Details for: PGE AL 5830-E.pdf


Click on the image for full size preview

Document data

Erik Jacobson
Director
Regulatory Relations

Pacific Gas and Electric Company
77 Beale St., Mail Code B13U
P.O. Box 770000
San Francisco, CA 94177
Fax: 415-973-3582

May 19, 2020
Advice 5830-E
(Pacific Gas and Electric Company ID U 39 E)

Public Utilities Commission of the State of California
Subject:

Addition of B1-ST Storage Rate Option to Electric Schedule B-1
Pursuant to Decision 18-08-013

Purpose
Pacific Gas and Electric Company (PG&E) requests California Public Utilities
Commission’s (CPUC, Commission) approval of the attached pro forma tariffs for the new
small commercial storage rate option (option B1-ST) under Electric Rate Schedule B-1
as adopted in Decision (D.) 18-08-013. PG&E’s pro forma tariff is provided as Attachment
1.
Background
On August 9, 2018, the California Public Utilities Commission (CPUC or Commission)
issued D.18-08-013 (the Decision) in PG&E’s 2017 General Rate Case Phase II
Application to Revise Its Electric Marginal Costs, Revenue Allocation, and Rate Design
(Application (A.) 16-06-013). The Decision accepts various settlement agreements that
make significant changes to PG&E’s rate designs. In particular, the decision adopted,
with certain modifications, a settlement for Small Light and Power Rate Design that
included a new rate option for small commercial customers called the A-1 STORE rate.
In this advice letter, PG&E has prepared pro forma tariffs for the A-1 STORE rate,
renamed B1-ST herein, to be consistent with the nomenclature for the new small
commercial rate schedules: Schedules B-1 and B-6.
PG&E currently expects the new B1-ST storage rate option to become available on a
voluntary basis on August 1, 2020. In this advice letter PG&E is proposing pro forma
tariffs pursuant to the Commission’s decision.
Rate Design
The Small Light and Power Rate Design Settlement adopted by D.18-08-013 included
illustrative rates for the new B1-ST rate based on overall rate levels in place in March
2017, together with rules for adjusting those rates for later implementation. In review of
the Settlement rates, PG&E discovered an error in the allocation of sales by TOU period





- Page 1 -

Advice 5830-E -2- May 19, 2020 which resulted in rates that were set too high. PG&E’s illustrative rates provided in the pro forma tariff have been corrected and brought forward to be revenue neutral to May 1, 2020 rate levels based on the rules for adjusting the rates for revenue requirement and sales changes. Tariff Revisions PG&E has revised Schedule B-1 to include the new B1-ST optional rate. PG&E’s pro forma tariff is provided as Attachment 1. PG&E’s updated B-1 tariff includes the applicability and illustrative rate values for the new optional storage rate for small commercial customers (B1-ST). As noted above, the illustrative rates are based on overall rate levels effective on May 1, 2020. As required by D.18-08-013, Ordering Paragraph 8, the tariff specifies the eligibility for the new rate option without simply crossreferencing the Self-Generation Incentive Program (SGIP) Handbook or other SGIP rules. In addition, the tariff specifies that the demand charge on this new option applies only from 2 pm to 11 pm. PG&E will revise these illustrative rates to take into consideration the revenue requirements that will be in effect on August 1, 2020, prior to the August 1, 2020 implementation date. PG&E requests approval of these new pro forma tariffs in this Tier 1 Advice Letter. PG&E will include final rates effective August 1 in a separate advice letter, or as a supplement to this advice letter if the Commission has not issued a disposition letter by the middle of July. PG&E’s pro forma tariffs are provided as Attachment 1. For the convenience of the reader, PG&E has provided a redline version of the revised proforma tariff in Attachment 2. Protests ***Due to the COVID-19 pandemic and the shelter at home orders, PG&E is currently unable to receive protests or comments to this advice letter via U.S. mail or fax. Please submit protests or comments to this advice letter to EDTariffUnit@cpuc.ca.gov and PGETariffs@pge.com*** Anyone wishing to protest this submittal may do so by letter sent via U.S. mail, facsimile or E-mail, no later than June 8, 2020, which is 20 day after the date of this submittal. Protests must be submitted to: CPUC Energy Division ED Tariff Unit 505 Van Ness Avenue, 4th Floor San Francisco, California 94102
- Page 2 -

Advice 5830-E -3- May 19, 2020 Facsimile: (415) 703-2200 E-mail: EDTariffUnit@cpuc.ca.gov Copies of protests also should be mailed to the attention of the Director, Energy Division, Room 4004, at the address shown above. The protest shall also be sent to PG&E either via E-mail or U.S. mail (and by facsimile, if possible) at the address shown below on the same date it is mailed or delivered to the Commission: Erik Jacobson Director, Regulatory Relations c/o Megan Lawson Pacific Gas and Electric Company 77 Beale Street, Mail Code B13U P.O. Box 770000 San Francisco, California 94177 Facsimile: (415) 973-3582 E-mail: PGETariffs@pge.com Any person (including individuals, groups, or organizations) may protest or respond to an advice letter (General Order 96-B, Section 7.4). The protest shall contain the following information: specification of the advice letter protested; grounds for the protest; supporting factual information or legal argument; name, telephone number, postal address, and (where appropriate) e-mail address of the protestant; and statement that the protest was sent to the utility no later than the day on which the protest was submitted to the reviewing Industry Division (General Order 96-B, Section 3.11). Effective Date Pursuant to General Order (GO) 96-B, Rule 5.1, and OP 8 of D.18-08-013 this advice letter is submitted with a Tier 1 designation. PG&E requests that this Tier 1 advice submittal become effective on August 1, 2020. PG&E will include final rates effective August 1 in a separate advice letter, or as a supplement to this advice letter if the Commission has not issued a disposition letter by the middle of July. Notice In accordance with General Order 96-B, Section IV, a copy of this advice letter is being sent electronically and via U.S. mail to parties shown on the attached list and the parties on the service list for A.16-06-013. Address changes to the General Order 96-B service list should be directed to PG&E at email address PGETariffs@pge.com. For changes to any other service list, please contact the Commission’s Process Office at (415) 703-2021
- Page 3 -

