-Holiday Weekends) Rate Component FY 23-24 Rate Time of Use

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.22466/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.11219/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.18087/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.14328/kWh All other hours including holidays Schedule 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 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.33895/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.17222/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.11833/kWh All other hours
Winter Energy Charge November 1—April 30
Peak $0.11359/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.08471/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.08471/kWh All other hours
Schedule EV-2: Residential Time-of-Use for Plug-In Electric Vehicle Customers Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.22288/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.17249/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.12611/kWh All other hours
Winter Energy Charge October 1—May 31

Rate Component FY 23-24 Rate Time of Use
Peak $0.15876/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.14470/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.11823/kWh All other hours
Schedule E-6: Residential Time-of-Use Service
Schedule E-6 is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.29023/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Part-Peak $0.19757/kWh
2:00pm to 4:00pm and 9:00pm to 10:00pm, Monday
through Friday (except holidays)
5:00pm to 8:00pm, Saturday and Sunday (except
holidays)
Off-Peak $0.11916/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Part-Peak $0.16103/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.12326/kWh All other hours including holidays 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 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.28183/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.14338/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.16259/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.11893/kWh All other hours including holidays Schedule E-ELEC: Residential Home Electrification
Schedule E-ELEC applies to customers that have EV charging, a home electric battery, electric heat pump space conditioning, and/or electric heat pump water heating.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.27068/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.17543/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.13208/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11486/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.09567/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.08284/kWh All other hours
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 Commercial
Charges for Small Commercial customers based on meter readings on July 1, 2023 are as follows:

Schedule B-1: Small General Service
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.18393/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.13580/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.11545/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.12991/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.11415/kWh All other hours
Super Off-Peak $0.09810/kWh 9:00am to 2:00pm, every day in March—May Schedule B-1-ST: Small General Service with Storage
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19110 /kWh 4:00pm to 9:00pm, every day
Part-Peak $0.14902/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.11359/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.14098/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.12874/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.10694/kWh All other hours
Super Off-Peak $0.09067/kWh 9:00am to 2:00pm, every day in March—May

Schedule B-6: Small General Time-of-Use Service
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19485/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.12198/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.12981/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.11234/kWh All other hours
Super Off-Peak $0.09554/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 23-24 Rate Time of Use
Summer Energy Charge $0.14801/kWh May 1—October 31
Winter Energy Charge $0.10675/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 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.15623/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.15623/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.13000/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.12359/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.12299/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 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.21024/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.16083/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.12866/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.11927/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.11856/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 23-24 Rate
SuperGreen $0.00500/kWh

Medium Commercial – Low Demand (75-500 kW)
Charges for Medium Commercial – Low Demand customers based on meter readings on July 1, 2023 are as follows:

Schedule B-10: Medium General Demand Metered Service
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.19242/kWh
Primary $0.17684/kWh
Transmission $0.15521/kWh
Part-Peak

2:00pm to 4:00pm and 9:00pm to 11:00pm, every
day
Secondary $0.13728/kWh
Primary $0.12474/kWh
Transmission $0.10449/kWh
Off-Peak

All other hours
Secondary $0.10817/kWh
Primary $0.09717/kWh
Transmission $0.07761/kWh
Winter Energy Charge

October 1—May 31
Peak

4:00pm to 9:00pm, every day
Secondary $0.14053/kWh
Primary $0.12800/kWh
Transmission $0.10779/kWh
Off-Peak

All other hours
Secondary $0.10882/kWh
Primary $0.09795/kWh
Transmission $0.07844/kWh
Super Off-Peak

9:00am to 2:00pm, every day in March—May
Secondary $0.07634/kWh
Primary $0.06547/kWh
Transmission $0.04595/kWh

Schedule A-10-A: Medium General Demand-Metered Service
Schedule A-10-A is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge

May 1—October 31
Secondary $0.13350/kWh
Primary $0.11846/kWh
Transmission $0.10002/kWh
Winter Energy Charge

November 1—April 30
Secondary $0.11352/kWh
Primary $0.10117 kWh
Transmission $0.08430/kWh
Schedule A-10-B: Medium General Demand-Metered Service
Schedule A-10-B is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.15153/kWh
Primary $0.13631/kWh
Transmission $0.11835/kWh
Part-Peak

8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.15153/kWh
Primary $0.13631/kWh
Transmission $0.11835/kWh
Off-Peak

All other hours including holidays
Secondary $0.12599/kWh
Primary $0.11217/kWh
Transmission $0.09484/kWh
Winter Energy Charge

November 1-April 30
Part-Peak

8:30am to 9:30pm, Monday through Friday (except
holidays)
Secondary $0.11851/kWh
Primary $0.10510/kWh
Transmission $0.08795/kWh

Rate Component FY 23-24 Rate Time of Use
Off-Peak

All other hours including holidays
Secondary $0.11784/kWh
Primary $0.10447/kWh
Transmission $0.08732/kWh
Medium Commercial – Low Demand SuperGreen Premium
Medium Commercial – 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 23-24 Rate
SuperGreen $0.00500/kWh

Medium Commercial – High Demand (500-1000 kW)
Charges for Medium Commercial – High Demand customers based on meter readings on July 1, 2023 are as follows:

Schedule B-19: Medium General Demand-Metered Time-of-Use Service Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.14613/kWh
Primary $0.12772/kWh
Transmission $0.11598/kWh
Part-Peak - Energy

2:00pm to 4:00pm and 9:00pm to 11:00pm,
every day
Secondary $0.11076/kWh
Primary $0.10080/kWh
Transmission $0.10467/kWh
Off-Peak - Energy

All other hours
Secondary $0.08577/kWh
Primary $0.07740/kWh
Transmission $0.08057/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $26.74/kW
Primary $22.91/kW
Transmission $18.05/kW
Part-Peak - Demand 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $3.89/kW
Primary $3.35/kW
Transmission $4.51/kW
Winter Energy Charge

October 1—May 31
Peak - Energy

4:00pm to 9:00pm, every day
Secondary $0.12367/kWh
Primary $0.11312/kWh
Transmission $0.11749/kWh
Off-Peak - Energy

All other hours

Rate Component FY 23-24 Rate Time of Use
Secondary $0.08566/kWh
Primary $0.07756/kWh
Transmission $0.08089/kWh
Super Off-Peak - Energy

9:00am to 2:00pm, every day in March—May
Secondary $0.03468/kWh
Primary $0.02695/kWh
Transmission $0.02704/kWh
Winter Demand Charge October 1—May 31
Peak - Demand

4:00pm to 9:00pm, every day
Secondary $3.18/kW
Primary $2.34/kW
Transmission $1.73/kW

Schedule B -19-R/B-19-S: Medium General Demand -Metered Time-of- Use Servic e, Solar/Storage
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.27671/kWh
Primary $0.25340/kWh
Transmission $0.22054/kWh
Part-Peak

2:00pm to 4:00pm and 9:00pm to 11:00pm, every
day
Secondary $0.14301/kWh
Primary $0.13156/kWh
Transmission $0.14017/kWh
Off-Peak All other hours
Secondary $0.10503/kWh
Primary $0.09666/kWh
Transmission $0.09859/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.14670/kWh
Primary $0.13390/kWh
Transmission $0.13202/kWh
Off-Peak All other hours
Secondary $0.10497/kWh
Primary $0.09677/kWh
Transmission $0.09881/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.06965/kWh
Primary $0.06144/kWh
Transmission $0.06348/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 23-24 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 $0.10413/kWh
Primary $0.09152/kWh
Transmission $0.08167/kWh
Part-Peak - Energy 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.10413/kWh
Primary $0.09152/kWh
Transmission $0.08167/kWh
Off-Peak - Energy
9:30pm to 8:30am, Monday through Friday (except
holidays)
All day, Saturday through Sunday and holidays
Secondary $0.09785/kWh
Primary $0.08551/kWh
Transmission $0.07572/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $10.69/kW
Primary $9.28/kW
Transmission $10.25/kW
Part-Peak - Demand 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $10.69/kW
Primary $9.28/kW
Transmission $10.25/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.09512/kWh
Primary $0.08291/kWh
Transmission $0.07316/kWh
Off-Peak - Energy 9:30pm to 8:30 am, Monday through Friday

