Services of the San Francisco Public Utilities Commission Adopt Power Rates:
FY 2022-23 & FY 2023-24 Hetch Hetchy Power
FY 2022-23 CleanPowerSF
1 Erin Franks
Rates Administrator
05.24.2022
Agenda
1. 2022 Power Rates Study
• Overview
• Goals
• Rate Study Process
2. CleanPowerSF Rates Proposal
• Key Takeaways
• Customer Bill Impacts
3. Hetch Hetchy Power Rates Proposal
• Key Takeaways
• Customer Bill Impacts
2 2022 Power Rates Study Overview
• SF City Charter requirement: at least every five years by independent consultant
• Hetch Hetchy Power’s third rates study
• CleanPowerSF’s first rates study (program implemented 2016) • 2022 Power Rates Study began November 2020
• Rate Study: a complex model incorporating customer usage data, budgets, various internal and external scenarios, and compliance with financial policies
3 2022 Power Rates Study Goals
4 • Ensure long-term financial
health
• Agency must ensure rates recover
cost of delivering reliable service
• No longer follow PG&E rates
• Prioritize needs of customers
• Modernize and standardize Hetch
Hetchy Power rates
• First cost of service study for
CleanPowerSF
• Factor the City’s climate action
goals
• Ensure rates support transition to
100% renewable power by 2025
Rates Study Process
5 STEP 1
STEP 2
STEP 4
STEP 3
STEP 5
Determine the revenue
requirements of the utility
Unbundle costs by functions
and services (production,
transmission, distribution, etc.)
Classify costs (demand, energy,
customer costs, etc.)
Allocate cost among customer
classes
Design rates
Revenue Requirement
Determination
Cost Allocation
Rate Design
CleanPowerSF – Key Rate Takeaways
• Adopt one year of rates (FY 2022-23)
• Minimize rate changes for customers
• stable rates based on cost-of-service analysis
• no longer following PG&E’s rate changes
• Decrease from current rates, resulting in lower rates than PG&E
• Build up reserves to newly-adopted 180 days-cash-on-
hand fund balance reserve policy
6 CleanPowerSF – Bill Impacts
Average Residential (E-TOU-C)
PG&E
Delivery
Charge
$57
PG&E
Delivery
Charge
$57
PG&E
Delivery
Charge
$57
PG&E
Delivery
Charge
$57
PG&E
Generation
Charge
$41
PG&E
Generation
Charge
$41
CleanPowerSF
Generation
Charge
$35
CleanPowerSF
Generation
Charge
$34
PCIA + FFS, $6 PCIA + FFS, $6
CleanPowerSF
Customer Savings, $1
$-
$20
$40
$60
$80
$100
$97 $97 $97 $96
Average Monthly Bill
Current (March 2022) Proposed FY 2022-23
7 Assumes 284 kWh monthly usage. Customers’ bills on time-of use rates can vary significantly based on usage patterns.
CleanPowerSF– Bill Impacts
Average Small Commercial (B-1)
PG&E
Delivery
Charge
$231
PG&E
Delivery
Charge
$231
PG&E
Delivery
Charge
$231
PG&E
Delivery
Charge
$231
PG&E
Generation
Charge
$186
PG&E
Generation
Charge
$186
CleanPowerSF
Generation
Charge
$161
CleanPowerSF
Generation
Charge
$141
PCIA + FFS, $25
PCIA + FFS, $25
CleanPowerSF
Customer Savings, $20
$-
$50
$100
$150
$200
$250
$300
$350
$400
$450
$417 $417 $417 $397
Average Monthly Bill
Current (March 2022) Proposed FY 2022-23
8 Assumes 1,266 kWh monthly usage. Customers’ bills on time-of use rates can vary significantly based on usage patterns.
Hetch Hetchy –Key Rate Takeaways
• Adopt two years of rates (FY 2022-23, FY 2023-24)
• Standardize current structure to modern customer classes based on cost of service
• Raise subsidized “General Use Municipal” rates $0.03/kWh annually • Consolidate most “Enterprise Municipal”, retail rates by FY 2023-24 • All rates closer to cost of service in two years
• Bills may increase or decrease depending on current rate schedule, customer energy usage patterns
• All rates projected lower than PG&E’s
• Smooth rate changes during transition to cost of service • Limit average annual rate increase to <10% for most retail customers 9 Hetch Hetchy – Bill Impacts
Average Retail Residential (Electric Heating)
10 SFPUC R-1E vs. PG&E E-1 rates. Assumes 349 kWh summer and 432 kWh winter usage $90 $90
$99
$128
$-
$20
$40
$60
$80
$100
$120
$140
Current FY 2021-22
Rates
Proposed FY 2022-
23 Rates
Proposed FY 2023-
24 Rates
Current PG&E
Rates
Monthly Bill
Customer Charge Tier 1 Energy Tier 2 Energy Tier 3 Energy Hetch Hetchy – Bill Impacts
Retail Small Commercial (Retail Store)
11 SFPUC C-1 vs. PG&E A-1 rates. Assumes 1,498 kWh summer and 1,532 kWh winter usage $371 $402
$441
$491
$-
$100
$200
$300
$400
$500
$600
Current FY 2021-22
Rates
Proposed FY 2022-
23 Rates
Proposed FY 2023-
24 Rates
Current PG&E Rates
Monthly Bill
Customer Charge Energy Charge
Hetch Hetchy – Bill Impacts
Retail Large Commercial (Manufacturing)
12 SFPUC C-3P vs. PG&E E-19P rates. Assumes 101,000 kWh summer usage, 39,000 kWh winter usage, and 608 kW max demand. Customers’ bills on time-of use rates can vary significantly based on usage patterns.
$25,938 $28,094
$30,306
$34,438
$-
$5
$10
$15
$20
$25
$30
$35
$40
Current FY 2021-22
Rates
Proposed FY 2022-
23 Rates
Proposed FY 2023-
24 Rates
Current PG&E Rates
Monthly Bill (Thousands)
Customer Charge Energy Charges Demand Charges
Thank You
Services of the San Francisco Public Utilities Commission Rate Fairness Board:
Thoughts on Staff proposed
power rates
Presentation at Commission meeting
24 May 2022
Rate Fairness Board
Name Position / Title Appointed by
Reese Isbell (vice-chair) Residential Ratepayer Mayor
VACANT Large Business
Representative Mayor
Howard Ash (chair) Residential Ratepayer Bd. Of Supervisors VACANT Small Business Owner Bd. Of Supervisors
Trisha McMahon Budget & Planning
Manager City Administrator
Edward de Asis Asst. Citywide Budget
Manager Controller
Vishal Trivedi Financial Analyst Controller’s Office of Public Finance
2 Rate Fairness Board (charter)
◼ The Rate Fairness Board was established by Proposition E which was passed by San Francisco voters in 2002
◼ The Rate Fairness Board, as specified by Article 8B of the Charter of the City and County of San Francisco, may:
• Review the five-year rate forecast;
• Hold one or more public hearings on annual rate recommendations before the Public Utilities Commission adopts rates;
• Provide a report and recommendations to the Public Utilities Commission on the rate proposal; and
• In connection with periodic rate studies, submit to the Public Utilities Commission rate policy recommendations for the Commission's consideration, including recommendations to reallocate costs among various retail utility customer classifications, subject to any outstanding bond requirements
3 Multiple Rate Objectives
4 Public
Acceptance Conservation
Ease of
Understanding
Revenue
Sufficiency
Reasonableness
Ease of
Implementation
Customer
Equity
AffordabilityMitigate Monthly
Bill Impacts
Transparency
Fair
Rates
Two decades of change
SFPUC moving toward traditional utility service role
SFPUC function/attribute 2001 2022
General Fund departments pay for water NO YES
SFPUC $ transfers to General Fund YES NO
SFPUC $ transfers among departments Probably NO
Independent rate studies NO YES
Low-income rates (water, sewer, power) NO YES
Rates designed to encourage conservation Not really YES SFPUC bonding authority Voters Bd. Of Sups.