Advice 5830-E -4- May 19, 2020 or at Process_Office@cpuc.ca.gov. Send all electronic approvals to PGETariffs@pge.com. Advice letter submittals can also be accessed electronically at: http://www.pge.com/tariffs/. /S/ Erik Jacobson Director, Regulatory Relations Attachments cc: Service List A.16-06-013
- Page 4 -

ADVICE LETTER SUMMARY ENERGY UTILITY MUST BE COMPLETED BY UTILITY (Attach additional pages as needed) Company name/CPUC Utility No.: Pacific Gas and Electric Company (ID U39 E) Utility type: ELC GAS PLC HEAT ELC = Electric PLC = Pipeline WATER Contact Person: Annie Ho Phone #: (415) 973-8794 E-mail: PGETariffs@pge.com E-mail Disposition Notice to: AMHP@pge.com EXPLANATION OF UTILITY TYPE GAS = Gas WATER = Water HEAT = Heat (Date Submitted / Received Stamp by CPUC) Tier Designation: 1 Advice Letter (AL) #: 5830-E Subject of AL: Addition of B1-ST Storage Rate Option to Electric Schedule B-1 Pursuant to Decision 18-08-013 Keywords (choose from CPUC listing): AL Type: Monthly Quarterly Annual One-Time Other: If AL submitted in compliance with a Commission order, indicate relevant Decision/Resolution #: D.18-08-013 Does AL replace a withdrawn or rejected AL? If so, identify the prior AL: No Summarize differences between the AL and the prior withdrawn or rejected AL: Confidential treatment requested? Yes No If yes, specification of confidential information: Confidential information will be made available to appropriate parties who execute a nondisclosure agreement. Name and contact information to request nondisclosure agreement/ access to confidential information: Resolution required? Yes No Requested effective date: 8/1/20 No. of tariff sheets: N/A Estimated system annual revenue effect (%): N/A Estimated system average rate effect (%): N/A When rates are affected by AL, include attachment in AL showing average rate effects on customer classes (residential, small commercial, large C/I, agricultural, lighting). Tariff schedules affected: Service affected and changes proposed1: N/A Pending advice letters that revise the same tariff sheets: N/A 1 Discuss in AL if more space is needed. Clear Form
- Page 5 -

Protests and all other correspondence regarding this AL are due no later than 20 days after the date of this submittal, unless otherwise authorized by the Commission, and shall be sent to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, CA 94102 Email: EDTariffUnit@cpuc.ca.gov Name: Erik Jacobson, c/o Megan Lawson Title: Director, Regulatory Relations Utility Name: Pacific Gas and Electric Company Address: 77 Beale Street, Mail Code B13U City: San Francisco, CA 94117 State: California Telephone (xxx) xxx-xxxx: (415) 793-2093 Facsimile (xxx) xxx-xxxx: (415) 973-3582 Email: PGETariffs@pge.com Name: Title: Utility Name: Address: City: Telephone (xxx) xxx-xxxx: Facsimile (xxx) xxx-xxxx: Email: State: California Clear Form
- Page 6 -

Advice 5830-E May 19, 2020 Attachment 1 Proforma Tariffs
- Page 7 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 46358-E San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE APPLICABILITY: Sheet 1 Schedule B-1 applies to single-phase and polyphase alternating-current service (for a description of these terms, see Section D of Rule 2*). This schedule is not available to residential or agricultural service for which a residential or agricultural schedule is applicable, except for single-phase and polyphase service in common areas in a multifamily complex (see Common-Area Accounts section). Customers that are otherwise eligible to take service on Schedule B-1 but are purchasing power to serve electric vehicle charging equipment, are not eligible to take service on this rate schedule. Decision 18-08-013 adopted new TOU periods and seasonal definitions for all nonresidential customer classes. Schedules A-1, A-6, A-10, E-19 and E-20 will be retained as legacy rate schedules with their current TOU periods until the rates with new TOU periods (Schedules B-1, B-6, B-10, B-19 and B-20) established in the same proceeding, become mandatory in March 2021. Certain qualifying customers with solar systems will be permitted to maintain (i.e., be grandfathered on) their existing legacy TOU rate periods for a certain period of time, per Decision 17-01-006, as described in the Electric Rule 1, Definitions: Behind-the-Meter Solar TOU Grandfathering and Eligibility Requirements. These new rates with revised TOU periods adopted in D.18-08-013, including Schedule B-1, will be available to qualifying customers on a voluntary basis beginning in November 2019 through February 2021. During that period, eligible customers have a one-time opportunity to opt-in.. Customers eligible for this rate schedule must have an interval data meter that can be read remotely by PG&E. Beginning March 2021, customers still served on Schedule A-1, with the exception of solar grandfathered customers referenced above, will be transitioned to Schedule B-1 with revised TOU periods. The mandatory transition process is further described in the legacy rate Schedule A-1. Customers with a maximum demand of 75 kW or greater for three consecutive months in the most recent twelve months are not eligible for continued service under this rate schedule. Eligibility for B-1 will be reviewed annually and the transition of customers that are no longer eligible for service on this rate schedule to Schedule B10 will occur on the start of the customer’s November billing cycle, or to Schedule B19 Mandatory for customers with a maximum demand of 499 kW or greater for three consecutive months in the most recent twelve months. These customers will have at least 45-day notice prior to their planned transition date, during which they will continue to take service on this rate schedule. Customers may elect any other applicable rate schedule up to five (5) days prior to the planned transition date to Schedule B-10. The provisions of Schedule SB—Standby Service Special Conditions 1 through 6 shall also apply to customers served under this schedule whose premises are regularly supplied in part (but not in whole) by electric energy from a non-utility source of supply. These customers will pay monthly reservation charges as specified under Section 1 of Schedule SB, in addition to all applicable Schedule B-1 charges. Exemptions to Standby Charges are outlined in the Standby Applicability Section of this rate schedule. (L) (L) * The Rules referred to in this schedule are part of PG&E’s electric tariffs. Copies are available at PG&E’s local offices and website at http://www.pge.com/tariffs (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 8 -