Rate Component FY 23-24 Rate Time of Use
(except holidays)
All day, Saturday through Sunday and holidays
Secondary $0.09438/kWh
Primary $0.08220/kWh
Transmission $0.07247/kWh

Schedule E-19-R: Medium General Demand-Metered Time-of-Use Service with Solar Schedule E-19-R is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.16657/kWh
Primary $0.16580/kWh
Transmission $0.16057/kWh
Part-Peak 8:30am to 12:00 noon & 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.14932/kWh
Primary $0.14887/kWh
Transmission $0.14566/kWh
Off-Peak 9:30pm to 8:30am, Monday through Friday (except holidays)
All day, Saturday through Sunday and holidays
Secondary $0.12021 /kWh
Primary $0.12040/kWh
Transmission $0.12076/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.11763/kWh
Primary $0.11768/kWh
Transmission $0.11809/kWh
Off-Peak 9:30pm to 8:30 am, Monday through Friday (except holidays)
All day, Saturday through Sunday and holidays
Secondary $0.11692/kWh
Primary $0.11695/kWh
Transmission $0.11736/kWh

Medium Commercial – High Demand SuperGreen Premium
Medium Commercial – 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 23-24 Rate
SuperGreen $0.005/kWh

Large Commercial
Charges for Large Commercial customers based on meter readings on July 1, 2023 are as follows:

Schedule B-20: Service to Customers with Maximum Demands of 1000 Kilowatts or More Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.12254/kWh
Primary $0.11951/kWh
Transmission $0.10051/kWh
Part-Peak - Energy 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.09453/kWh
Primary $0.08974/kWh
Transmission $0.08216/kWh
Off-Peak - Energy All other hours
Secondary $0.07241/kWh
Primary $0.06896/kWh
Transmission $0.06165/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $27.81/kW
Primary $30.64/kW
Transmission $34.68/kW
Part-Peak - Demand 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $4.04/kW
Primary $4.20/kW
Transmission $8.26/kW
Winter Energy Charge October 1—May 31
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.10586/kWh
Primary $0.10056/kWh
Transmission $0.09962/kWh
Off-Peak - Energy All other hours
Secondary $0.07224/kWh
Primary $0.06903/kWh

Rate Component FY 23-24 Rate Time of Use
Transmission $0.05794/kWh
Super Off-Peak - Energy 9:00am to 2:00pm, every day in March—May Secondary $0.02719/kWh
Primary $0.02428/kWh
Transmission $0.01631/kWh
Winter Demand Charge October 1—May 31
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $3.55/kW
Primary $3.52/kW
Transmission $4.63/kW

Schedule B-20-R/B-20-S: Service to Customers with Maximum Demands of 1000 Kilowatts or More, Solar/Storage
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.25077/kWh
Primary $0.24967/kWh
Transmission $0.25951/kWh
Part-Peak 2:00pm to 4:00pm & 9:00pm to 11:00pm, every day Secondary $0.12649/kWh
Primary $0.12538/kWh
Transmission $0.14012/kWh
Off-Peak All other hours
Secondary $0.09142/kWh
Primary $0.09190/kWh
Transmission $0.08955/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.13223/kWh
Primary $0.13059/kWh
Transmission $0.13997/kWh
Off-Peak All other hours
Secondary $0.09129/kWh
Primary $0.09194/kWh
Transmission $0.08660/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.05782/kWh
Primary $0.05747/kWh
Transmission $0.05360/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 23-24 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 $0.08249/kWh
Primary $0.07962/kWh
Transmission $0.06840/kWh
Part-Peak - Energy 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.08249/kWh
Primary $0.07962/kWh
Transmission $0.06840/kWh
Off-Peak - Energy All other hours
Secondary $0.07731/kWh
Primary $0.07458/kWh
Transmission $0.06344/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $13.93/kW
Primary $14.89/kW
Transmission $17.73/kW
Part-Park - Demand 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $13.93/kW
Primary $14.89/kW
Transmission $17.73/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07504/kWh
Primary $0.07242/kWh
Transmission $0.06131/kWh
Off-Peak - Energy 9:30pm to 8:30am, Monday through Friday, All day, Saturday through Sunday and holidays

Rate Component FY 23-24 Rate Time of Use
Secondary $0.07442/kWh
Primary $0.07183/kWh
Transmission $0.06073/kWh

Schedule E-20-R: Service to Customers with Maximum Demands of 1000 Kilowatts or More, with Solar
Schedule E-20-R is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.14897/kWh
Primary $0.15276/kWh
Transmission $0.15466/kWh
Part-Peak 8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.13431/kWh
Primary $0.13533/kWh
Transmission $0.13638/kWh
Off-Peak All other hours
Secondary $0.10784/kWh
Primary $0.10763/kWh
Transmission $0.10762/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.10530/kWh
Primary $0.10516/kWh
Transmission $0.10507/kWh
Off-Peak 9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.10461/kWh
Primary $0.10450/kWh
Transmission $0.10439/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 23-24 Rate
SuperGreen $0.00500/kWh

Business Electric Vehicles
Charges for Business Electric Vehicle customers based on meter readings on July 1, 2023 are as follows:

Schedule BEV-1: Business Electric Vehicles Secondary Voltage Rate Component FY 23-24 Rate Time of Use
Peak Energy Charge $0.23725/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.08035/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05853/kWh All other hours Schedule BEV-2-S Business Electric Vehicles Secondary Voltage Rate Component FY 23-24 Rate Time of Use
Peak Energy Charge $0.25471/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.07800/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05593/kWh All other hours Schedule BEV-2-P Business Electric Vehicles Primary or Transmission Voltage Rate Component FY 23-24 Rate Time of Use
Peak Energy Charge $0.24569/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.07540/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05437/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 optio n will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:

Rate Component FY 23-24 Rate
SuperGreen $0.00500/kWh

Agriculture
Charges for Agriculture customers based on meter readings on July 1, 2023 are as follows:

Schedule AG-A: Time-of-Use Agricultural Power
Applies to PG&E rate schedules AG-A1 and AG-A2.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.24238/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.11992/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11652/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08946/kWh All other hours
Schedule AG-B: Time-of-Use Agricultural Power
Rate Component FY 23-24 Time of Use
Summer Energy Charge June 1—September 30
Peak $0.22805/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.11780/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11302/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08955/kWh All other hours
Schedule AG-C: Time-of-Use Agricultural Power
Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.11193/kWh 5:00pm to 8:00pm, every day Off-Peak - Energy $0.08379/kWh All other hours
Summer Demand Charge June 1—September 30
Peak - Demand $10.58/kW 5:00pm to 8:00pm, every day
Winter Energy Charge October 1—May 31
Peak $0.09795/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.07360/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.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21239/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.13146/kWh All hours, Option 1, 2 or 3
Winter Energy Charge

October 1—May 31
Peak $0.12076/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.09300/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.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.20005/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.12674/kWh All other hours, Option 1, 2 or 3 Winter Energy Charge

October 1—May 31
Peak $0.11586/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.09203/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.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.10926/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.08550/kWh All other hours, Option 1, 2 or 3 Summer Demand Charge June 1—September 30
Peak - Demand $10.58/kW 5:00pm to 8:00pm, every day except off-peak days Winter Energy Charge October 1—May 31
Peak - Energy $0.09785/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.07691/kWh All other hours, Option 1, 2 or 3 Schedule AG-5A: Large Time-of-Use Agricultural Power
Applies to PG&E rate schedules AG-5A and AG-5D. Schedule AG-5A is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.13232/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Off-Peak $0.11178/kWh All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Connected Load Summer $8.66/kW May 1—October 31
Winter Energy Charge November 1—April 30
Part-Peak $0.10198/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.10120/kWh All other hours, Monday through Friday All day, Saturday through Sunday and holidays

Schedule AG-5B: Large Time-of-Use Agricultural Power
Applies to PG&E rate schedules AG-5B and AG-5E. Schedule AG-5B is a legacy rate that is closed to new customers.