Standardized utility-type accounting practices NO YES
◼ Financial independence and integrity
◼ Rates reflect Cost of Service
◼ Traditional utility customer classes
◼ Simplification
5 Views on Current Power Rate Proposal
Hetch Hetchy Power and Clean Power SF
◼ One-year (CPSF) and 2-year (HH) rate proposals, rather than 4 or 5 ✓ ◼ Separate rate-setting for Hetch Hetchy and Clean Power SF ✓ ◼ Trend all rates toward Cost of Service, subject to reasonable caps on annual increases ✓
◼ Continue low-income rate programs ✓
6 Views on Current Power Rate Proposal
Hetch Hetchy Power
◼ Move away from GUSE / Enterprise / Retail customer classes to regular utility classes:
residential, commercial, industrial, etc. ✓
◼ Residential:
● New tiers for residential: size of blocks (below average, above average, very high) ✓ ● Different summer v. winter block sizes ✓
● New all-electric rate schedule ✓
● Use PG&E blocks for Hetch Hetchy customers – electric/gas and all-electric ✓ ● Expand Tier 2 to be of meaningful size ✓
◼ Maintain monthly customer charge (and the programs funded with these dollars), with phased increase toward Cost of Service ✓
◼ No change to current seasonal or Time-of-Use periods (pending further analysis) ✓ ◼ Discounts for high-voltage customers ✓
◼ Pilot for EV-only rate equivalent to small commercial energy rate ✓ ◼ 3-5 year journey for GUSE customers to reach COS rate (to avoid rate shock) ✓ ● Observation: Staff proposal moves a lot of $ from airport to residential & commercial customers
7 Views on Current Power Rate Proposal
Clean Power SF
◼ 1-Year rate proposal, due to current uncertainties in the power market ✓ ◼ Move to rates that are independent of PG&E rate changes, but still comparable to PG&E rates ✓ ◼ Delay implementation of fixed residential customer charge until CPUC process sorts out (energy charge will compensate for this, for now) ✓
◼ Staff intends to continue a 2-year transition to Cost of Service for the Energy rate (which is currently lower than comparable PG&E rate) ✓
◼ Super Green program: simplify to a standard rate premium ✓ ◼ Rates build fund reserve towards SFPUC target ✓
8 Final thoughts
A big “Thank you” to:
◼ Staff
◼ RFB members
◼ Our consultants:
◼ NewGen Strategy and Solutions
◼ Bell Burnett and Associates
Questions ?
9 AGENDA ITEM
Public Utilities Commission
City and County of San Francisco
DEPARTMENT Financial Services AGENDA NO. 11
MEETING DATE May 24, 2022
APPROVAL:
COMMISSION
SECRETARY Donna Hood
Public Hearing: Regular Calendar
Project Manager: Erin Franks
Adopt CleanPowerSF Rates for FY 2022-23
Summary of
Proposed
Commission
Action:
Public Hearing to consider the adoption of schedules of rates, fees and charges of the San Francisco Public Utilities Commission Power Enterprise for CleanPowerSF power service in San Francisco to be effective on or after July 1, 2022. 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 Department has determined that this action is exempt from the CEQA. If the item is approved, the Commission will rely on that determination to make its decision.
Background: 2022 Power Rates Study
As required by the San Francisco Charter Section 8B.125, the San Francisco Public Utilities Commission ( SFPUC)
has engaged an
independent rate consultant, NewGen Strategies & Solutions, to perform a retail power rates study. The independent rate consultant was selected through a competitive bid process via request for proposal.
SFPUC staff have worked closely wit h the consultant over the past 14 months to analyze the current revenues and revenue requirement of the Power Enterprise and determined that CleanPowerSF rate updates are necessary to appropriately allocate costs and cover the capital and operating costs o f the program. Detailed information on the revenue requirement, cost of service analysis, and rate design, are included in the attached independent consultant report (2022 SFPUC Power Rates Study).
The Study was a cross -agency effort, with the Business Se rvices’ Financial Planning team serving as the project lead and primary point of contact for the SFPUC. Customer Service, ITS, and Power staff were all heavily involved in data collection and policy recommendations .
Communications and External Affairs also
provided direction on
communication strategies, outreach efforts to elected officials, city Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
departments, the public, impacted customers, and other communities of interest.
Several internal working groups also provided guidance to SFPUC staff and NewGen a s well. SFPUC staff and NewGen met with SFPUC leadership regularly beginning in September 2020 while developing CleanPowerSF rates. This is the first Cost of Service Study for the CleanPowerSF program.
Revised CleanPowerSF Reserve Policy Incorporated
While CleanPowerSF operates under much of the same legal and policy framework as the SFPUC’s other utility services, the program is also reliant on a volatile regulatory and power supply market and faces competitive pressures that may reduce its flexibility for rate increases. In light of this market volatility, the SFPUC Fund Balance Reserve Policy was revised in April to include a specific CleanPowerSF program reserve.
This rates action is consistent with this revised reserve policy.
CleanPowerSF and the Power Enterprise
In 2016, the SFPUC began enrolling customers into CleanPowerSF, San Francisco’s community choice aggregation (CCA) program. Authorized under State law, the CCA program allows cities and counties to partner with local investor -owned electric utilities to provide additional choice in the sources of electricity generated and delivered to residents and businesses within their jurisdictions. Under CCA in San Francisco, retail electric distribution customers of Pacific Gas and Electric Co. (PG&E ) may choose their electricity generation provider: either CleanPowerSF or PG&E. After completing citywide enrollment in 2020, CleanPowerSF now serves approximately 60% of the electricity consumed in San Francisco. CleanPowerSF, like Hetch Hetchy Power, is
a retail electric
service business operated by the Power Enterprise of the SFPUC.
