Details for: PGE AL 5493-E.pdf


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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

March 11, 2019

Advice 5493-E
(Pacific Gas and Electric Company ID U 39 E)

Public Utilities Commission of the State of California
Subject:

Tariffs Updates for Remaining Demand Response Issues Per
Decision 18-11-029

Purpose
Pacific Gas and Electric Company (PG&E) hereby submits this advice letter to modify
its tariffs pursuant to Ordering Paragraph (OP) 1 of Decision (D.) 18-11-029. Also,
specific to the BIP tariff, PG&E is making updates pursuant to OP 2, OP 4 and OP 5.
Background
On December 10, 2018, the California Public Utilities Commission (CPUC) issued D.
18-11-0291 titled “Decision Resolving Remaining Application Issues for the 2018-2022
Demand Response Portfolios and Declining to Authorize Additional Demand Response
Auction Mechanism Pilot Solicitations.” D.18-11-029 ordered the IOUs to make a
number of tariff updates, including the submission of advice filings. The updates herein
pertain to limitations placed on dual participation and modifications to the management
of the cap utilized for reliability demand response. Furthermore, in a few cases
clarifying edits were made to improve context and readability. 2
Dual Participation
OP 1 of the Decision effectively limited incremental dual enrollments (i.e. grandfathered) between a “Critical Peak Pricing” program3 and another utility or third-party
1

2

3

D.18-11-029 resolved remaining issues from PG&E’s Application 17-01-012 (2018-2022 DR
Funding), which was originally approved by D.17-12-003.
For the SmartAC tariffs (E-RSAC and E-CSAC), the generic term “time varying rates” was
replaced with the specific PG&E program name. This included “SmartRate” for E-RSAC and
“PDP” for E-CSAC. Separately, for the E-RSMART (SmartRate) tariff, the term Demand
“Reduction” was corrected to Demand “Response.”
PG&E’s Critical Pricing Programs (CPP) include SmartRate for residential and PDP for nonresidential customers. While SmartRate has its own separate tariff, PDP is a rider embedded
within the applicable tariff of the non-residential rate (A-1, AG-4, AG-5, A-6, A-10, A-19 and A20).