Rate Component FY 23-24 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 $0.10273/kWh
Primary $0.10273/kWh
Transmission $0.10273/kWh
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.08116/kWh
Primary $0.08116/kWh
Transmission $0.08116/kWh
Maximum - Demand All hours
Secondary $10.99/kW
Primary $7.53/kW
Transmission $5.00/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07766/kWh
Primary $0.07766/kWh
Transmission $0.07766/kWh
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.07705/kWh
Primary $0.07705/kWh
Transmission $0.07705/kWh

Schedule AG-5C: Large Time-of-Use Agricultural Power
Applies to PG&E rate schedules AG-5C and AG-5F. Schedule AG-5C is a legacy rate that is closed to new customers.

Rate Component FY 23-24 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 $0.08109/kWh
Primary $0.08109/kWh
Transmission $0.08109/kWh
Part-Peak - Energy 8:30 am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.06962/kWh
Primary $0.06962/kWh
Transmission $0.06962/kWh
Off-Peak - Energy 9:30pm to 8:30am, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.06535/kWh
Primary $0.06535/kWh
Transmission $0.06535/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $10.29/kW
Primary $9.44/kW
Transmission $8.71/kW
Part-Peak - Demand 8:30 am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $8.22/kW
Primary $8.22/kW
Transmission $8.22/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.06718/kWh
Primary $0.06718/kWh
Transmission $0.06718/kWh

Rate Component FY 23-24 Rate Time of Use
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.06654/kWh
Primary $0.06654/kWh
Transmission $0.06654/kWh
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 23-24 Rate
SuperGreen $0.00500/kWh

Lighting and Traffic Controls
Charges for Lighting and Traffic Control customers based on meter readings on July 1, 2023 are as follows:

Schedule SL-1: Street and Highway Lighting
Applies to PG&E rate schedules LS-2, SL-3, and OL-1.

Rate Component FY 23-24 Rate
All Energy $0.12559/kWh
Schedule TC-1: Traffic Control Service
Rate Component FY 23-24 Rate
All Energy $0.12559/kWh
Schedule A-15: Direct-Current Lighting Service
Schedule A-15 is a legacy rate that is unavailable to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy $0.12992/kWh June 1-September 30
Winter Energy $0.11091/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 23-24 Rate
SuperGreen $0.00500/kWh

Standby Charges
Standby rates apply to Full Standby customers under Rate Schedule. All partial standby customers are billed at their Otherwise Applicable Schedule (OAS) rate. SuperGreen premium charged at your OAS rate premium.

Charges for Standby customers based on meter readings on July 1, 2023 are as follows:

Schedule SEM: Residential Multi Meter Standby
Rate Component FY 23-24 Rate Time of Use
Reservation Charge $0.70/kW Year-Round
Energy Charge $0.13770/kWh All hours

S
chedule B-ST: Standby Service
Applies to PG&E rate schedule SB.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.11840/kWh
Primary $0.11840/kWh
Transmission $0.10281/kWh
Part-Peak 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.10464/kWh
Primary $0.10464/kWh
Transmission $0.08956/kWh
Off-Peak All other hours
Secondary $0.08933/kWh
Primary $0.08933/kWh
Transmission $0.07481/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.11290/kWh
Primary $0.11290/kWh
Transmission $0.09760/kWh
Off-Peak All other hours
Secondary $0.09062/kWh
Primary $0.09062/kWh
Transmission $0.07618/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.04117/kWh
Primary $0.04117/kWh
Transmission $0.02722/kWh
Reservation Charge Year-Round
Secondary $0.40/kW
Primary $0.40/kW
Transmission $0.23/kW

Schedule S-B: Standby Service
Applies to PG&E’s rate schedule S. Schedule S-B is a legacy rate that is closed to new customers.

Rate Component FY 23-24 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.20864/kWh
Primary $0.20864/kWh
Transmission $0.21004/kWh
Part-Peak

8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.17214/kWh
Primary $0.17214/kWh
Transmission $0.17283/kWh
Off-Peak

9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.12436/kWh
Primary $0.12436/kWh
Transmission $0.12358/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.17796/kWh
Primary $0.17796/kWh
Transmission $0.17869/kWh
Off-Peak

9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.14094/kWh
Primary $0.14094/kWh
Transmission $0.14086/kWh
Reservation Charge Year-Round
Secondary $0.84/kW
Primary $0.84/kW
Transmission $0.75/kW

Section 3 – Net Energy Metering Ta riff
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, NEM2
5, or other NEM programs (PG&E NEM), and install a
Renewable Electrical Generation Facility.

This Schedule is available upon request, on a first-come, first-served basis to eligible CleanPowerSF customers that provide PG&E with a completed PG&E NEM Application and comply with all PG&E NEM requirements of the applicable NEM 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) 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 Tariff 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.

Definitions
“Annual True-up Period”
The twelve-month period commencing in May of each year. “Net Electricity Consumer”
NEM-CleanPowerSF customer that generates 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”

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

A NEM-CleanPowerSF customer that generates 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 of 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, charges incurred, credits generated during the current billing period, and remaining generation bill credits from previous billing cycles. The monetary value of any excess generation 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 generated 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 kilowatt -hours (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 generated 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 kilowatt -hours (kWh) produced shall be calculated based on the applicable time - of-use rate when the excess kilowatt-hours were produced. The customer will receive a net bill credit if

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.

the sum of CleanPowerSF electric generation charges and credits across all applicable TOU periods during the billing cycle is a net positive value.

2. All CleanPowerSF charges under the customer’s otherwise applicable rate schedule shall be in effect and all charges shall b e 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 net bill credits reflected on the customer’s bill will be carried over for use in subsequent billing period(s) throughout the Annual True -up Period until such credits are exhausted.

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. 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.

2. When the customer is a Net Electricity Consumer at the end of the Annual True -up Period, any net bill credit balances remaining at that time will be reset to zero for the beginning of the next True-Up Period.

3. When the custom er 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 during 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 23-24 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. In lieu of receiving a bill credit from CleanPowerSF, customers may elect to receive payment 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 the California Public Utilities Code Section 2827(h)(4)(B), aggregated NEM customers are “permanently ineligible to receive net surplus electricity compensation.” Thus, C leanPowerSF 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 (FF S) 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 municipalities for the purpose
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 sections, 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 in effect until repealed, modified or superseded. These rates will be applied to meter readings on or after July 1, 2023.

I hereby certify that the foregoing resolution was adopted by the Public Utilities Commission at its meeting of May 9, 2023.