CleanPowerSF Revenue Requirement
The CleanPowerSF revenue requirement for the study is estimated to be approximately $302.4 million and represents the average of the two-ye ar period from FY 2022- 23 to FY 2023-
24. Costs include purchases of
renewable energy, shaped energy, capacity, wholesale energy market costs, contingency, and operating and other costs. Renewable energy costs include short - and long- term renewable energy p
ower purchase
agreements and greenhouse gas free (GHG -Free) power contracts. Shaped energy costs include bi -lateral system energy contracts used to balance CleanPowerSF’s renewable energy supply with customer demand.
Capacity cost s include contracted resou rces required to meet Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
CleanPowerSF’s State resource adequacy (RA) compliance requirements, including energy storage and long-term renewable energy agreements. The California Independent System Operator (CAISO) runs the wholesale electricity market and impo ses costs to participate in the market.
Contingency costs are included in the budgetary process to allow for unexpected changes in power supply costs. Operating and other costs include labor, operation s and capital plans. Anticipated contributions to internal reserves are also included in the operating and other costs category.
Energy Demands
The Study shows that while the peak energy demand for CleanPowerSF customers occurs in December, peak demand for CleanPowerSF is relatively constant throughout the year. The below table describes CleanPowerSF customers’ energy usage for major customer classes.
Customer Class No. of Customers
Total Usage for
Customer Class
(MWh/Yr)
Residential 357,331 1,301,964
Small Commercial 27,375 444,383
Medium Commercial 2,459 379,090
Medium Commercial
High 1,800 709,060
Large Commercial 56 258,621
Outdoor Lighting 305 1,617
Cost of Service (COS) Analysis
The objectives of the Study were to establish a COS -based rate setting methodology for the two separate operations within the Power Enterprise:
Hetch Hetchy Power and CleanPowerSF. The COS methodology was utilized to align retail rates with the service off erings to the various customer classes. Further, the COS methodology will form the basis for future rate offerings as the Power Enterprise continues to evolve and offer additional products and services in the future.
The Study utilized industry accepted methodology to assign utility costs to the various functions, or business units, of the organization. These functionalized costs were classified based on their underlying cost causation and were allocated to the various customer classes served by the Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
utility. Allocating costs to CleanPowerSF customer classes is achieved through three major processes: 1) functionalization, 2) classification, and 3) allocation.
After functionalizing costs, the Study found that the majority of CleanPowerSF costs (92%) are rel ated to the Power Supply function, driven mostly by the renewable energy, shaped energy, and other power supply costs incurred by CleanPowerSF.
These costs were further sub -functionalized during the classification process based on the underlying nature of each cost. These groups include capacity costs (fixed), fixed market charges (fixed), green energy (variable), SuperGreen energy (variable), and other energy costs (variable). For the renewable energy purchases, the total costs were allocated between the two energy products currently offered, “Green” energy and “SuperGreen” energy, based on an analysis of the specific contracts/power purchase agreements entered into by CleanPowerSF.
After costs were functionalized and classified, they were then allocated to CleanPowerSF customer classes. Utility costs can be classified as demand related, energy related, customer related, revenue related, and direct assignment. Demand allocation factors are utilized to assign fixed costs to customer classes based on the amount of demand they put on the system at certain times. Energy -related allocation factors assign costs based on the combined energy usage of the class, and customer -
related allocation
factors assign costs based on the number of customers within the class.
Revenue-related allocation factors utilize the combined costs (as a result of the other allocation factors) to assign costs. Directly assigned costs are allocated directly to the customer classes. For CleanPowerSF, the customer classes include Residential, Small Commercial, Medium Commercial – Low Demand (Medium Commercial Low), Medium Commercial – High Demand (Medium Commercial High), Large Commercial and Outdoor Lighting.
Rate design is based on a combination of analysis of the customer class revenue requirement and policy decisions. For CleanPowerSF, the overall rate design strategy developed for the rates proposed in the resolution was to begin to lower the current rates for each rate class and rate code in FY 2022-23, while ensuring that CleanPowerSF me
ets its financial metrics.
For each rate class, an effective all -in COS rate was developed. The intent of the rate plan is to move existing rates towards cost of service from the existing effective rate for the class by approximately 50% in FY 2022- 2023 to provide a smooth transition for customers while ensuring the program is building to its reserve fund balances as required by the Fund Balance Reserve Policy. The effective rate for each class was determined from the sum of the billing determinants times t he existing CleanPowerSF Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
rate across the various time of use (TOU) and seasonal periods. The proposed rates continue the pricing differentials previously adopted by the Commission, as established by PG&E for the current and legacy rate offerings, including those by season and TOU periods.1
Rate Design
Current Rate Structure
One of the main objectives of this Study is to set CleanPowerSF rates based on cost of service and SFPUC policy goals —and no longer tying them to PG&E rates.
CleanPowerSF rate schedules are grouped by customer class into the following categories:
• Residential
• Small commercial
• Medium commercial – low demand (which are less than 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% Ca lifornia Renewable Portfolio Standard- eligible renewable energy and is more than 90% greenhouse gas free. CleanPowerSF also offers a “SuperGreen” product that is 100% California Renewable Portfolio Standard- eligible renewable energy and greenhouse gas free, as a premium product. The SuperGreen product is sold as a voluntary rate rider that is in addition to the standard Green energy product rate.
Proposed Rate Design
Staff-proposed rate design changes are consistent with the consultant recommendation and a re highlighted below and further described in the attached Study. The key change being proposed is for CleanPowerSF to offer cost-based rates, applied to the PG&E TOU periods. This is a change from the above -described rates that were set to PG&E and theref ore 1 The Study provides information helpful to establishing TOU and seasonal periods customized to San Francisco customer usage, but the operational and customer impacts of adjusting the pricing differentials between TOU or seasonal periods require further study before staff can recommend a change.
Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
subject to market volatility.
For customers that are exempt or excluded from default TOU rates, CleanPowerSF will offer cost -based rates applied to “legacy” TOU periods. These new rates will be lower than comparable PG&E current rates effective March 2022), meaning that the CleanPowerSF generation rate, when added to the Power Charge Indifference Adjustment ( PCIA) and Franchise Fee Surcharge ( FFS), will be comparable to the PG&E generation rate.2 As a result of this analysis, the rate proposal represents a decrease from the current CleanPowerSF rates, which are set equal to PG&E’s generation rate after including the PCIA and FFS charges.
Proposed CleanPowerSF Rates FY 2022-23
Customer Class FY 2022-23 Rates % Rate Change
Residential $0.11902 -8%
Small General
Service
$0.11011 -11%
Medium General
Service - Low
$0.11263 -15%
Medium General
Service - High
$0.10393 -12%
Large General
Service
$0.09646 -14%
Agriculture $0.08394 -11%
Street Lighting $0.10416 0%
Traffic Control $0.10980 -4%
SuperGreen Premium
SuperGreen rates were also evaluated through this Study and deemed to meet COS. This Study proposed that SuperGreen residential rates be kept at the current premium of $0.01/kWh , while standardizing commercial rates – which currently vary from $0.005 to $0.0075/kWh depending on the customer class – to $0.005/kWh. Since the SuperGreen rate premiums are applied on top of the Green rate, the overall cost of SuperGreen service will decline for all customers, helping CleanPowerSF maintain an affordable option for 100% renewable energy.