Revised U 39 Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE APPLICABILITY: (Cont’d) Sheet 2 B1-ST for Storage: The B1-ST rate for storage is an optional rate available to qualifying customers taking Bundled, DA or CCA service under Schedule B-1. The B1-ST rate is a pilot program that will be offered with a cap on the number of participants of 15,000. The B1-ST rate for storage is available to customers who are subject to the maximum demand eligibility requirements for the class of 75 kW or usage in excess of 150,000 kWh per year (as defined in each rate schedule) and have a minimum energy storage capacity equal to the greater of either 4.8 kWh or at least 0.05 percent of the customer’s annual usage (in kWh) for the previous 12 months. Customer under 75 kW that are eligible to take service on Schedule B-1 may elect to take service on B1-ST for Storage. For additional B1-ST details and program specifics see the Special Condition “B1-ST FOR STORAGE” provided further below in this tariff. (N) | | | | | | | | | | | (N) . TERRITORY: This rate schedule applies everywhere PG&E provides electric service. (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 9 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE RATES: 46464-E Sheet 3 Total bundled service charges are calculated using the total rates shown below. Direct Access (DA) and Community Choice Aggregation (CCA) charges shall be calculated in accordance with the paragraph in this rate schedule titled Billing. Time-of-Use Rates B-1 Rates (L) | (L) B1-ST Rates $0.32854 $0.32854 (N) $0.82136 $0.82136 (N) (L)(N) | | | | | (L)(N) (N) (N) (N) | | | | (N) Total Customer Charge Rates Customer Charge Single-phase ($ per meter per day) Customer Charge Poly-phase ($ per meter per day) Demand Charge (for B1-ST only) Total Demand Rate (per metered kW/month assessed from 2:00 p.m. to 11:00 p.m. only) Summer Winter ----- $3.64 $3.64 Total TOU Energy Rates ($ per kWh) Peak Summer Part-Peak Summer Off-Peak Summer $0.32805 $0.27882 $0.25801 (I) (I) (I) $0.39528 $0.25398 $0.20665 (N) (N) (N) Peak Winter Partial-Peak Winter (for B1-ST only) Off-Peak Winter Super Off-Peak Winter $0.25263 --$0.23651 $0.22009 (I) $0.29733 $0.26783 $0.17878 $0.16236 (N) (N) (N) (N) (I) (I) (L)(N) | | | | | (L)(N) (N) (L)(N) (L)(N) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 10 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE RATES: (Cont’d.) 46465-E Sheet 4 Total bundled service charges shown on customers’ bills are unbundled according to the component rates shown below. UNBUNDLING OF TOTAL RATES Time-of-Use Rates B-1 Rate B1-ST Rate (L) | | | (L) (L)(N) Customer and Demand Charge Rates: Customer and demand charge rates provided in the Total Rate section above are assigned entirely to the unbundled distribution component. (L)(T) (L)(T) (L) (L) Energy Rates by Components ($ per kWh) (L) | (L) (L)(N) | | | (L)(N) (N) (L)(N) | | | | | | | (L)(N) (N) (L)(N) | | | | | | | | | | | | (L)(N) Generation: Peak Summer Part-Peak Summer Off-Peak Summer $0.17737 $0.12814 $0.10733 (I) (I) (I) $0.18216 $0.13970 $0.10395 (N) (N) (N) $0.12212 ---$0.10600 $0.08958 (I) (I) (I) $0.13158 $0.11924 $0.09724 $0.08082 (N) (N) (N) (N) $0.09551 $0.09551 $0.09551 (I) (I) (I) $0.15795 $0.05911 $0.04753 (N) (N) (N) Peak Winter Partial-Peak Winter (For B1-ST Only) Off-Peak Winter Super Off-Peak Winter $0.07534 ---$0.07534 $0.07534 (I) $0.11058 $0.09342 $0.02637 $0.02637 (N) (N) (N) (N) Transmission* (all usage) Transmission Rate Adjustments* (all usage) Reliability Services* (all usage) Public Purpose Programs (all usage) Nuclear Decommissioning (all usage) Competition Transition Charges (all usage) Energy Cost Recovery Amount (all usage) New System Generation Charge (all usage)** DWR Bond (all usage) California Climate Credit (all usage)*** $0.02766 $0.00314 ($0.00051) $0.01299 $0.00101 $0.00092 $0.00005 $0.00411 $0.00580 $0.00000 $0.02766 $0.00314 $(0.00051) $0.01299 $0.00101 $0.00092 $0.00005 $0.00411 $0.00580 $0.00000 (N) (N) (N) (N) (N) (N) (N) (N) (N) (N) Peak Winter Partial-Peak Winter (For B1-ST Only) Off-Peak Winter Super Off-Peak Winter Distribution**: Peak Summer Part-Peak Summer Off-Peak Summer (I) (I) (R) (I) (R) (I) (I) * Transmission, Transmission Rate Adjustments, and Reliability Service charges are combined for presentation on customer bills. ** Distribution and New System Generation Charges are combined for presentation on customer bills. *** Only customers that qualify as Small Businesses – California Climate Credit under Rule 1 are eligible for the California Climate Credit. (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 11 -