______________________________________
Secretary, Public Utilities Commission
San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Revenue Requirement
FYE 2024
Supply Costs
Contracted Energy Non-Renewables 72,619,545$
Contracted Energy Renewables
sPower Raceway 9,700,810$
NextEra Blythe 5,236,233$
Terragen Voyager 7,742,194$
Terragen Oasis 8,898,731$
EDF Maverick 8,182,938$
Calpine Geysers (End 12/2029) 25,824,960$
HHP Sunset (end 11/25) 33,452$
CC Power Ormat 3462 (10/1/24-9/30/44) -$
CC Power OME 3482 (6/1/24-5/31/44) 96,626$
Paulsell 2.0 (20 MW PV, 15 MW Storage) 11,464$
-$
-$
-$
-$
Contracted Energy Renewables Total 65,727,407$

Spot Market Energy 80,288,353$
Resource Adequacy
Resource Adequacy Contracts 28,704,727$
Resource Adequacy Net Short 21,303,155$
Resource Adequacy Total 50,007,882$
San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Revenue Requirement
FYE 2024
Renewable & GHG-Free Attributes
Contracted RECs 4,904,874$
Incremental RPS RECs -$
Voluntary RECs (incl. losses) 1,144,367$
Incremental Super Green (incl. losses) -$
GHG-Free Attribute Contracts 2,048,369$
GHG-Free Attribute Net Short 986,566$
Renewable & GHG-Free Attributes Total 9,084,176$
Other Purchased Power & Supply Costs
CAISO Services 10,176,000$
Scheduling Coordinator (APX Collateral) -$
Other Purchased Power & Supply Costs Total 10,176,000$
Contingency 17,426,553$
Total Supply Costs 305,329,916$
Operating and Other Costs
Labor/Personnel 8,205,685$
Services of Bureaus 5,468,773$
Non-Personnel Services
Professional Services 3,766,899$
Calpine Data Manager Fees 4,825,005$
PG&E Service Fees 1,705,810$
Letter of Credit 339,349$
Miscellaneous 1,326,965$
Materials and Supplies 229,358$
San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Revenue Requirement
FYE 2024
Services of Other Departments
Hetch Hetchy 2,106,350$
City Attorney 1,200,000$
Repro (Marketing) 639,723$
All Other Departments 236,328$
Working Capital Interest -$
Total Operating Costs 30,050,245$
Uncollectible 3,690,298$
Working Capital Principal -$
Non-Debt Capital Expenditures 1,607,220$
Margin 31,397,059$
Total Expenditures 372,074,738$
(Less) Wholesale Revenue (1,581,686)$
(Less) Interest and Other Revenue (1,463,220)$
Retail Revenue Requirement 369,029,832$
CleanPowerSF Metrics
Beginning Fund Balance 65,187,124$
EOY Fund Balance 96,584,184$
Days of Cash on Hand 105

San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Cost Functionalization
FY 2023-24 Adjustments
Adjusted Test
Year Allocation Power Supply Customer
Direct
Assign Total
Supply Costs
Contracted Energy Non-Renewables 72,619,545$ -$ 72,619,545$ Pow er Supply 72,619,545$ -$ -$ 72,619,545$ Contracted Energy Renewables
sPower Raceway 9,700,810$ -$ 9,700,810$ Pow er Supply 9,700,810$ -$ -$ 9,700,810$ NextEra Blythe 5,236,233$ -$ 5,236,233$ Pow er Supply 5,236,233$ -$ -$ 5,236,233$ Terragen Voyager 7,742,194$ -$ 7,742,194$ Pow er Supply 7,742,194$ -$ -$ 7,742,194$ Terragen Oasis 8,898,731$ -$ 8,898,731$ Pow er Supply 8,898,731$ -$ -$ 8,898,731$ EDF Maverick 8,182,938$ -$ 8,182,938$ Pow er Supply 8,182,938$ -$ -$ 8,182,938$ Calpine Geysers (End 12/2029) 25,824,960$ -$ 25,824,960$ Pow er Supply 25,824,960$ -$ -$ 25,824,960$ HHP Sunset (end 11/25) 33,452$ -$ 33,452$ P ower Supply 33,452$ -$ -$ 33,452$ CC Power Ormat 3462 (10/1/24-9/30/44) -$ -$ -$ Power Supply -$ -$ -$ -$ CC Power OME 3482 (6/1/24-5/31/44) 96,626$ -$ 96,626$ P ower Supply 96,626$ -$ -$ 96,626$ Paulsell 2.0 (20 MW PV, 15 MW Storage) 11,464$ -$ 11,464$ P ower Supply 11,464$ -$ -$ 11,464$ -$ -$ -$ N/A -$ -$ -$ -$ Contracted Energy Renewables Total 65,727,407$ -$ 65,727,407$ 65,727,407$ -$ -$ 65,727,407$