2 The PCIA is charged to all customers to collect the above market costs of energy purchased by PG&E. The FFS is charged to all customers to collect the franchise fees paid by PG&E to local governments for the use of streets.
Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
PCIA Adjustment Credit
The PCIA Adjustment Credit was adopted in Resolution 20- 0048 to offset higher PCIA charges paid by CleanPowerSF customers to PG&E based on the year they were enrolled into CleanPowerSF, otherwise known as the customer’s PCIA vintage. The PCIA rates for applicable PCIA vintages have largely levelized since the PCIA Adjustment Credit was adopted, and currently only 2016 vintaged customers receive a bill adjustment, and it is less than 0.2% of their monthly bill. Additionally, because this proposed rate design will not follow PG&E rate changes, inclusive of the PCIA, there is no pathway to modify the PCIA Adjustment Credit when PG&E implements new PCIA rates at least once per year. Therefore, staff propose to eliminate the PCIA Adjustment Credit.
Net Energy Metering Tariff
Staff propose cost-neutral changes to the existing CleanPowerSF Electric Schedule, Net Energy Metering (CleanPowerSF NEM Tariff) to clarify the applicability of the Tariff to existing PG&E NEM offerings for distribution service, streamline the administration of the program, and improve the customer experience.
The proposed tariff changes would eliminate the exclusion of an annual true-up for Net Surplus Compensation for CleanPowerSF NEM customers who have less than 10 monthly billing cycles in the program .3 The elimination of this provision of the Tariff will provide significant administrative efficiencies and improve the customer experience in the program, allowing customers that have recently installed solar to benefit from any net generation they provide to CleanPowerSF prior to the true-up process.
Second, staff propose a change to clarify that the CleanPowerSF NEM Tariff is available to customers on PG&E’s Net Energy Metering Aggregation Tariff. However, they are not eligible to receive Net Surplus Compensation. The CleanPowerSF NEM Tariff refers to t he accompanying PG&E NEM tariffs that customers may be on and this change simply updates the tariff to add a PG&E NEM tariff that is not currently listed in CleanPowerSF’s NEM tariff as applicable. The changes would also allow staff to update PG&E NEM tari
ff eligibility as an
administrative measure going forward to ensure that customers may 3 Net Surplus Compensation is the payment that CleanPowerSF makes to participating customers that generate more electricity from their rooftop solar than they consume for the grid over the previous 12 -month period, making them a “net generator” of electricity.
Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
participate in CleanPowerSF’s NEM Tariff in a timely manner.
And lastly, the changes would streamline the process to address any net bill credit balances of customers w ho close their accounts. For customers closing their accounts, the CleanPowerSF NEM T ariff currently requires the account to undergo the Net Surplus Compensation t rue-up process.
This change would instead require a simple cash out of the customer’s NEM credit balance, avoiding the time -consuming calculations of net generation.
Rate Time Period
Staff propose one year of rates to go into effect in FY 2022- 23. While the consultant report recommended two years of rates, recent volatility in energy markets cau sed by geopolitical conflict and supply chain disruptions caused by COVID -19 have caused significant risk in power procurement costs. Since a major goal of this study is to support CleanPowerSF’s new reserves policy to build up sufficient reserves, the pro
posed single year of rate increases will allow CleanPowerSF to monitor and respond to rapidly changing market conditions for FY 2023-
24. Public Outreach and Education
SFPUC staff engaged customers, communities of interest, 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 the Power Rate Study’s methodology, objectives, and preliminary analysis have been discussed since the rate study process began i n late
2020. Near-final results of the Power Rate Study were presented to Rate Fairness Board members on Friday, April 8, 2022.
SFPUC staff presented to community members , such as the Tenderloin Neighborhood Development Corporation and Literacy for Environmental Justice, on Thursday, April 7, 2022 via the agency’s quarterly Community Power Update meeting. SFPUC staff also presented to the agency’s Power Subcommittee of the Citizens’ Advisory Committee (CAC) on Tuesday, April 12, 2022 and the Local Agency Formation Commission on Friday, April 15, 2022 ahead of this proposed rate action.
Once rates are formally adopted, CleanPowerSF will communicate the rate change to customers through a variety of channels including website, email, bill message, and social media. SFPUC staff will also proactively engage key customer accounts as necessary. Residenti
al customers will
also be reminded about available discount programs and other ways to Public Hearing: Adopt CleanPowerSF Rates for FY 2022-23 Commission Meeting Date: May 24, 2022
save on their monthl y e lectricity bill.
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 from May 4 to May 11, 2022 and posted on the SFPUC website for a public hearing on May 24th, with possible Commission action on this date. If approved by the Commission, these rates and charges
will be subject 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, these proposed CleanPowerSF rates will become effective on or after July 1, 2022 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.
Budget & Costs: There are no additional costs to adoption of the CleanPowerSF rates.
Environmental
Review
On May 3, 2022 the San Francisco Planning Department determined the Project to be statutorily exempt from environmental review under CEQA Section 21080(b)(8) and CEQA Guidelines Section 15273 (Rates, Tolls, Fares and Charges) ( Case Number 2022 -004061ENV) related to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or other charges . The exemption can be found here:
https://sfpuc.sharefile.com/d-saf10cb380e09471f917083e468334807 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, 2022 and will adversely impact the SFPUC’s ability to meet projected revenue requirements for the Power Enterprise.
Recommendation: SFPUC staff recommends that the Commission adopt the attached resolution.