Cancelling U 39 Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 45566-E* San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE TIME PERIOD Sheet 5 Times of the year and times of the day are defined as follows: SUMMER (Service from June 1 through September 30): Peak: 4:00 p.m. to 9:00 p.m. Every day, including weekends and holidays Partial-Peak: 2:00 p.m. to 4:00 p.m. AND Every day, including weekends 9:00 p.m. to 11:00 p.m. and holidays Off-Peak All other hours WINTER (Service from October 1, through May 31): Peak 4:00 p.m. to 9:00 p.m. Super Off Peak 9:00 a.m. to 2:00 p.m. Off-Peak Every day, including weekends and holidays Every day in March, April and May only, including weekends and holiday All other hours. For Customer on B1-ST Only Partial-Peak 2:00 p.m. to 4:00 p.m. AND 9:00 p.m. to 11:00 p.m. Every day, including weekends and holidays SEASONS: The summer rate is applicable June 1 through September 30, and the winter rate is applicable October 1 through May 31. When billing includes use in both the summer and winter periods, charges will be prorated based upon the number of days in each period. CONTRACT: For customers who use service for only part of the year, this schedule is available only on annual contract. COMMONAREA ACCOUNTS: Common-area accounts are those accounts that provide electric service to Common Use Areas as defined in Rule 1. Common-area accounts that are separately metered by PG&E and which took electric service from PG&E on or prior to January 16, 2003, had a one-time opportunity to return to a residential rate schedule from April 1, 2004, to May 31, 2004, by notifying PG&E in writing. These accounts remain eligible for service under this rate schedule if the customer did not invoke this first right of return. In the event that the CPUC substantially reduces the surcharges or substantially amends any or all of PG&E’s commercial or residential rate schedules, the Executive Council of Homeowners (ECHO) can direct PG&E to begin an optional second right-of-return period lasting 105 days. Newly constructed common-areas that are separately metered by PG&E and which first took electric service from PG&E after January 16, 2003, have a one-time opportunity to transfer to a residential rate schedule during a two-month window that begins 14 months after taking service on a commercial rate schedule. This must be done by notifying PG&E in writing. These common-area accounts have an additional opportunity to return to a residential schedule in the event that ECHO directs PG&E to begin a second right-of-return period. (L) | | | | | | | | | | | | | | | | (L) (N) | (N) (L) | | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 12 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE BILLING: 46466-E Sheet 6 A customer’s bill is calculated based on the option applicable to the customer. Bundled Service Customers receive supply and delivery services solely from PG&E. The customer’s bill is based on the total rates and conditions set forth in this schedule. Transitional Bundled Service Customers take transitional bundled service as prescribed in Rules 22.1 and 23, or take bundled service prior to the end of the six (6) month advance notice period required to elect bundled portfolio service as prescribed in Rules 22.1 and 23. These customers shall pay charges for transmission, transmission rate adjustments, reliability services, distribution, nuclear decommissioning, public purpose programs, New System Generation Charges, the applicable Cost Responsibility Surcharge (CRS) pursuant to Schedule DA CRS or Schedule CCA CRS and short-term commodity prices as set forth in Schedule TBCC. Direct Access (DA) and Community Choice Aggregation (CCA) Customers purchase energy from their non-utility provider and continue receiving delivery services from PG&E. Bills are equal to the sum of charges for transmission, transmission rate adjustments, reliability services, distribution, public purpose programs, nuclear decommissioning, New System Generation Charges, the franchise fee surcharge, and the applicable CRS. The CRS is equal to the sum of the individual charges set forth below. Exemptions to the CRS are set forth in Schedules DA CRS and CCA CRS. DA /CCA CRS Energy Cost Recovery Amount Charge (per kWh) DWR Bond Charge (per kWh) CTC Charge (per kWh) $0.00005 $0.00580 $0.00092 (I) (R) $0.02453 $0.02756 $0.02990 $0.02979 $0.03186 $0.03230 $0.03213 $0.03199 $0.03194 $0.03196 $0.03406 $0.04065 (I) (I) (I) (I) (I) (I) (I) (I) (I) (I) (I) (N) Power Charge Indifference Adjustment (per kWh) 2009 Vintage 2010 Vintage 2011 Vintage 2012 Vintage 2013 Vintage 2014 Vintage 2015 Vintage 2016 Vintage 2017 Vintage 2018 Vintage 2019 Vintage 2020 Vintage (L) | | | || | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 13 -