Firming and Shaping 80,288,353$ -$ 80,288,353$ Pow er Supply 80,288,353$ -$ -$ 80,288,353$ Resource Adequacy
Resource Adequacy Contracts 28,704,727$ -$ 28,704,727$ Pow er Supply 28,704,727$ -$ -$ 28,704,727$ Resource Adequacy Net Short 21,303,155$ -$ 21,303,155$ Pow er Supply 21,303,155$ -$ -$ 21,303,155$ Resource Adequacy Total 50,007,882$ -$ 50,007,882$ 50,007,882$ -$ -$ 50,007,882$ Renewable & GHG-Free Attributes
Contracted RECs 4,904,874$ -$ 4,904,874$ Pow er Supply 4,904,874$ -$ -$ 4,904,874$ Incremental RPS RECs -$ -$ -$ N/A -$ -$ -$ -$ Voluntary RECs (incl. losses) 1,144,367$ -$ 1,144,367$ Pow er Supply 1,144,367$ -$ -$ 1,144,367$ Incremental Super Green (incl. losses) -$ -$ -$ Power Supply -$ -$ -$ -$ GHG-Free Attribute Contracts 2,048,369$ -$ 2,048,369$ Pow er Supply 2,048,369$ -$ -$ 2,048,369$ GHG-Free Attribute Net Short 986,566$ -$ 986,566$ P ow er Supply 986,566$ -$ -$ 986,566$ Renewable & GHG-Free Attributes Total 9,084,176$ -$ 9,084,176$ 9,084,176$ -$ -$ 9,084,176$ Other Purchased Power & Supply Costs
CAISO Services 10,176,000$ -$ 10,176,000$ Pow er Supply 10,176,000$ -$ -$ 10,176,000$ Scheduling Coordinator (APX Collateral) -$ -$ -$ N/A -$ -$ -$ -$ 1 Other Purchased Power & Supply Costs Total 10,176,000$ -$ 10,176,000$ 10,176,000$ -$ -$ 10,176,000$ Contingency 17,426,553$ -$ 17,426,553$ Pow er Supply 17,426,553$ -$ -$ 17,426,553$ Total Supply Costs 305,329,916$ -$ 305,329,916$ 305,329,916$ -$ -$ 305,329,916$ Operating and Other Costs
Labor/Personnel 8,205,685$ -$ 8,205,685$ Labo r 3,135,959$ 5,069,726$ -$ 8,205,685$ Services of Bureaus 5,468,773$ -$ 5,468,773$ Labo r 2,089,996$ 3,378,777$ -$ 5,468,773$ Non-Personnel Services
Professional Services 3,766,899$ -$ 3,766,899$ Pro f. Services 2,758,996$ 1,007,902$ -$ 3,766,899$ Calpine Data Manager Fees 4,825,005$ -$ 4,825,005$ Custo mer -$ 4,825,005$ -$ 4,825,005$ PG&E Service Fees 1,705,810$ -$ 1,705,810$ Custo mer -$ 1,705,810$ -$ 1,705,810$ Letter of Credit 339,349$ -$ 339,349$ P ow er Supply 339,349$ -$ -$ 339,349$ Miscellaneous 1,326,965$ -$ 1,326,965$ Rev Re q 1,238,628$ 88,337$ -$ 1,326,965$ Materials and Supplies 229,358$ -$ 229,358$ L abo r 87,654$ 141,704$ -$ 229,358$ Services of Other Departments
Hetch Hetchy 2,106,350$ -$ 2,106,350$ HHP La bor 1,764,372$ 341,978$ -$ 2,106,350$ City Attorney 1,200,000$ -$ 1,200,000$ City Attorney 792,232$ 407,768$ -$ 1,200,000$ Repro (Marketing) 639,723$ -$ 639,723$ C usto mer -$ 639,723$ -$ 639,723$ All Other Departments 236,328$ -$ 236,328$ L abo r 90,317$ 146,011$ -$ 236,328$ Working Capital Interest -$ -$ -$ N/A -$ -$ -$ -$ Total Operating Costs 30,050,245$ -$ 30,050,245$ 12,297,503$ 17,752,742$ -$ 30,050,245$ Uncollectible 3,690,298$ -$ 3,690,298$ Custo mer -$ 3,690,298$ -$ 3,690,298$ Working Capital Principal -$ -$ -$ N/A -$ -$ -$ -$ Non-Debt Capital Expenditures 1,607,220$ -$ 1,607,220$ Capi tal 371,119$ 1,236,101$ -$ 1,607,220$ Margin 31,397,059$ -$ 31,397,059$ Rev Re q 29,306,936$ 2,090,123$ -$ 31,397,059$ (Less) Other Revenues
Wholesale (1,581,686)$ -$ (1,581,686)$ P ow er Supply (1,581,686)$ -$ -$ (1,581,686)$ Interest and Other Revenues (1,463,220)$ -$ (1,463,220)$ Re v Re q (1,365,812)$ (97,408)$ -$ (1,463,220)$ Revenue Requirement from Rates 369,029,832$ -$ 369,029,832$ 344,357,975$ 24,671,857$ -$ 369,029,832$ Check -$
2 Direct Allocators
1 0 0 1
Power Supply Power Supply 100% 0% 0% 100%
0 1 0 1
Customer Customer 0% 100% 0% 100%
0 0 1 1
Direct Assign Direct 0% 0% 100% 100%
Derived Allocators
317,627,419$ 17,752,742$ -$ 335,380,161$ Total Operations & Maintenance Expense Total O&M 95% 5% 0% 100% 316,759,909$ 22,590,805$ -$ 339,350,714$ Revenue Requirement Rev Req 93% 7% 0% 100%
2,572,748$ 4,159,215$ -$ 6,731,963$ Labor Expense Labor 38% 62% 0% 100%
557,244$ 108,007$ 665,251$
HHP Labor Expense HHP Labor 84% 16% 0% 100%
751,226$ 386,662$ 1,137,888$
City Attorney Expense City Attorney 66% 34% 0% 100%
179,298$ 65,500$ 244,798$
Professional Services Prof. Services 73% 27% 0% 100%
438,377$ 1,460,120$ 1,898,497$
Capital Capital 23% 77% 0% 100%
3 San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Cost Classification: Power Supply Line Item FY 2023-24
Adjustment to
Move SG-
Related Renew
PPA RA Costs
Test Year 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 72,619,545$ -$ 72,619,545$ Green -$ -$ -$ 72,619,545$ -$ -$ -$ 72,619,545$ Contracted Energy Renewables
sPower Raceway 9,700,810$ (1,407,115)$ 8,293,695$ sPo wer SG -$ -$ -$ 7,132,577$ 1,161,117$ -$ -$ 8,293,695$ NextEra Blythe 5,236,233$ (583,480)$ 4,652,753$ Bly the SG -$ -$ -$ 3,582,619$ 1,070,133$ -$ -$ 4,652,753$ Terragen Voyager 7,742,194$ (896,240)$ 6,845,954$ Voy ager SG -$ -$ -$ 4,312,951$ 2,533,003$ -$ -$ 6,845,954$ Terragen Oasis 8,898,731$ (1,078,770)$ 7,819,961$ Oasi s SG -$ -$ -$ 5,395,773$ 2,424,188$ -$ -$ 7,819,961$ EDF Maverick 8,182,938$ (539,805)$ 7,643,133$ Mave rick SG -$ -$ -$ 6,649,526$ 993,607$ -$ -$ 7,643,133$ Calpine Geysers (End 12/2029) 25,824,960$ -$ 25,824,960$ Calpin e SG -$ -$ -$ 25,824,960$ -$ -$ -$ 25,824,960$ HHP Sunset (end 11/25) 33,452$ -$ 33,452$ S un set SG -$ -$ -$ -$ 33,452$ -$ -$ 33,452$ CC Power Ormat 3462 (10/1/24-9/30/44) -$ -$ -$ Calpine SG -$ -$ -$ -$ -$ -$ -$ -$ CC Power OME 3482 (6/1/24-5/31/44) 96,626$ -$ 96,626$ Ca lpin e SG -$ -$ -$ 96,626$ -$ -$ -$ 96,626$ Paulsell 2.0 (20 MW PV, 15 MW Storage) 11,464$ -$ 11,464$ C row Creek SG -$ -$ -$ 11,464$ -$ -$ -$ 11,464$ -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Contracted Energy Renewables Total 65,727,407$ (4,505,410)$ 61,221,997$ -$ -$ -$ 53,006,496$ 8,215,501$ -$ -$ 61,221,997$