Attachment: 1. 2022 SFPUC Power Rates Study Report
1 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, which prepared the report, 2022 SFPUC Power Rates Study, which has been submitted to the Rate Fairness Board for its review, and posted to the sfwater.org website; and WHEREAS, The rate consultant recommended vari ous changes to CleanPowerSF rates , including change to rates themselves; and
WHEREAS, The Commission adopted a Net Energy Metering (NEM) Tariff (Schedule NEM-CleanPowerSF) for the CleanPowerSF program, which was designed to achieve the following objectives: (1) encourage existing CleanPowerSF customers to install solar generation equipment; (2) encourage existing NEM customers of PG&E to join CleanPowerSF; (3) remai n fair to non- participating CleanPowerSF ratepayers; and (4) provide a simple and clear NEM program; and
WHEREAS, In furtherance of the objective to provide a simple and clear NEM program, staff proposes modifications to the CleanPowerSF NEM program and the NEM -CleanPowerSF schedule, which will be applied to the 2022 True -Up Period, in order to streamline program administration and improve customer retention in the program; and WHEREAS, The Rate Fairness Board has reviewed the findings and recommendations of the independent rate consultant report, and staff has prepared its own proposal and presented that report to this Commission on May 24, 2022; 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 the Power Enterprise as projected in the Power Enterprise 10 -Year Financial Plan, and recommend adjustments to CleanPowerSF rates applicable effective on or after July 1, 2022; 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 May 5 through May 11, 2022, and posted on the SFPUC website and at the San Francisco Public Library, as required, for a public hearing on May 24, 2022; 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 servi ce in San Francisco, public hearings were held at five Rates Fairness Board meetings beginning on December 3, 2019, and concluding on April
2 8, 2022, and on May 10, 2022 members of the public were given an additional opportunity to express their views on the revised Schedules of CleanPowerSF Rates and Charges; and WHEREAS, This Commission hereby finds that adoption of this resolution will establish rates for the purpose of: Meeting operating expenses, including employee wage rates and fringe benefits; Purch asing or leasing supplies, equipment, or materials; Meeting financial reserve needs and requirements, and Obtaining funds for capital projects necessary to maintain service within existing service areas; and Obtaining funds necessary to maintain such intra -city transfers as are authorized by the City Charter; and
WHEREAS, On May 3 , 2022 the San Francisco Planning Department determined the Project to be statutorily exempt from environmental review under CEQA Section 21080(b)(8) and CEQA Guidelines Section 15273 (Rates, Tolls, Fares and Charges) (Case Number 2022- 004061ENV) related to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or other charges; and
WHEREAS, 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; 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 NEM -CleanPowerSF schedule, as modified and presented in Section 3 below in this resolution, to be effective on or after Ju ly 1, 2022; and be it
FURTHER RESOLVED, That the PCIA adjustment credit is eliminated, and all CleanPowerSF customers on different PCIA vintages will pay the PCIA as set by the CPUC, with no changes to their CleanPowerSF generation rates as a result; and be it FURTHER RESOLVED, That the following CleanPowerSF Tariff s shall apply to all CleanPowerSF customers:
Section 1 - Authority and General Purpose
This Resolution is adopted pursuant to Section 8B.125 of the Charter of the City and County of San Francisco for the purpose of establishing an orderly system for the imposition and collection of charges for the operating, maintenance, replacement, debt service and other costs incurred by CleanPowerSF in providing power supply to residential and commercial customers. Section 2 – Billing Rates for CleanPowerSF
The following Schedules of CleanPowerSF Rates apply to all CleanPowerSF customers. A customer’s CleanPowerSF rate is determined by the rate schedule they sign up for with Pacific
3 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, 2022 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 22-23 Rate
All Energy $0.11963/kWh
Schedule E-TOU-C: Residential Time-of-Use
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.16699/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.11747/kWh All other hours
Winter Energy Charge
October 1—May 31
Peak $0.12180/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.10788/kWh All other hours
Schedule E-TOU-D: Residential Time-of-Use Peak Pricing 5-8pm (Non-Holiday Weekends) Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19376/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.09676/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.15599/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.12357/kWh All other hours including holidays
4 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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.30285/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.15388/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.10573/kWh All other hours
Winter Energy Charge November 1—April 30
Peak $0.10149/kWh
2:00pm to 9:00pm, Monday through Friday (except
holidays)
3:00pm to 7:00pm, Saturday through Sunday and
holidays
Part-Peak $0.07569/kWh 7:00am to 2:00pm and 9:00pm to 11:00pm, Monday through Friday (except holidays)
Off-Peak $0.07569/kWh All other hours
Schedule EV-2: Residential Time-of-Use for Plug-In Electric Vehicle Customers Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.18709/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.14479/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.10586/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.13327/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.12147/kWh 3:00pm to 4:00pm and 9:00pm to 12:00am, every day
Off-Peak $0.09925/kWh All other hours
5 Schedule E-6: Residential Time-of-Use Service
Schedule E-6 is a legacy rate that is closed to new customers.
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.24476/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Part-Peak $0.16662/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 $0.10049/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Part-Peak $0.13580/kWh 5:00pm to 8:00pm, Monday through Friday (except holidays)
Off-Peak $0.10395/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 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.23680/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.12047/kWh All other hours including holidays Winter Energy Charge October 1—May 31
Peak $0.13661/kWh 4:00pm to 9:00pm, Monday through Friday (except holidays)
Off-Peak $0.09993/kWh All other hours including holidays Residential SuperGreen Premium
Residential customers served by the schedules in the above section electing the SuperGreen 100% renewable energy service option will pay the SuperGreen premium in addition to their applicable Green rate on all kWh:
Rate Component FY 22-23 Rate
SuperGreen $0.01000/kWh
6 Small Commercial
Charges for Small Commercial customers based on meter readings on July 1, 2022 are as follows:
Schedule B-1: Small General Service
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.16499/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.12182/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.10356/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11654/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.10240/kWh All other hours
Super Off-Peak $0.08800/kWh 9:00am to 2:00pm, every day in March—May Schedule B-1-ST: Small General Service with Storage
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.17914/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.13969/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.10648/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.13215/kWh 4:00pm to 9:00pm, every day
Part-Peak $0.12068/kWh 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Off-Peak $0.10025/kWh All other hours
Super Off-Peak $0.08499/kWh 9:00am to 2:00pm, every day in March—May
7 Schedule B-6: Small General Time-of-Use Service
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.17029/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.10661/kWh All other hours
Winter Energy Charge October 1—May 31
Peak $0.11345/kWh 4:00pm to 9:00pm, every day