Cancelling U 39 Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 45568-E San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE Sheet 7 CARE DISCOUNT: Nonprofit Group-Living Facilities which meet the eligibility criteria in Rule 19.2 or 19.3 are eligible for a California Alternate Rates for Energy discount pursuant to Schedule E CARE. CARE customers are exempt from paying the DWR Bond Charge. STANDBY APPLICABILITY: SOLAR GENERATION FACILITIES EXEMPTION: Customers who utilize solar generating facilities which are less than or equal to one megawatt to serve load and who do not sell power or make more than incidental export of power into PG&E’s power grid and who have not elected service under Schedule NEM, will be exempt from paying the otherwise applicable standby reservation charges. DISTRIBUTED ENERGY RESOURCES EXEMPTION: Any customer under a time-of-use rate schedule using electric generation technology that meets the criteria as defined in Electric Rule 1 for Distributed Energy Resources is exempt from the otherwise applicable standby reservation charges. Customers qualifying for this exemption shall be subject to the following requirements. Customers qualifying for an exemption from standby charges under Public Utilities (PU) Code Sections 353.1 and 353.3, as described above, must transfer to Schedule A-6 or E-19, to receive this exemption until a real-time pricing program, as described in PU Code 353.3, is made available. Once available, customers qualifying for the standby charge exemption must participate in the real-time program referred to above. Qualification for and receipt of this distributed energy resources exemption does not exempt the customer from metering charges applicable to time-of-use (TOU) and real-time pricing, or exempt the customer from reasonable interconnection charges, non-bypassable charges as required in Preliminary Statement BB - Competition Transition Charge Responsibility for All Customers and CTC Procurement, or obligations determined by the Commission to result from participation in the purchase of power through the California Department of Water Resources, as provided in PU Code Section 353.7. DWR BOND CHARGE: The Department of Water Resources (DWR) Bond Charge was imposed by California Public Utilities Commission Decision 02-10-063, as modified by Decision 02-12-082, and is property of DWR for all purposes under California law. The Bond Charge applies to all retail sales, excluding CARE and Medical Baseline sales. The DWR Bond Charge (where applicable) is included in customers’ total billed amounts. (L) | | I | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 14 -

Revised U 39 Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE B1-ST FOR STORAGE OPTION: Sheet 8 B1-ST for Storage: The B1-ST for storage (“B1-ST”) option is available to qualifying customers taking Bundled, DA or CCA service that are eligible to take service under Schedule B-1. The B1-ST option is available to customers who are subject to the maximum demand eligibility requirements for the class of 75 kW or usage in excess of 150,000 kWh per year (as defined in each rate schedule) and have a minimum energy storage capacity equal to the greater of either 4.8 kWh or at least 0.05 percent of the customer’s annual usage (in kWh) for the previous 12 months. If customer has usage history less than 12 months or customer has no usage history the battery capacity must be greater or equal to 4.8 kWh in order to qualify for the B1-ST. The energy capacity (Wh) for energy storage technologies is calculated as follows: DC/AC systems: The nominal voltage multiplied by the amp-hour capacity multiplied by the applicable efficiency (VDC x Amp-Hours x (1 kW/1000W) x Applicable Efficiency). The following specifications must be provided to calculate energy capacity: • Duration of discharge (hours) • DC dischargeable amp-hour capacity, associated with the duration of discharge specified, including all losses and ancillary loads (such as power conditioning and thermal management) • Nominal voltage (VDC) • Applicable efficiency (if necessary), which accounts for conversion, transformation, or other efficiency losses (e.g. Inverter CEC weighted efficiency, DC-DC converter efficiency, etc.) Basis for Demand Charge (applicable to B1-ST) The customer will be billed for demand according to the customer’s “maximum demand” each month based on the single highest demand occurring during the combined on-peak and part-peak period (2:00 p.m. to 11:00 p.m.). The demand charge will not apply to demand during the off-peak and super off-peak periods. However, the 75 kW eligibility threshold evaluation will include demand during the off-peak and super off-peak periods. The number of kW used will be recorded over 15-minute intervals; the highest 15-minute average in the month outside of off-peak and super off-peak hours will be the customer's maximum demand for demand charge per kW billing purposes. (N) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (N) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 15 -

Advice 5830-E May 19, 2020 Attachment 2 Redline Tariffs
- Page 16 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 46358-E San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE APPLICABILITY: Sheet 1 Schedule B-1 applies to single-phase and polyphase alternating-current service (for a description of these terms, see Section D of Rule 2*). This schedule is not available to residential or agricultural service for which a residential or agricultural schedule is applicable, except for single-phase and polyphase service in common areas in a multifamily complex (see Common-Area Accounts section). Customers that are otherwise eligible to take service on Schedule B-1 but are purchasing power to serve electric vehicle charging equipment, are not eligible to take service on this rate schedule. Decision 18-08-013 adopted new TOU periods and seasonal definitions for all nonresidential customer classes. Schedules A-1, A-6, A-10, E-19 and E-20 will be retained as legacy rate schedules with their current TOU periods until the rates with new TOU periods (Schedules B-1, B-6, B-10, B-19 and B-20) established in the same proceeding, become mandatory in March 2021. Certain qualifying customers with solar systems will be permitted to maintain (i.e., be grandfathered on) their existing legacy TOU rate periods for a certain period of time, per Decision 17-01-006, as described in the Electric Rule 1, Definitions: Behind-the-Meter Solar TOU Grandfathering and Eligibility Requirements. These new rates with revised TOU periods adopted in D.18-08-013, including Schedule B-1, will be available to qualifying customers on a voluntary basis beginning in November 2019 through February 2021. During that period, eligible customers have a one-time opportunity to opt-in.. Customers eligible for this rate schedule must have an interval data meter that can be read remotely by PG&E. Beginning March 2021, customers still served on Schedule A-1, with the exception of solar grandfathered customers referenced above, will be transitioned to Schedule B-1 with revised TOU periods. The mandatory transition process is further described in the legacy rate Schedule A-1. Customers with a maximum demand of 75 kW or greater for three consecutive months in the most recent twelve months are not eligible for continued service under this rate schedule. Eligibility for B-1 will be reviewed annually and the transition of customers that are no longer eligible for service on this rate schedule to Schedule B10 will occur on the start of the customer’s November billing cycle, or to Schedule B19 Mandatory for customers with a maximum demand of 499 kW or greater for three consecutive months in the most recent twelve months. These customers will have at least 45-day notice prior to their planned transition date, during which they will continue to take service on this rate schedule. Customers may elect any other applicable rate schedule up to five (5) days prior to the planned transition date to Schedule B-10. The provisions of Schedule SB—Standby Service Special Conditions 1 through 6 shall also apply to customers served under this schedule whose premises are regularly supplied in part (but not in whole) by electric energy from a non-utility source of supply. These customers will pay monthly reservation charges as specified under Section 1 of Schedule SB, in addition to all applicable Schedule B-1 charges. Exemptions to Standby Charges are outlined in the Standby Applicability Section of this rate schedule. TERRITORY: This rate schedule applies everywhere PG&E provides electric service. (L) (L) * The Rules referred to in this schedule are part of PG&E’s electric tariffs. Copies are available at PG&E’s local offices and website at http://www.pge.com/tariffs (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 17 -