Firming and Shaping 80,288,353$ -$ 80,288,353$ Fir m & Shape -$ -$ -$ 79,385,552$ -$ 902,801$ -$ 80,288,353$ Resource Adequacy
Resource Adequacy Contracts 28,704,727$ -$ 28,704,727$ Capa city Split 26,628,673$ 2,076,054$ -$ -$ -$ -$ -$ 28,704,727$ Resource Adequacy Net Short 21,303,155$ -$ 21,303,155$ Capa city Split 19,762,416$ 1,540,740$ -$ -$ -$ -$ -$ 21,303,155$ Shiloh -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Sunset -$ -$ -$ Sunset SG Cap -$ -$ -$ -$ -$ -$ -$ -$ Calpine Geysers -$ -$ -$ Calpine SG Cap -$ -$ -$ -$ -$ -$ -$ -$ NextEra Crow Creek 801 (11/23) (100%) +9k/mo -$ -$ -$ Capacity Split -$ -$ -$ -$ -$ -$ -$ -$ NextEra - Blythe IV (10/20) (90%) +9k/mo -$ 583,480$ 583,480$ Ca pa city Split 541,280$ 42,200$ -$ -$ -$ -$ -$ 583,480$ EDF - Maverick (12/21) (100%) -$ 539,805$ 539,805$ Ca pa city Split 500,764$ 39,041$ -$ -$ -$ -$ -$ 539,805$ sPower - Raceway (100%) -$ 1,407,115$ 1,407,115$ Capa city Split 1,305,346$ 101,769$ -$ -$ -$ -$ -$ 1,407,115$ Terragen Voyager (90%) -$ 896,240$ 896,240$ Ca pa city Split 831,420$ 64,820$ -$ -$ -$ -$ -$ 896,240$ Terragen Oasis (90%) -$ 1,078,770$ 1,078,770$ Capa city Split 1,000,749$ 78,021$ -$ -$ -$ -$ -$ 1,078,770$ Calpine Geysers Xtension -$ -$ -$ Calpine X SG Cap -$ -$ -$ -$ -$ -$ -$ -$ Intersect Aramis -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Resource Adequacy Total 50,007,882$ 4,505,410$ 54,513,292$ 50,570,647$ 3,942,645$ -$ -$ -$ -$ -$ 54,513,292$ Renewable & GHG-Free Attributes
Contracted RECs 4,904,874$ -$ 4,904,874$ Green -$ -$ -$ 4,904,874$ -$ -$ -$ 4,904,874$ Incremental RPS RECs -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Voluntary RECs (incl. losses) 1,144,367$ -$ 1,144,367$ Green -$ -$ -$ 1,144,367$ -$ -$ -$ 1,144,367$ Incremental Super Green (incl. losses) -$ -$ -$ Green -$ -$ -$ -$ -$ -$ -$ -$ GHG-Free Attribute Contracts 2,048,369$ -$ 2,048,369$ Green -$ -$ -$ 2,048,369$ -$ -$ -$ 2,048,369$ GHG-Free Attribute Net Short 986,566$ -$ 986,566$ G reen -$ -$ -$ 986,566$ -$ -$ -$ 986,566$ Renewable & GHG-Free Attributes Total 9,084,176$ -$ 9,084,176$ -$ -$ -$ 9,084,176$ -$ -$ -$ 9,084,176$ Other Purchased Power & Supply Costs
CAISO Services 10,176,000$ -$ 10,176,000$ Othe r Energy -$ -$ -$ -$ -$ -$ 10,176,000$ 10,176,000$ Scheduling Coordinator (APX Collateral) -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Other Purchased Power & Supply Costs Total 10,176,000$ -$ 10,176,000$ -$ -$ -$ -$ -$ -$ 10,176,000$ 10,176,000$ Contingency 17,426,553$ -$ 17,426,553$ PS C ont 3,060,999$ 238,645$ -$ 12,959,040$ 497,277$ 54, 646$ 615, 945$ 17, 426,553$ Total Supply Costs 305,329,916$ -$ 305,329,916$ 53,631,646$ 4,181,290$ -$ 227,054,809$ 8,712,778$ 957,447$ 10, 791,945$ 305,329,916$ 4 Operating and Other Costs
Labor/Personnel 3,135,959$ -$ 3,135,959$ Fi xed C harges -$ -$ 3,135,959$ -$ -$ -$ -$ 3, 135,959$ Services of Bureaus 2,089,996$ -$ 2,089,996$ Fi xed C harges -$ -$ 2,089,996$ -$ -$ -$ -$ 2, 089,996$ Non-Personnel Services
Professional Services 2,758,996$ -$ 2,758,996$ Fi xed C harges -$ -$ 2,758,996$ -$ -$ -$ -$ 2, 758,996$ Calpine Data Manager Fees -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ PG&E Service Fees -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Letter of Credit 339,349$ -$ 339,349$ Fixed C harges -$ -$ 339,349$ -$ -$ -$ -$ 339,349$ Miscellaneous 1,238,628$ -$ 1,238,628$ Fi xed C harges -$ -$ 1,238,628$ -$ -$ -$ -$ 1, 238,628$ Materials and Supplies 87,654$ -$ 87,654$ Fixed Charges -$ -$ 87,654$ -$ -$ -$ -$ 87,654$ Services of Other Departments
Hetch Hetchy 1,764,372$ -$ 1,764,372$ Fi xed C harges -$ -$ 1,764,372$ -$ -$ -$ -$ 1, 764,372$ City Attorney 792,232$ -$ 792,232$ Fixed C harges -$ -$ 792,232$ -$ -$ -$ -$ 792,232$ Repro (Marketing) -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ All Other Departments 90,317$ -$ 90,317$ Fixed Charges -$ -$ 90,317$ -$ -$ -$ -$ 90,317$ Working Capital Interest -$ -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Total Operating Costs 12,297,503$ -$ 12,297,503$ -$ -$ 12, 297,503$ -$ -$ -$ -$ 12, 297,503$ Uncollectible -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Working Capital Principal -$ -$ N/A -$ -$ -$ -$ -$ -$ -$ -$ Non-Debt Capital Expenditures 371,119$ 371,119$ Capit al -$ -$ -$ -$ 371,119$ -$ -$ 371,119$ Margin 29,306,936$ 29,306,936$ Rev R eq 4,942,725$ 385,350$ 1,133,345$ 20,925, 508$ 837, 177$ 88,239$ 994,592$ 29,306, 936$ (Less) Other Revenues
Wholesale (1,581,686)$ (1,581,686)$ Capac ity Split (1,467,291)$ (114,395)$ -$ -$ -$ -$ -$ ( 1,581,686)$ Interest and Other Revenues (1,365,812)$ (1,365,812)$ Rev R eq (230,349)$ (17,959)$ (52, 818)$ (975, 207)$ ( 39,016)$ ( 4,112)$ ( 46,352)$ ( 1,365,812)$ Revenue Requirement from Rates 344,357,975$ -$ 347,305,473$ 56, 876,730$ 4, 434,287$ 13, 378,030$ 247, 005,110$ 9, 882,059$ 1, 041,573$ 11, 740,185$ 344, 357,975$ Check -$ -$
Direct Allocators
1 0 0 0 0 0 0 1
Green Capacity Purchases Green Capacity 100% 0% 0% 0% 0% 0% 0% 100% 0 0 1 0 0 0 0 1
Fixed Market Charges Fixed Charges 0% 0% 100% 0% 0% 0% 0% 100% 0 0 0 1 0 0 0 1
Fixed Market Charges Green 0% 0% 0% 100% 0% 0% 0% 100%
0 0 0 0 1 0 0 1
Fixed Market Charges SuperGreen 0% 0% 0% 0% 100% 0% 0% 100% 0 0 0 0 0 0 1 1
Other Energy Costs Other Energy 0% 0% 0% 0% 0% 0% 100% 100% 2,872,876,980 223,978,450 3,096,855,431 Capacity Split Allocator Capacity Split 93% 7% 0% 0% 0% 0% 0% 100% 0 0 0 79,385,552$ 0 $ 902,801 0 80,288,353 Firming & Shaping Allocator Firm & Shape 0% 0% 0% 99% 0% 1% 0% 100% 50,570,647$ 3,942,645$ -$ 214,095,769$ 8, 215,501$ 902, 801$ 10,176, 000$ 287, 903,363$ Power Supply Contigency Allocator PS Cont 18% 1% 0% 74% 3% 0% 4% 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% 93% 7% 0 0% 0% 0% 0 1
Blythe SuperGreen Capacity Allocator Blythe SG Cap 93% 7% 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% 0 0 0 1 0 0 0 1
Calpine Geyers SuperGreen Allocator Calpine SG 0% 0% 0% 100% 0% 0% 0% 100% 5 0 0 0 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% 0 0 0 1 0% 0% 0 1
Calpine Geysers Xtension SuperGreen Allocator Calpine X SG 0% 0% 0% 100% 0% 0% 0% 100% Derived Allocators
-$ -$ 12,297,503$ -$ -$ -$ 12,297,503$ Total Operations & Maintenance Expense Total O&M 0% 0% 100% 0% 0% 0% 100% 53,631,646$ 4,181,290$ 12,297,503$ 227,054,809$ 9,083,897$ 957,447$ 10, 791,945$ 317,998,537$ Revenue Requirement Rev Req 17% 1% 4% 71% 3% 0% 3% 100% -$ 438,377$ 0% 438,377$ Capital Revenue Funded Capital 0% 0% 0% 0% 100% 0% 0% 100% 0 -1 0 55,435,254$ 10,292,153$ 0% 0 65,727,406$ Green/Super Green PPA Contracts Green/Super PPA 0% 0% 0% 84% 16% 0% 0% 100% 6 San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Cost Classification: Customer