Off-Peak $0.09818/kWh All other hours
Super Off-Peak $0.08349/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 22-23 Rate Time of Use
Summer Energy Charge $0.12906/kWh May 1—October 31
Winter Energy Charge $0.09308/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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.13388/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.13388/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.11140/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.10591/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.10539/kWh All other hours including holidays
8 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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.18609/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Part-Peak $0.14236/kWh 8:30am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.11388/kWh All other hours including holidays Winter Energy Charge November 1—April 30
Part-Peak $0.10557/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.10494/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 22-23 Rate
SuperGreen $0.00500/kWh
9 Medium Commercial – Low Demand (75-500 kW)
Charges for Medium Commercial – Low Demand customers based on meter readings on July 1, 2022 are as follows:
Schedule B-10: Medium General Demand Metered Service
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.18079/kWh
Primary $0.16616/kWh
Transmission $0.14583/kWh
Part-Peak
2:00pm to 4:00pm and 9:00pm to 11:00pm, every
day
Secondary $0.12898/kWh
Primary $0.11720/kWh
Transmission $0.09818/kWh
Off-Peak
All other hours
Secondary $0.10163/kWh
Primary $0.09130/kWh
Transmission $0.07292/kWh
Winter Energy Charge
October 1—May 31
Peak
4:00pm to 9:00pm, every day
Secondary $0.13204/kWh
Primary $0.12027/kWh
Transmission $0.10128/kWh
Off-Peak
All other hours
Secondary $0.10224/kWh
Primary $0.09203/kWh
Transmission $0.07370/kWh
Super Off-Peak
9:00am to 2:00pm, every day in March—May
Secondary $0.07172/kWh
Primary $0.06151/kWh
Transmission $0.04318/kWh
10 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 22-23 Rate Time of Use
Summer Energy Charge
May 1—October 31
Secondary $0.12346/kWh
Primary $0.10955/kWh
Transmission $0.09250/kWh
Winter Energy Charge
November 1—April 30
Secondary $0.10498/kWh
Primary $0.09356/kWh
Transmission $0.07796/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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.13705/kWh
Primary $0.12329/kWh
Transmission $0.10704/kWh
Part-Peak
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.13705/kWh
Primary $0.12329/kWh
Transmission $0.10704/kWh
Off-Peak
All other hours including holidays
Secondary $0.11395/kWh
Primary $0.10145/kWh
Transmission $0.08578/kWh
Winter Energy Charge
November 1-April 30
Part-Peak
8:30am to 9:30pm, Monday through Friday (except
holidays)
Secondary $0.10719/kWh
Primary $0.09506/kWh
11 Rate Component FY 22-23 Rate Time of Use
Transmission $0.07954/kWh
Off-Peak
All other hours including holidays
Secondary $0.10658/kWh
Primary $0.09448/kWh
Transmission $0.07897/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 22-23 Rate
SuperGreen $0.00500/kWh
12 Medium Commercial – High Demand (500-1000 kW)
Charges for Medium Commercial – High Demand customers based on meter readings on July 1, 2022 are as follows:
Schedule B-19: Medium General Demand-Metered Time-of-Use Service Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.12847/kWh
Primary $0.11228/kWh
Transmission $0.10196/kWh
Part-Peak - Energy
2:00pm to 4:00pm and 9:00pm to 11:00pm,
every day
Secondary $0.09738/kWh
Primary $0.08862/kWh
Transmission $0.09202/kWh
Off-Peak - Energy
All other hours
Secondary $0.07540/kWh
Primary $0.06805/kWh
Transmission $0.07083/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $21.22/kW
Primary $18.18/kW
Transmission $14.32/kW
Part-Peak - Demand 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $3.08/kW
Primary $2.66/kW
Transmission $3.58/kW
Winter Energy Charge
October 1—May 31
Peak - Energy
4:00pm to 9:00pm, every day
Secondary $0.10872/kWh
Primary $0.09945/kWh
Transmission $0.10329/kWh
13 Rate Component FY 22-23 Rate Time of Use
Off-Peak - Energy
All other hours
Secondary $0.07531/kWh
Primary $0.06819/kWh
Transmission $0.07111/kWh
Super Off-Peak - Energy
9:00am to 2:00pm, every day in March—May
Secondary $0.03048/kWh
Primary $0.02369/kWh
Transmission $0.02378/kWh
Winter Demand Charge October 1—May 31
Peak - Demand
4:00pm to 9:00pm, every day
Secondary $2.52/kW
Primary $1.86/kW
Transmission $1.37/kW
14 Schedule B -19-R/B-19-S: Medium General Demand -Metered Time-of- Use Servic e, Solar/Storage
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.24503/kWh
Primary $0.22439/kWh
Transmission $0.19529/kWh
Part-Peak
2:00pm to 4:00pm and 9:00pm to 11:00pm, every
day
Secondary $0.12664/kWh
Primary $0.11650/kWh
Transmission $0.12412/kWh
Off-Peak
All other hours
Secondary $0.09301/kWh
Primary $0.08559/kWh
Transmission $0.08730/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.12990/kWh
Primary $0.11857/kWh
Transmission $0.11691/kWh
Off-Peak
All other hours
Secondary $0.09295/kWh
Primary $0.08569/kWh
Transmission $0.08750/kWh
Super Off-Peak
9:00am to 2:00pm, every day in March—May
Secondary $0.06167/kWh
Primary $0.05441/kWh
Transmission $0.05621/kWh
15 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 22-23 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 $0.08633/kWh
Primary $0.07588/kWh
Transmission $0.06771/kWh
Part-Peak - Energy
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.08633/kWh
Primary $0.07588/kWh
Transmission $0.06771/kWh
Off-Peak - Energy
9:30pm to 8:30am, Monday through Friday (except
holidays)
All day, Saturday through Sunday and holidays
Secondary $0.08112/kWh
Primary $0.07089/kWh
Transmission $0.06278/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $10.87/kW
Primary $9.43/kW
Transmission $10.42/kW
Part-Peak - Demand
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $10.87/kW
Primary $9.43/kW
Transmission $10.42/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07886/kWh
Primary $0.06874/kWh
16 Rate Component FY 22-23 Rate Time of Use
Transmission $0.06066/kWh
Off-Peak - Energy
9:30pm to 8:30 am, Monday through Friday (except
holidays)
All day, Saturday through Sunday and holidays
Secondary $0.07825/kWh
Primary $0.06815/kWh
Transmission $0.06008/kWh
17 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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.14665/kWh
Primary $0.13810/kWh
Transmission $0.13373/kWh
Part-Peak 8:30am to 12:00 noon & 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.13146/kWh
Primary $0.12400/kWh
Transmission $0.12131/kWh
Off-Peak 9:30pm to 8:30am, Monday through Friday (except holidays)
All day, Saturday through Sunday and holidays
Secondary $0.10583/kWh
Primary $0.10028/kWh
Transmission $0.10057/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.10356/kWh
Primary $0.09802/kWh
Transmission $0.09835/kWh
Off-Peak 9:30pm to 8:30 am, Monday through Friday (except holidays)
All day, Saturday through Sunday and holidays
Secondary $0.10294/kWh
Primary $0.09741/kWh
Transmission $0.09774/kWh
18 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 22-23 Rate
SuperGreen $0.005/kWh
19 Large Commercial
Charges for Large Commercial customers based on meter readings on July 1, 2022 are as follows:
Schedule B-20: Service to Customers with Maximum Demands of 1000 Kilowatts or More Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.11767/kWh
Primary $0.11476/kWh
Transmission $0.09651/kWh
Part-Peak - Energy 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.09077/kWh
Primary $0.08617/kWh
Transmission $0.07889/kWh
Off-Peak - Energy All other hours
Secondary $0.06953/kWh
Primary $0.06622/kWh
Transmission $0.05920/kWh
Summer Demand Charge June 1—September 30
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $20.70/kW
Primary $22.81/kW
Transmission $25.82/kW
Part-Peak - Demand 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $3.01/kW
Primary $3.13/kW
Transmission $6.15/kW
Winter Energy Charge October 1—May 31
Peak - Energy 4:00pm to 9:00pm, every day
Secondary $0.10165/kWh
Primary $0.09656/kWh
Transmission $0.09566/kWh
Off-Peak - Energy All other hours
20 Rate Component FY 22-23 Rate Time of Use
Secondary $0.06937/kWh
Primary $0.06628/kWh
Transmission $0.05564/kWh
Super Off-Peak - Energy 9:00am to 2:00pm, every day in March—May Secondary $0.02611/kWh
Primary $0.02331/kWh
Transmission $0.01566/kWh
Winter Demand Charge October 1—May 31
Peak - Demand 4:00pm to 9:00pm, every day
Secondary $2.64/kW
Primary $2.62/kW
Transmission $3.45/kW