Revised U 39 Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE APPLICABILITY: (Cont’d) Sheet 2 B1-ST for Storage: The B1-ST rate for storage is an optional rate available to qualifying customers taking Bundled, DA or CCA service under Schedule B-1. The B1-ST rate option is a pilot program that will be offered with a cap on the number of participants of 15,000. The B1-ST rate for storage is available to customers who are subject to the maximum demand eligibility requirements for the class of 75 kW or usage in excess of 150,000 kWh per year (as defined in each rate schedule) and have a minimum energy storage capacity equal to the greater of either 4.8 kWh or at least 0.05 percent of the customer’s annual usage (in kWh) for the previous 12 months. Customer under 75 kW that are eligible to take service on Schedule B-1 may elect to take service on B1-ST for Storage. For additional B1-ST details and program specifics see the Special Condition “B1-ST FOR STORAGE” provided further below in this tariff. (N) | | | | | | | | | | | (N) . TERRITORY: This rate schedule applies everywhere PG&E provides electric service. (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 18 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE RATES: 46464-E Sheet 3 Total bundled service charges are calculated using the total rates shown below. Direct Access (DA) and Community Choice Aggregation (CCA) charges shall be calculated in accordance with the paragraph in this rate schedule titled Billing. Time-of-Use Rates B-1 Rates (L) | (L) B1-ST Rates $0.32854 $0.32854 (N) $0.82136 $0.82136 (N) (L)(N) | | | | | (L)(N) (N) (N) (N) | | | | (N) Total Customer Charge Rates Customer Charge Single-phase ($ per meter per day) Customer Charge Poly-phase ($ per meter per day) Demand Charge (for B1-ST only) Total Demand Rate (per metered kW/month assessed from 2 pm to 11 pm only) Summer Winter ----- $3.64 $3.64 Total TOU Energy Rates ($ per kWh) Peak Summer Part-Peak Summer Off-Peak Summer $0.32805 $0.27882 $0.25801 (I) (I) (I) $0.39528 $0.25398 $0.20665 (N) (N) (N) Peak Winter Partial-Peak Winter (for B1-ST only) Off-Peak Winter Super Off-Peak Winter $0.25263 --$0.23651 $0.22009 (I) $0.29733 $0.26783 $0.17878 $0.16236 (N) (N) (N) (N) (I) (I) (L)(N) | | | | | (L)(N) (N) (L)(N) (L)(N) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 19 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE RATES: (Cont’d.) 46465-E Sheet 4 Total bundled service charges shown on customers’ bills are unbundled according to the component rates shown below. UNBUNDLING OF TOTAL RATES Time-of-Use Rates B-1 Rate B1-ST Rate (L) | | | (L) (L)(N) Customer and Demand Charge Rates: Customer and demand charge rates provided in the Total Rate section above are assigned entirely to the unbundled distribution component. (L)(T) (L)(T) (L) (L) Energy Rates by Components ($ per kWh) (L) | (L) (L)(N) | | | (L)(N) (N) (L)(N) | | | | | | | (L)(N) (N) (L)(N) | | | | | | | | | | | | (L)(N) Generation: Peak Summer Part-Peak Summer Off-Peak Summer $0.17737 $0.12814 $0.10733 (I) (I) (I) $0.18216 $0.13970 $0.10395 (N) (N) (N) $0.12212 ---$0.10600 $0.08958 (I) (I) (I) $0.13158 $0.11924 $0.09724 $0.08082 (N) (N) (N) (N) $0.09551 $0.09551 $0.09551 (I) (I) (I) $0.15795 $0.05911 $0.04753 (N) (N) (N) Peak Winter Partial-Peak Winter (For B1-ST Only) Off-Peak Winter Super Off-Peak Winter $0.07534 ---$0.07534 $0.07534 (I) $0.11058 $0.09342 $0.02637 $0.02637 (N) (N) (N) (N) Transmission* (all usage) Transmission Rate Adjustments* (all usage) Reliability Services* (all usage) Public Purpose Programs (all usage) Nuclear Decommissioning (all usage) Competition Transition Charges (all usage) Energy Cost Recovery Amount (all usage) New System Generation Charge (all usage)** DWR Bond (all usage) California Climate Credit (all usage)*** $0.02766 $0.00314 ($0.00051) $0.01299 $0.00101 $0.00092 $0.00005 $0.00411 $0.00580 $0.00000 $0.02766 $0.00314 $(0.00051) $0.01299 $0.00101 $0.00092 $0.00005 $0.00411 $0.00580 $0.00000 (N) (N) (N) (N) (N) (N) (N) (N) (N) (N) Peak Winter Partial-Peak Winter (For B1-ST Only) Off-Peak Winter Super Off-Peak Winter Distribution**: Peak Summer Part-Peak Summer Off-Peak Summer (I) (I) (R) (I) (R) (I) (I) * Transmission, Transmission Rate Adjustments, and Reliability Service charges are combined for presentation on customer bills. ** Distribution and New System Generation Charges are combined for presentation on customer bills. *** Only customers that qualify as Small Businesses – California Climate Credit under Rule 1 are eligible for the California Climate Credit. (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 20 -