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Advice 5493-E -2- March 11, 2019 demand response (DR) program “beginning immediately and until further notice.” The start of this limitation was subsequently clarified in a modified Proposed Decision to be “prior to October 26, 2018.”4 Furthermore, dual enrolled participants that were grandfathered were now further limited to being “capped at the current megawatt level”5 as of November 29, 2018, the date of the Decision as understood by PG&E. Reliability Cap Management D.18-11-029 modified how the two percent reliability cap 6 is managed for Reliability Demand Response Resources (RDRR), which includes PG&E’s BIP tariff and resources offered through the Demand Response Auction Mechanism. Discussion Dual Participation PG&E expressed in opening and reply comments concerns related to the implementation of the dual participation restriction. 7 In particular, the need to make IT system changes that could take 5-9 months.8 In the interim, there would be no option other than having a manual work-around to prevent and/or identify erroneous dual enrollments. Aggravating this situation, the PD was revised on November 28, 2018, by adding retroactively the dual enrollment cut-off date as of October 26, 2018. 9 Due to this retractive change, PG&E has identified customers that have become dually enrolled or requested enrollment since October 26, 2108. These customers, and subsequent customers who may be inadvertently enrolled, will have to be informed about their ineligibility for dual enrollment, and either be de-enrolled or their enrollment request cancelled.10 While preventative measures have been implemented to keep this occurrence low, this manual process will be in place until IT system changes are completed. 4 The Proposed Decision (PD) for D.18-11-029 was originally released on 10/25/12018 with a revised version released on 11/28/2018, the day before the PD was adopted by the CPUC on 11/29/2018. The revised version modified OP 1 by: (a) extending the tariff compliance filing from 60 to 90 days from the issuance of the decision (12/10/2018), and (b) introducing two retroactive conditions by adding language to state “…in the specific demand response programs in which they had participated prior to October 26, 2018 and capped at the current megawatt level.” 5 Ibid 4, part b. 6 D.10-06-034, which adopted the settlement agreement, specified that starting in 2014 the reliability cap would be set at two percent of the recorded all-time coincident CAISO peak load. 7 PG&E Opening Comments dated November 14, 2018, page 2, part b. PG&E Reply Comments dated November 19, 2018, pages 2-3, part III. 8 These IT changes are especially acute for SmartRate, as this program option is more automated in the billing system than for PDP. 9 Ibid 4, part b. 10 The identified dual enrollments occurred between SmartRate and SmartAC (residential).
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Advice 5493-E -3- March 11, 2019 Reliability Cap Management OPs 2, 4, and 5 call for changes to how the reliability cap is managed. A number of changes are being proposed to the BIP tariff, including the addition of a new section titled “Reliability Cap.” in order to comply with the Decision. Because there were ambiguities in the Decision with respect to the reliability cap, the three IOUs convened to interpret the relevant provisions of the Decision in order to encourage consistency where at all possible.11 Tariff Revisions The following table provides a roadmap of the applicable modifications to the tariffs: Tariff Program BIP (commercial) Demand Response SmartAC (RSAC: residential) SmartAC (CSAC: commercial) SmartRate (residential) A-1 (commercial) Demand Response Demand Response A-6 (commercial) A-10 (commercial) E-19 (commercial) E-20 (commercial) AG-4 (agriculture) AG-5 (agriculture) 11 Critical Peak Pricing (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Rate with PDP (CPP) Tariff Sheet(s) 1, 2,12,13 Issue(s) 2 Dual participation and the Reliability Cap Dual Participation 2,3 Dual Participation 5 Dual Participation 12 Dual Participation 10 Dual Participation 15 Dual Participation 21 Dual Participation 15 Dual Participation 18 Dual Participation 20 Dual Participation The three IOUs convened to develop a brief interpretation document that was presented to the Energy Division on February 22, 2019. This document was intended to guide each IOU in communicating the process to BIP participants and Aggregators to ensure that there was consistency in both process and messaging.
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Advice 5493-E -4- March 11, 2019 Protests Anyone wishing to protest this advice letter may do so by letter sent via U.S. mail, facsimile or E-mail, no later than April 1, 2019, which is 21 days12 after the date of this filing. Protests must be submitted to: CPUC Energy Division ED Tariff Unit 505 Van Ness Avenue, 4th Floor San Francisco, California 94102 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). 12 The 20-day protest period concludes on a weekend, therefore, PG&E is moving this date to the following business day.
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Advice 5493-E -5- March 11, 2019 Effective Date PG&E requests that this Tier 1 advice letter become effective upon date of submittal, which is March 11, 2019. 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.17-01-012. 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 or at Process_Office@cpuc.ca.gov. Send all electronic approvals to PGETariffs@pge.com. Advice letter filings can also be accessed electronically at: http://www.pge.com/tariffs/. /S/ Erik Jacobson Director, Regulatory Relations Attachments cc: Service List A.17-01-012 et al.
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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 U39E) Utility type: ELC GAS PLC ✔ HEAT ELC = Electric PLC = Pipeline WATER Contact Person: Yvonne Yang Phone #: (415)973-2094 E-mail: PGETariffs@pge.com E-mail Disposition Notice to: Yvonne.Yang@pge.com EXPLANATION OF UTILITY TYPE GAS = Gas WATER = Water HEAT = Heat (Date Submitted / Received Stamp by CPUC) Tier Designation: 1 Advice Letter (AL) #: 5493-E Subject of AL: Tariffs Updates for Remaining Demand Response Issues Per D. 18-11-029 Keywords (choose from CPUC listing): Compliance AL Type: Monthly Quarterly Annual ✔ One-Time Other: If AL submitted in compliance with a Commission order, indicate relevant Decision/Resolution #: D.18-11-029 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: Yes Yes ✔ No ✔ No 3/11/19 No. of tariff sheets: 21 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: Please see attachment 1 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