21 Schedule B-20-R/B-20-S: Service to Customers with Maximum Demands of 1000 Kilowatts or More, Solar/Storage
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.23404/kWh
Primary $0.22911/kWh
Transmission $0.23245/kWh
Part-Peak 2:00pm to 4:00pm & 9:00pm to 11:00pm, every day Secondary $0.11805/kWh
Primary $0.11505/kWh
Transmission $0.12551/kWh
Off-Peak All other hours
Secondary $0.08532/kWh
Primary $0.08433/kWh
Transmission $0.08021/kWh
Winter Energy Charge October 1—May 31
Peak 4:00pm to 9:00pm, every day
Secondary $0.08520/kWh
Primary $0.11983/kWh
Transmission $0.12537/kWh
Off-Peak All other hours
Secondary $0.05396/kWh
Primary $0.08437/kWh
Transmission $0.07757/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.09909/kWh
Primary $0.05274/kWh
Transmission $0.04801/kWh
22 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 22-23 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 $0.07921/kWh
Primary $0.07645/kWh
Transmission $0.06567/kWh
Part-Peak - Energy
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.07921/kWh
Primary $0.07645/kWh
Transmission $0.06567/kWh
Off-Peak - Energy
All other hours
Secondary $0.07423/kWh
Primary $0.07161/kWh
Transmission $0.06091/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $10.37/kW
Primary $11.08/kW
Transmission $13.20/kW
Part-Park - Demand
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $10.37/kW
Primary $11.08/kW
Transmission $13.20/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07206/kWh
Primary $0.06954/kWh
Transmission $0.05887/kWh
23 Rate Component FY 22-23 Rate Time of Use
Off-Peak - Energy
9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.07146/kWh
Primary $0.06898/kWh
Transmission $0.05832/kWh
24 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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.13500/kWh
Primary $0.13694/kWh
Transmission $0.13493/kWh
Part-Peak 8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.12172/kWh
Primary $0.12131/kWh
Transmission $0.11898/kWh
Off-Peak All other hours
Secondary $0.09773/kWh
Primary $0.09648/kWh
Transmission $0.09389/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.09543/kWh
Primary $0.09427/kWh
Transmission $0.09167/kWh
Off-Peak 9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.09480/kWh
Primary $0.09367/kWh
Transmission $0.09107/kWh
25 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 22-23 Rate
SuperGreen $0.00500/kWh
Business Electric Vehicles
Charges for Business Electric Vehicle customers based on meter readings on July 1, 2022 are as follows:
Schedule BEV-1: Business Electric Vehicles Secondary Voltage Rate Component FY 22-23 Rate Time of Use
Peak Energy Charge $0.22952/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.07773/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05662/kWh All other hours Schedule BEV-2-S Business Electric Vehicles Secondary Voltage Rate Component FY 22-23 Rate Time of Use
Peak Energy Charge $0.24340/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.07454/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05345/kWh All other hours Schedule BEV-2-P Business Electric Vehicles Primary or Transmission Voltage Rate Component FY 22-23 Rate Time of Use
Peak Energy Charge $0.23478/kWh 4:00pm to 9:00pm, every day Off-Peak Energy Charge $0.07205/kWh 9:00pm to 9:00am and 2:00pm to 4:00pm, every day
Super Off-Peak Energy Charge $0.05196/kWh All other hours
26 Agriculture
Charges for Agriculture customers based on meter readings on July 1, 2022 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 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21790/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.10781/kWh All other hours
Winter Energy Charge
October 1—May 31
Peak $0.10475/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08042/kWh All other hours
Schedule AG-B: Time-of-Use Agricultural Power
Rate Component FY 22-23 Time of Use
Summer Energy Charge June 1—September 30
Peak $0.21936/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.11331/kWh All other hours
Winter Energy Charge
October 1—May 31
Peak $0.10871/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.08613/kWh All other hours
Schedule AG-C: Time-of-Use Agricultural Power
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.09998/kWh 5:00pm to 8:00pm, every day
Off-Peak - Energy $0.07485/kWh All other hours
Summer Demand Charge June 1—September 30
Peak - Demand $12.31/kW 5:00pm to 8:00pm, every day
Winter Energy Charge October 1—May 31
Peak $0.08750/kWh 5:00pm to 8:00pm, every day
Off-Peak $0.06574/kWh All other hours
27 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 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.18523/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.11465/kWh All hours, Option 1, 2 or 3
Winter Energy Charge October 1—May 31
Peak $0.10532/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.08111/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 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak $0.19008/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.12042/kWh All other hours, Option 1, 2 or 3 Winter Energy Charge October 1—May 31
Peak $0.11009/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak $0.08744/kWh All other hours, Option 1, 2 or 3
28 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 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak - Energy $0.11086/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.08675/kWh All other hours, Option 1, 2 or 3 Summer Demand Charge June 1—September 30
Peak - Demand $12.31/kW 5:00pm to 8:00pm, every day except off-peak days Winter Energy Charge October 1—May 31
Peak - Energy $0.09928/kWh 5:00pm to 8:00pm, every day except off-peak days Off-Peak - Energy $0.07803/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 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak $0.11541/kWh 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Off-Peak $0.09749/kWh All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Connected Load Summer $7.97/kW May 1—October 31
Winter Energy Charge November 1—April 30
Part-Peak $0.08894/kWh 8:30am to 9:30pm, Monday through Friday (except holidays)
Off-Peak $0.08827/kWh All other hours, Monday through Friday All day, Saturday through Sunday and holidays
29 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 22-23 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 $0.09452/kWh
Primary $0.09452/kWh
Transmission $0.09452/kWh
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.07468/kWh
Primary $0.07468/kWh
Transmission $0.07468/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $3.15/kW
Primary $3.15/kW
Transmission $3.15/kW
Maximum - Demand All hours
Secondary $10.11/kW
Primary $6.93/kW
Transmission $4.60/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.07145/kWh
Primary $0.07145/kWh
Transmission $0.07145/kWh
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.07089/kWh
Primary $0.07089/kWh
Transmission $0.07089/kWh
30 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 22-23 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 $0.07976/kWh
Primary $0.07976/kWh
Transmission $0.07976/kWh
Part-Peak - Energy 8:30 am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $0.06848/kWh
Primary $0.06848/kWh
Transmission $0.06848/kWh
Off-Peak - Energy 9:30pm to 8:30am, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.06428/kWh
Primary $0.06428/kWh
Transmission $0.06428/kWh
Summer Demand Charge May 1—October 31
Peak - Demand 12:00 noon to 6:00pm, Monday through Friday (except holidays)
Secondary $10.12/kW
Primary $9.29/kW
Transmission $8.56/kW
Part-Peak - Demand 8:30 am to 12:00 noon and 6:00pm to 9:30pm, Monday through Friday (except holidays)
Secondary $8.09/kW
Primary $8.09/kW
Transmission $8.09/kW
Winter Energy Charge November 1—April 30
Part-Peak - Energy 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.06608/kWh
Primary $0.06608/kWh
31 Rate Component FY 22-23 Rate Time of Use
Transmission $0.06608/kWh
Off-Peak - Energy All other hours, Monday through Friday All day, Saturday through Sunday and holidays
Secondary $0.06544/kWh
Primary $0.06544/kWh
Transmission $0.06544/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 22-23 Rate
SuperGreen $0.00500/kWh
32 Lighting and Traffic Controls
Charges for Lighting and Traffic Control customers based on meter readings on July 1, 2022 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 22-23 Rate
All Energy $0.10416/kWh
Schedule TC-1: Traffic Control Service
Rate Component FY 22-23 Rate
All Energy $0.10980/kWh
Schedule A-15: Direct-Current Lighting Service
Schedule A-15 is a legacy rate that is unavailable to new customers.