Line Item FY 2023-24 Allocation
Data Management
& Service Fees
Cust. Account,
Service & Sales Energy Programs Bad Debt Direct Assign 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 Ormat 3462 (10/1/24-9/30/44) -$ N/A -$ -$ -$ -$ -$ -$ CC Power OME 3482 (6/1/24-5/31/44) -$ 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 -$ -$ -$ -$ -$ -$ Incremental RPS RECs -$ N/A -$ -$ -$ -$ -$ -$ Voluntary RECs (incl. losses) -$ N/A -$ -$ -$ -$ -$ -$ Incremental Super Green (incl. losses) -$ 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 -$ -$ -$ -$ -$ -$ Scheduling Coordinator (APX Collateral) -$ N/A -$ -$ -$ -$ -$ -$ Other Purchased Power & Supply Costs Total -$ -$ -$ -$ -$ -$ -$ 7 Contingency -$ N/A -$ -$ -$ -$ -$ -$ Total Supply Costs -$ -$ -$ -$ -$ -$ -$ Operating and Other Costs
Labor/Personnel 5,069,726$ Payroll -$ 5,069,726$ -$ -$ -$ 5,069,726$ Services of Bureaus 3,378,777$ Cust. Accts -$ 3,378,777$ -$ -$ -$ 3,378,777$ Non-Personnel Services
Professional Services 1,007,902$ Cust. Accts -$ 1,007,902$ -$ -$ -$ 1,007,902$ Calpine Data Manager Fees 4,825,005$ Data Mng. & Serv. Fee 4,825,005$ -$ -$ -$ -$ 4,825,005$ PG&E Service Fees 1,705,810$ Data Mng. & Serv. Fee 1,705,810$ -$ -$ -$ -$ 1,705,810$ Letter of Credit -$ N/A -$ -$ -$ -$ -$ -$ Miscellaneous 88,337$ Cust. Accts -$ 88,337$ -$ -$ -$ 88,337$ Materials and Supplies 141,704$ Cust. Accts -$ 141,704$ -$ -$ -$ 141,704$ Services of Other Departments
Hetch Hetchy 341,978$ Cust. Accts -$ 341,978$ -$ -$ -$ 341,978$ City Attorney 407,768$ Cust. Accts -$ 407,768$ -$ -$ -$ 407,768$ Repro (Marketing) 639,723$ Cust. Accts -$ 639,723$ -$ -$ -$ 639,723$ All Other Departments 146,011$ Cust. Accts -$ 146,011$ -$ -$ -$ 146,011$ Working Capital Interest -$ N/A -$ -$ -$ -$ -$ -$ Total Operating Costs 17,752,742$ 6,530,816$ 11,221,927$ -$ -$ -$ 17,752,742$ Uncollectible 3,690,298$ Bad Debt -$ -$ -$ 3,690,298$ -$ 3,690,298$ Working Capital Principal -$ N/A -$ -$ -$ -$ -$ -$ Non-Debt Capital Expenditures 1,236,101$ Energy Programs -$ -$ 1,236,101$ -$ -$ 1,236,101$ Margin 2,090,123$ Cust. Accts -$ 2,090,123$ -$ -$ -$ 2,090,123$ (Less) Other Revenues
Wholesale -$ N/A -$ -$ -$ -$ -$ -$ Interest and Other Revenues (97,408)$ Rev Req (28,050)$ (48,198)$ (5,309)$ (15,850)$ -$ (97,408)$ Revenue Requirement from Rates 24,671,857$ 6,502,765$ 13,263,851$ 1,230,792$ 3,674,448$ -$ 24,671,857$ Check -$
Direct Allocators
1 0 0 0 0 1
Data Management & PG&E Service Fees Data Mng. & Serv. Fee 100% 0% 0% 0% 0% 100% 0 1 0 0 0 1
Customer Accounts, Service, and Sales Cust. Accts 0% 100% 0% 0% 0% 100% 0 0 1 0 0 1
Energy Programs Energy Programs 0% 0% 100% 0% 0% 100%
0 0 0 1 0 1
Bad Debt Bad Debt 0% 0% 0% 100% 0% 100%
0 0 0 0 1 1
Direct Assign Direct 0% 0% 0% 0% 100% 100%
8 Derived Allocators
6,530,816$ 11,221,927$ -$ -$ -$ 17,752,742$ Total Operations & Maintenance Total O&M 37% 63% 0% 0% 0% 100% 6,530,816$ 11,221,927$ 1,236,101$ 3,690,298$ -$ 22,679,142$ Revenue Requirement Rev Req 29% 49% 5% 16% 0% 100%
0 1 0 0 0 1
Payroll Payroll 0% 100% 0% 0% 0% 100%
9 San Francisco Public Utilities Commission
FY 2023-24 CleanPowerSF Cost Allocation
Line Item FY 2023-24 Allocation Residential Small Commercial Medium Commercial Medium Commercial
High Large Commercial Street Lighting
SuperGreen
Customers Blank Total
Power Supply
Green Capacity 56,876,730$ 12 CP Green 26,500,184$ 8,895,524$ 7, 038,123$ 10, 842,303$ 3, 577,388$ 23, 209$ -$ -$ 56,876,730$ Super Green Capacity 4,434,287$ SuperGreen -$ -$ -$ -$ -$ -$ 4,434,287$ -$ 4,434,287$ Green and SuperGreen Fixed Charges 13,378,030$ 12 CP Split 5,785,828$ 1,942,174$ 1, 536,645$ 2, 367,217$ 781, 057$ 5,067$ 960,042$ -$ 13, 378,030$ Green Energy 247,005,110$ Wght Price Green 113,849,771$ 37,737,789$ 30, 321,862$ 49, 616,774$ 15, 338,488$ 140, 427$ -$ -$ 247,005,110$ Super Green Energy 9,882,059$ SuperGreen -$ -$ -$ -$ -$ -$ 9,882,059$ -$ 9,882,059$ SuperGreen Firming & Shaping 1,041,573$ SuperGreen -$ -$ -$ -$ -$ -$ 1,041,573$ -$ 1,041,573$ Green & SuperGreen Other Energy Costs 11,740,185$ NEFL Split 4,954,656$ 1,686,108$ 1, 357,109$ 2, 208,198$ 679, 034$ 5,977$ 849,103$ -$ 11, 740,185$ Total Power Supply 344,357,975$ 151,090,438$ 50,261,595$ 40, 253,739$ 65, 034,492$ 20, 375,966$ 174, 681$ 17,167, 064$ -$ 344,357,975$ Check -$
Customer
Data Management & Service Fees 6,502,765$ Customer Split 5,765,146$ 437,409$ 33,529$ 108,808$ 1,174$ 3,332$ 153, 368$ -$ 6, 502,765$ Cust. Account, Service & Sales 13,263,851$ Wght C&O Split 9,875,763$ 749,287$ 287,174$ 1,863, 890$ 20, 113$ 5,708$ 461,917$ -$ 13, 263,851$ Energy Programs 1,230,792$ Energy Programs 873,564$ 38,406$ 2,944$ 9,554$ 103$ 293$ 305,929$ -$ 1, 230,792$ Bad Debt 3,674,448$ Bad Debt 1,759,339$ 674,383$ 499,827$ 732,441$ 7,904$ 555$ -$ -$ 3,674,448$ Direct Assign -$ n/a -$ -$ -$ -$ -$ -$ -$ -$ -$ Total Customer 24,671,857$ 18,273,812$ 1,899,485$ 823, 474$ 2,714, 693$ 29, 293$ 9,888$ 921,213$ -$ 24, 671,857$ Check -$
Total Cost of Service 369,029,832$ 169,364,250$ 52,161,079$ 41, 077,213$ 67, 749,185$ 20, 405,260$ 184, 568$ 18,088, 278$ -$ 369,029,832$ Allocation of Super Green Customer Costs
Power Supply
Super Green Capacity 4,434,287$ 12 CP SG 601,150$ 206,711$ 265,053$ 1,122, 787$ 2, 238,587$ -$ -$ -$ 4,434,287$ Green and SuperGreen Fixed Charges 960,042$ 12 CP SG 130,152$ 44,754$ 57,385$ 243,088$ 484,664$ -$ -$ -$ 960,042$ Super Green Energy 9,882,059$ NEFL SG 1,297,133$ 452,183$ 589,831$ 2,639, 071$ 4, 903,841$ -$ -$ -$ 9,882,059$ SuperGreen Firming & Shaping 1,041,573$ SG Firm & Shape 56,291$ 19,057$ 61,248$ 132,976$ 771,150$ 852$ -$ -$ 1,041,573$ Green & SuperGreen Other Energy Costs 849,103$ NEFL SG 111,454$ 38,853$ 50,680$ 226,759$ 421,356$ -$ -$ -$ 849,103$ Total Power Supply 17,167,064$ 2,196,180$ 761,558$ 1,024, 197$ 4, 364,682$ 8, 819,597$ 852$ -$ -$ 17,167,064$ Customer
Data Management & Service Fees 153,368$ SG Customers 129,686$ 10,065$ 1,252$ 11,648$ 716$ -$ -$ -$ 153,368$ Cust. Account, Service & Sales 461,917$ Wght C&O SG 222,154$ 17,242$ 10,724$ 199,535$ 12,262$ -$ -$ -$ 461,917$ Energy Programs 305,929$ SG Customers 258,691$ 20,078$ 2,498$ 23,235$ 1,428$ -$ -$ -$ 305,929$ Total Customer 921,213$ 610,531$ 47,385$ 14,474$ 234,418$ 14,405$ -$ -$ -$ 921,213$ Total Cost of Service - Green & Super Green 369,029,832$ -$ 172,170,961$ 52, 970,022$ 42, 115,883$ 72, 348,285$ 29, 239,262$ 185, 420$ -$ -$ 369,029,832$ Unbundled Cost of Service Results - Green and Super Green