Cancelling U 39 Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 45566-E* San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE TIME PERIOD Sheet 5 Times of the year and times of the day are defined as follows: SUMMER (Service from June 1 through September 30): Peak: 4:00 p.m. to 9:00 p.m. Every day, including weekends and holidays Every day, including weekends Partial-Peak: 2:00 p.m. to 4:00 p.m. AND and holidays 9:00 p.m. to 11:00 p.m. Off-Peak All other hours WINTER (Service from October 1, through May 31): Peak 4:00 p.m. to 9:00 p.m. Super Off Peak 9:00 a.m. to 2:00 p.m. Off-Peak All other hours. Every day, including weekends and holidays Every day in March, April and May only, including weekends and holiday For Customer on B1-ST Only Partial-Peak 2:00 p.m. to 4:00 p.m. AND 9:00 p.m. to 11:00 p.m. Every day, including weekends and holidays SEASONS: The summer rate is applicable June 1 through September 30, and the winter rate is applicable October 1 through May 31. When billing includes use in both the summer and winter periods, charges will be prorated based upon the number of days in each period. CONTRACT: For customers who use service for only part of the year, this schedule is available only on annual contract. COMMONAREA ACCOUNTS: Common-area accounts are those accounts that provide electric service to Common Use Areas as defined in Rule 1. Common-area accounts that are separately metered by PG&E and which took electric service from PG&E on or prior to January 16, 2003, had a one-time opportunity to return to a residential rate schedule from April 1, 2004, to May 31, 2004, by notifying PG&E in writing. These accounts remain eligible for service under this rate schedule if the customer did not invoke this first right of return. In the event that the CPUC substantially reduces the surcharges or substantially amends any or all of PG&E’s commercial or residential rate schedules, the Executive Council of Homeowners (ECHO) can direct PG&E to begin an optional second right-of-return period lasting 105 days. Newly constructed common-areas that are separately metered by PG&E and which first took electric service from PG&E after January 16, 2003, have a one-time opportunity to transfer to a residential rate schedule during a two-month window that begins 14 months after taking service on a commercial rate schedule. This must be done by notifying PG&E in writing. These common-area accounts have an additional opportunity to return to a residential schedule in the event that ECHO directs PG&E to begin a second right-of-return period. (L) | | | | | | | | | | | | | | | | (L) (N) | | (N) (L) | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 21 -

Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE BILLING: 46466-E Sheet 6 A customer’s bill is calculated based on the option applicable to the customer. Bundled Service Customers receive supply and delivery services solely from PG&E. The customer’s bill is based on the total rates and conditions set forth in this schedule. Transitional Bundled Service Customers take transitional bundled service as prescribed in Rules 22.1 and 23, or take bundled service prior to the end of the six (6) month advance notice period required to elect bundled portfolio service as prescribed in Rules 22.1 and 23. These customers shall pay charges for transmission, transmission rate adjustments, reliability services, distribution, nuclear decommissioning, public purpose programs, New System Generation Charges, the applicable Cost Responsibility Surcharge (CRS) pursuant to Schedule DA CRS or Schedule CCA CRS and short-term commodity prices as set forth in Schedule TBCC. Direct Access (DA) and Community Choice Aggregation (CCA) Customers purchase energy from their non-utility provider and continue receiving delivery services from PG&E. Bills are equal to the sum of charges for transmission, transmission rate adjustments, reliability services, distribution, public purpose programs, nuclear decommissioning, New System Generation Charges, the franchise fee surcharge, and the applicable CRS. The CRS is equal to the sum of the individual charges set forth below. Exemptions to the CRS are set forth in Schedules DA CRS and CCA CRS. DA /CCA CRS Energy Cost Recovery Amount Charge (per kWh) DWR Bond Charge (per kWh) CTC Charge (per kWh) $0.00005 $0.00580 $0.00092 (I) (R) $0.02453 $0.02756 $0.02990 $0.02979 $0.03186 $0.03230 $0.03213 $0.03199 $0.03194 $0.03196 $0.03406 $0.04065 (I) (I) (I) (I) (I) (I) (I) (I) (I) (I) (I) (N) Power Charge Indifference Adjustment (per kWh) 2009 Vintage 2010 Vintage 2011 Vintage 2012 Vintage 2013 Vintage 2014 Vintage 2015 Vintage 2016 Vintage 2017 Vintage 2018 Vintage 2019 Vintage 2020 Vintage (L) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 22 -