Rate Component FY 22-23 Rate Time of Use
Summer Energy $0.11897/kWh June 1-September 30
Winter Energy $0.10156/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 22-23 Rate
SuperGreen $0.00500/kWh
33 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, 2022 are as follows:
Schedule SEM: Residential Multi Meter Standby
Rate Component FY 22-23 Rate Time of Use
Reservation Charge $0.61/kW Year-Round
Energy Charge $0.11973/kWh All hours
34 Schedule B-ST: Standby Service
Applies to PG&E rate schedule SB.
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge June 1—September 30
Peak 4:00pm to 9:00pm, every day
Secondary $0.11369/kWh
Primary $0.11369/kWh
Transmission $0.09872/kWh
Part-Peak 2:00pm to 4:00pm and 9:00pm to 11:00pm, every day
Secondary $0.10048/kWh
Primary $0.10048/kWh
Transmission $0.08599/kWh
Off-Peak All other hours
Secondary $0.08577/kWh
Primary $0.08577/kWh
Transmission $0.07183/kWh
Winter Energy Charge October 1—May 31
Peak 4:00 noon to 9:00pm, every day
Secondary $0.10841/kWh
Primary $0.10841/kWh
Transmission $0.09372/kWh
Off-Peak All other hours
Secondary $0.08702/kWh
Primary $0.08702/kWh
Transmission $0.07315/kWh
Super Off-Peak 9:00am to 2:00pm, every day in March—May Secondary $0.03954/kWh
Primary $0.03954/kWh
Transmission $0.02614/kWh
Reservation Charge Year-Round
Secondary $0.40/kW
Primary $0.40/kW
Transmission $0.23/kW
35 Schedule A-ST: Standby Service
Applies to PG&E’s rate schedule. Schedule A-ST is a legacy rate that is closed to new customers.
Rate Component FY 22-23 Rate Time of Use
Summer Energy Charge May 1—October 31
Peak 12:00 noon to 6:00pm, Monday through Friday
(except holidays)
Secondary $0.15205/kWh
Primary $0.15205/kWh
Transmission $0.13794/kWh
Part-Peak
8:30am to 12:00 noon and 6:00pm to 9:30pm,
Monday through Friday (except holidays)
Secondary $0.12545/kWh
Primary $0.12545/kWh
Transmission $0.11350/kWh
Off-Peak
9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.09063/kWh
Primary $0.09063/kWh
Transmission $0.08116/kWh
Winter Energy Charge November 1—April 30
Part-Peak 8:30am to 9:30pm, Monday through Friday (except holidays)
Secondary $0.12969/kWh
Primary $0.12969/kWh
Transmission $0.11735/kWh
Off-Peak
9:30pm to 8:30am, Monday through Friday,
All day, Saturday through Sunday and holidays
Secondary $0.10271/kWh
Primary $0.10271/kWh
Transmission $0.09251/kWh
Reservation Charge Year-Round
Secondary $0.61/kW
Primary $0.61/kW
Transmission $0.49/kW
36 Section 3 – Net Energy Metering Tariff
Applicability
This Schedule Net Energy Metering (NEM-CleanPowerSF) is applicable to enrolled CleanPowerSF customers who use a Renewable Electrical Generation Facility.
To be eligible, the CleanPowerSF customer must satisfy the requirements of, and take electricity service on, a Pacific Gas and Electric Company’s (PG&E) net energy metering Electric Tariff Schedule, including NEM, NEM2
4, 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.
4 For more information see PG&E’s NEM tariffs by selecting the “Electric Rate Schedules” link at:
https://www.pge.com/tariffs/index.page
37 “Net Electricity Generator”
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)5 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 e lectricity 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
5 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.
38 (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 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 be due and payable on the due date identified in each billing statement.
a. Residential and small commercial NEM -CleanPowerSF customers may elect to receive Annual Billing, under which CleanPowerSF charges for the preceding Annual True-Up Period become due once per year, after the Annual True -Up (see Section IV.B below). Eligible small commercial customers are defined as those having a maximum monthly peak demand of less than 20 kilowatts.
3. Any 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 customer is a Net Electricity Generator at the end of the Annual True-up Period, the customer is eligible to receive Net Surplus Electricity Compensatio n 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 22-23 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.
39 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, CleanPowerSF aggregated NEM accounts are ineligible to receive Net Surplus Compensation
Renewable Energy Credits and Environmental Attributes
The customer will retain ownership of all RECs and environmental attributes associated with its usage of electricity produced by the eligible Renewable Electrical Generation Facility.
Termination of CleanPowerSF Service
If a NEM-CleanPowerSF customer opts-out of the CleanPowerSF program and returns to PG&E bundled service, or otherwise closes their CleanPowerSF account, that customer may request that CleanPowerSF settle any remaining net generation credits on the account, provided that the request is received within 90 calendar days of the return to PG&E service or the account closure.
For customers with remaining net bill credit balances credits, CleanPowerSF will issue a check for the amount of any net bill credit balances remaining at the time of the return to PG&E service or the account closure.
Section 4 – Definitions
For the purpose of this Resolution, the following definitions shall apply unless the context specifically dictates otherwise.
“City”
The City and County of San Francisco
“Commission”
The San Francisco Public Utilities Commission
“Customer”
Any person, firm, corporation, partnership, trust, or any other entity including, but not limited to, local, state and federal governments utilizing the services of CleanPowerSF. “Customer Class”
Customers with the same or similar usage characteristics are grouped into Customer Classes for purposes of cost allocation and rate setting.
“General Manager”
The General Manager of the Public Utilities Commission or his or her designee.
40 “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 – 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 eac h 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 6 – 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, 2022.
I hereby certify that the foregoing resolution was adopted by the Public Utilities Commission at its meeting of May 24, 2022.
______________________________________
Secretary, Public Utilities Commission