0.12717 0.13770 0.12442 0.12117 0.11982 0.10715 0.12559 Power Supply
Demand Related 74,689,048$ 33,017,313$ 11,089,162$ 8, 897,205$ 14, 575,396$ 7, 081,695$ 28, 277$ -$ -$ 74,689,048$ Energy Related 269,668,927$ 120,269,305$ 39,933,990$ 32, 380,730$ 54, 823,778$ 22, 113,868$ 147, 256$ -$ -$ 269,668,927$ Total 344,357,975$ 153,286,617$ 51,023,152$ 41, 277,936$ 69, 399,174$ 29, 195,563$ 175, 533$ -$ -$ 344,357,975$ Percent of Total 45% 15% 12% 20% 8% 0% 0% 0%
Percent of Class 89% 96% 98% 96% 100% 95%
Customer
Customer 24,671,857$ 18,884,343$ 1,946,870$ 837, 948$ 2,949, 110$ 43, 698$ 9,888$ -$ -$ 24, 671,857$ Total 24,671,857$ 18,884,343$ 1,946,870$ 837, 948$ 2,949, 110$ 43, 698$ 9,888$ -$ -$ 24, 671,857$ Percent of Total 77% 8% 3% 12% 0% 0% 0% 0%
Percent of Class 11% 4% 2% 4% 0% 5%
Total COS 369,029,832$ 172,170,961$ 52,970,022$ 42, 115,883$ 72, 348,285$ 29, 239,262$ 185, 420$ -$ -$ 369,029,832$ - - - - - - - - - - Representative COS Rates
Customer Charge 5.22$ 4.40$ 5.98$ 33.12$ 33.65$ 31.78$ 4.08$ -$ -$ 5. 22$ Demand Charge 5.37$ 3.54$ 7.13$ 9.19$ 10.59$ 10.58$ 9.84$ 5. 37$ Energy Charge 0.0929$ 0.0962$ 0.0938$ 0.0932$ 0.0908$ 0.0810$ 0.0997$ 0.0929$ Green Customers
10 1 - - - - - - - 1
Residential Residential 100% 0% 0% 0% 0% 0% 0% 0% 100%
349,497 - - - - - 7,862 - 357,359
Residential Split Residential Split 98% 0% 0% 0% 0% 0% 2% 0% 100% 1 - 1
SuperGreen SuperGreen 0% 0% 0% 0% 0% 0% 100% 0% 100%
357,359 27,127 2,108 7,302 115 202 - - 394, 213
Number of Customers Including SuperGreen Customers 91% 7% 1% 2% 0% 0% 0% 0% 100% 7,862 610 76 706 43 - - - 9,298
SuperGreen Customers SG Customers 85% 7% 1% 8% 0% 0% 0% 0% 100% 349,497 26,517 2,033 6,596 71 202 - - 384, 916
Green Customers Green Customers 91% 7% 1% 2% 0% 0% 0% 0% 100% 349,497 26,517 2,033 6,596 71 202 9,298 - 394,213
Customer Split Between Green and SuperGreen Customer Split 89% 7% 1% 2% 0% 0% 2% 0% 100% 1,336,351,271 455,014,679 371,350,276 642,299,009 290,263, 552 1, 576,643 - - 3,096,855,431 Total Energy at Wholesale (NEFL) NEFL 43% 15% 12% 21% 9% 0% 0% 0% 100% 29,399,728 10,248,795 13,368,610 59,814,979 111,146, 338 - - - 223,978,450 Total Energy at Wholesale (NEFL) SuperGreen NEFL SG 13% 5% 6% 27% 50% 0% 0% 0% 100% 1,306,951,543 444,765,884 357,981,666 582,484,031 179,117, 213 1, 576,643 - - 2,872,876,980 Total Energy at Wholesale (NEFL) Green NEFL Green 45% 15% 12% 20% 6% 0% 0% 0% 100% 1,306,951,543 444,765,884 357,981,666 582,484,031 179,117, 213 1, 576,643 223, 978,450 - 3,096,855,431 Total Energy at Wholesale (NEFL) Split NEFL Split 42% 14% 12% 19% 6% 0% 7% 0% 100% 1,250,347,380 425,733,650 347,580,890 603,805,700 272,875, 790 1, 476,380 - - 2,901,819,790 Total Energy at Retail Energy-Retail 43% 15% 12% 21% 9% 0% 0% 0% 100% 27,507,642 9,589,267 12,512,912 56,230,236 104,488, 299 - - - 210,328,356 Total Energy at Retail SuperGreen Energy-Retail SG 13% 5% 6% 27% 50% 0% 0% 0% 100% 1,222,839,738 416,144,384 335,067,978 547,575,464 168,387, 491 1, 476,380 - - 2,691,491,434 Total Energy at Retail Green Energy-Retail Green 45% 15% 12% 20% 6% 0% 0% 0% 100% 9,325,647 1,555,395 968,062 1,376,781 669,309 2, 875 - - 13, 898,069 Sum of Max Demands SMD 67% 11% 7% 10% 5% 0% 0% 0% 100%
2,561,603 860,334 690,211 1,130,255 548,054 2, 194 - - 5, 792,651 Coincident Peak 12 CP 44% 15% 12% 20% 9% 0% 0% 0% 100%
56,355 19,378 24,848 105,257 209,858 - - - 415,696
Coincident Peak SuperGreen Customers 12 CP SG 14% 5% 6% 25% 50% 0% 0% 0% 100% 2,505,248 840,956 665,363 1,024,999 338,196 2, 194 - - 5, 376,956 Coincident Peak Green Customers 12 CP Green 47% 16% 12% 19% 6% 0% 0% 0% 100% 2,505,248 840,956 665,363 1,024,999 338,196 2, 194 415,696 - 5, 792,651 Coincident Peak Split 12 CP Split 43% 15% 11% 18% 6% 0% 7% 0% 100% 87,477,554 29,011,736 23,636,445 41,113,560 18,678, 460 105, 525 200,023,279 Weighted Market Price of Energy Wght Price 44% 15% 12% 21% 9% 0% 0% 0% 100% 85,553,048 28,358,273 22,785,533 37,284,803 11,526, 193 105, 525 185,613,374 Weighted Market Price of Green Energy Wght Price Green 46% 15% 12% 20% 6% 0% 0% 0% 100% 357,359 27,127 10,542 73,023 1,146 202 - 469,399
Weighted Communications & Outreach Wght C&O 76% 6% 2% 16% 0% 0% 0% 0% 100% 7,862 610 380 7,061 434 - - 16, 347
Weighted Communications & Outreach SuperGreen Wght C&O SG 48% 4% 2% 43% 3% 0% 0% 0% 100% 349,497 26,517 10,163 65,962 712 202 - 453,052
Weighted Communications & Outreach Green Wght C&O Green 77% 6% 2% 15% 0% 0% 0% 0% 100% 349,497 26,517 10,163 65,962 712 202 16,347 - 469,399
Weighted Communications & Outreach Split Wght C&O Split 74% 6% 2% 14% 0% 0% 3% 0% 100% 1,347,472$ 59,242$ 4,541$ 14,737$ 159$ 451$ 471,895$ -$ 1, 898,497 Energy Programs Energy Programs 71% 3% 0% 1% 0% 0% 25% 0% 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% 0% 100% 8,741,819$ 3,350,879$ 2,483,544$ 3,639,357$ 39,271$ 2,757$ -$ -$ 18, 257,627 Bad Debt Expense Bad Debt 48% 18% 14% 20% 0% 0% 0% 0% 100% 11