Cancelling U 39 Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 45568-E San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE Sheet 7 CARE DISCOUNT: Nonprofit Group-Living Facilities which meet the eligibility criteria in Rule 19.2 or 19.3 are eligible for a California Alternate Rates for Energy discount pursuant to Schedule E CARE. CARE customers are exempt from paying the DWR Bond Charge. STANDBY APPLICABILITY: SOLAR GENERATION FACILITIES EXEMPTION: Customers who utilize solar generating facilities which are less than or equal to one megawatt to serve load and who do not sell power or make more than incidental export of power into PG&E’s power grid and who have not elected service under Schedule NEM, will be exempt from paying the otherwise applicable standby reservation charges. DISTRIBUTED ENERGY RESOURCES EXEMPTION: Any customer under a time-of-use rate schedule using electric generation technology that meets the criteria as defined in Electric Rule 1 for Distributed Energy Resources is exempt from the otherwise applicable standby reservation charges. Customers qualifying for this exemption shall be subject to the following requirements. Customers qualifying for an exemption from standby charges under Public Utilities (PU) Code Sections 353.1 and 353.3, as described above, must transfer to Schedule A-6 or E-19, to receive this exemption until a real-time pricing program, as described in PU Code 353.3, is made available. Once available, customers qualifying for the standby charge exemption must participate in the real-time program referred to above. Qualification for and receipt of this distributed energy resources exemption does not exempt the customer from metering charges applicable to time-of-use (TOU) and real-time pricing, or exempt the customer from reasonable interconnection charges, non-bypassable charges as required in Preliminary Statement BB - Competition Transition Charge Responsibility for All Customers and CTC Procurement, or obligations determined by the Commission to result from participation in the purchase of power through the California Department of Water Resources, as provided in PU Code Section 353.7. DWR BOND CHARGE: The Department of Water Resources (DWR) Bond Charge was imposed by California Public Utilities Commission Decision 02-10-063, as modified by Decision 02-12-082, and is property of DWR for all purposes under California law. The Bond Charge applies to all retail sales, excluding CARE and Medical Baseline sales. The DWR Bond Charge (where applicable) is included in customers’ total billed amounts. (L) | | I | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (L) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 23 -

Revised U 39 Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE B-1 SMALL GENERAL SERVICE B1-ST FOR STORAGE OPTION: Sheet 8 B1-ST for Storage: The B1-ST for storage (“B1-ST”) option is available to qualifying customers taking Bundled, DA or CCA service that are eligible to take service under Schedule B1. The B1-ST option is available to customers who are subject to the maximum demand eligibility requirements for the class of 75 kW or usage in excess of 150,000 kWh per year (as defined in each rate schedule) and have a minimum energy storage capacity equal to the greater of either 4.8 kWh or at least 0.05 percent of the customer’s annual usage (in kWh) for the previous 12 months. If customer has usage history less than 12 months or customer has no usage history the battery capacity must be greater or equal to 4.8 kWh in order to qualify for the B1-ST. The energy capacity (Wh) for energy storage technologies is calculated as follows: DC/AC systems: The nominal voltage multiplied by the amp-hour capacity multiplied by the applicable efficiency (VDC x Amp-Hours x (1 kW/1000W) x Applicable Efficiency). The following specifications must be provided to calculate energy capacity: • Duration of discharge (hours) • DC dischargeable amp-hour capacity, associated with the duration of discharge specified, including all losses and ancillary loads (such as power conditioning and thermal management) • Nominal voltage (VDC) • Applicable efficiency (if necessary), which accounts for conversion, transformation, or other efficiency losses (e.g. Inverter CEC weighted efficiency, DC-DC converter efficiency, etc.) Basis for Demand Charge (applicable to B1-ST) The customer will be billed for demand according to the customer’s “maximum demand” each month based on the single highest demand occurring during the combined on-peak and part-peak period (2:00 p.m. to 11:00 p.m.). The demand charge will not apply to demand during the off-peak and super off-peak period. However, the 75 kW eligibility threshold evaluation will include demand during the off-peak and super off-peak periods. The number of kW used will be recorded over 15-minute intervals; the highest 15-minute average in the month outside of off-peak and super off-peak hours will be the customer's maximum demand for demand charge per kW billing purposes. (N) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (N) (Continued) Advice Decision 5830-E 18-08-013 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution May 19, 2020
- Page 24 -

PG&E Gas and Electric Advice Submittal List General Order 96-B, Section IV AT&T Albion Power Company Alcantar & Kahl LLP Downey & Brand East Bay Community Energy Ellison Schneider & Harris LLP Energy Management Service Alta Power Group, LLC Anderson & Poole Engineers and Scientists of California Atlas ReFuel BART Barkovich & Yap, Inc. California Cotton Ginners & Growers Assn California Energy Commission California Public Utilities Commission California State Association of Counties Calpine Cameron-Daniel, P.C. Casner, Steve Cenergy Power Center for Biological Diversity Chevron Pipeline and Power City of Palo Alto City of San Jose Clean Power Research Coast Economic Consulting Commercial Energy Crossborder Energy Crown Road Energy, LLC Davis Wright Tremaine LLP Day Carter Murphy Dept of General Services Don Pickett & Associates, Inc. Douglass & Liddell GenOn Energy, Inc. Goodin, MacBride, Squeri, Schlotz & Ritchie Green Power Institute Hanna & Morton ICF IGS Energy International Power Technology Intestate Gas Services, Inc. Kelly Group Ken Bohn Consulting Keyes & Fox LLP Leviton Manufacturing Co., Inc. Los Angeles County Integrated Waste Management Task Force MRW & Associates Manatt Phelps Phillips Marin Energy Authority McKenzie & Associates Modesto Irrigation District NLine Energy, Inc. NRG Solar Office of Ratepayer Advocates OnGrid Solar Pacific Gas and Electric Company Peninsula Clean Energy Pioneer Community Energy Redwood Coast Energy Authority Regulatory & Cogeneration Service, Inc. SCD Energy Solutions SCE SDG&E and SoCalGas SPURR San Francisco Water Power and Sewer Seattle City Light Sempra Utilities Southern California Edison Company Southern California Gas Company Spark Energy Sun Light & Power Sunshine Design Tecogen, Inc. TerraVerde Renewable Partners Tiger Natural Gas, Inc. TransCanada Troutman Sanders LLP Utility Cost Management Utility Power Solutions Water and Energy Consulting Wellhead Electric Company Western Manufactured Housing Communities Association (WMA) Yep Energy
- Page 25 -