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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 94177 Zip: 94177 State: California Telephone (xxx) xxx-xxxx: (415)973-2093 Facsimile (xxx) xxx-xxxx: (415)973-3582 Email: PGETariffs@pge.com Name: Title: Utility Name: Address: City: State: District of Columbia Telephone (xxx) xxx-xxxx: Facsimile (xxx) xxx-xxxx: Email: Zip: Clear Form
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Attachment 1 Advice 5493-E Cal P.U.C. Sheet No. Title of Sheet Cancelling Cal P.U.C. Sheet No. 43916-E ELECTRIC SCHEDULE A-1 SMALL GENERAL SERVICE Sheet 12 40711-E 43917-E ELECTRIC SCHEDULE A-10 MEDIUM GENERAL DEMAND-METERED SERVICE Sheet 15 40714-E 43918-E ELECTRIC SCHEDULE A-6 SMALL GENERAL TIME-OF-USE SERVICE Sheet 10 40717-E 43919-E ELECTRIC SCHEDULE AG-4 TIME-OF-USE AGRICULTURAL POWER Sheet 18 40720-E 43920-E ELECTRIC SCHEDULE AG-5 LARGE TIME-OF-USE AGRICULTURAL POWER Sheet 20 40723-E 43921-E ELECTRIC SCHEDULE E-19 MEDIUM GENERAL DEMAND-METERED TOU SERVICE Sheet 21 42859-E 43922-E ELECTRIC SCHEDULE E-20 SERVICE TO CUSTOMERS WITH MAXIMUM DEMANDS of 1000 KILOWATTS or MORE Sheet 15 42862-E 43923-E ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM Sheet 1 42644-E 43924-E ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM Sheet 2 42645-E 43925-E ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM Sheet 12 42655-E 43926-E ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM Sheet 13 42656-E 43927-E ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM Sheet 2 31306-E 43928-E ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM Sheet 3 27302-E Page 1 of 2
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Attachment 1 Advice 5493-E Cal P.U.C. Sheet No. Title of Sheet Cancelling Cal P.U.C. Sheet No. 43929-E ELECTRIC SCHEDULE E-RSAC RESIDENTIAL SMART A/C PROGRAM Sheet 2 41741-E 43930-E ELECTRIC SCHEDULE E-RSMART RESIDENTIAL SMARTRATE PROGRAM Sheet 5 26394-E 43931-E ELECTRIC TABLE OF CONTENTS Sheet 1 43875-E 43932-E ELECTRIC TABLE OF CONTENTS Sheet 3 43877-E 43933-E ELECTRIC TABLE OF CONTENTS Sheet 4 43878-E 43934-E ELECTRIC TABLE OF CONTENTS Sheet 7 43881-E 43935-E ELECTRIC TABLE OF CONTENTS Sheet 9 43322-E 43936-E ELECTRIC TABLE OF CONTENTS Sheet 10 43882-E Page 2 of 2
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE A-1 SMALL GENERAL SERVICE PEAK DAY PRICING DETAILS (CONT’D): 43916-E 40711-E Sheet 12 g. Program Options: Customers may customize their PDP participation by choosing either a) no limit on the number of consecutive PDP events or b) every other PDP event. Customers electing every other PDP event will be divided into two groups and only be subject to a maximum of one-half of the PDP events called and the corresponding PDP rate credits will be reduced by 50%. Customers that do not elect an option will be defaulted to the no limit on the number of consecutive PDP events. The duration of PDP Event Operations for both options will be from 2:00 p.m. to 6:00 p.m. (four-hour window). h. Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted on PG&E’s PDP Website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during its initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE A-10 MEDIUM GENERAL DEMAND-METERED SERVICE PEAK DAY PRICING DETAILS (continued) 43917-E 40714-E h. Sheet 15 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43918-E 40717-E San Francisco, California ELECTRIC SCHEDULE A-6 SMALL GENERAL TIME-OF-USE SERVICE PEAK DAY PRICING DETAILS (continued) h. Sheet 10 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down by 2°F over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11-029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43919-E 40720-E San Francisco, California ELECTRIC SCHEDULE AG-4 TIME-OF-USE AGRICULTURAL POWER 16. PEAK DAY PRICING DETAILS (CONT’D): Sheet 18 g. Program Options: Customers may customize their PDP participation by choosing either a) no limit on the number of consecutive PDP events or b) every other PDP event. Customers electing every other PDP event will be divided into two groups and only be subject to a maximum of one-half of the PDP events called and the corresponding PDP rate credits will be reduced by 50%. Customers that do not elect an option will be defaulted to the no limit on the number of consecutive PDP events. The duration of PDP Event Operations for both options will be from 2:00 p.m. to 6:00 p.m. (four-hour window). h. Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43920-E 40723-E San Francisco, California ELECTRIC SCHEDULE AG-5 LARGE TIME-OF-USE AGRICULTURAL POWER 17. PEAK DAY PRICING DETAILS (CONT’D): i. Sheet 20 Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43921-E 42859-E San Francisco, California ELECTRIC SCHEDULE E-19 MEDIUM GENERAL DEMAND-METERED TOU SERVICE 19. PEAK DAY PRICING DETAILS: (cont.) h. Sheet 21 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43922-E 42862-E San Francisco, California ELECTRIC SCHEDULE E-20 SERVICE TO CUSTOMERS WITH MAXIMUM DEMANDS of 1000 KILOWATTS or MORE 17. PEAK DAY PRICING DETAILS (continued): h. Sheet 15 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5493-E 18-11-029 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, customers on a PDP rate may no longer participate in another demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43923-E 42644-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM APPLICABILITY: Sheet 1 This rate schedule is available until modified or terminated in the rate design phase of the next general rate case or in another proceeding. The E-BIP (Program) is intended to provide load reductions on PG&E’s system. Customers enrolled in the Program will be required to reduce their load down to their Firm Service Level (FSL). Pursuant to Decision 10-06-034, which placed a Megawatt (MW) cap on emergency demand response programs, the Program may at any time be subject to a cap for new participants. See the “Reliability Cap” section for details on the current process for administering the cap. (N) (N) TERRITORY: The Program is available throughout PG&E’s electric service area. ELIGIBILITY: Schedule E-BIP is available to PG&E customers receiving bundled-service, Community Choice Aggregation (CCA) service, or Direct Access (DA) service and being billed on a PG&E commercial, industrial, or agricultural electric rate schedule. Each customer, both directly enrolled and those enrolled in a DR aggregator’s portfolio, must take service under the provisions of a demand time-of-use rate schedule to participate in the Program and have at least 100 kilowatt (kW) or higher maximum demand during the summer on-peak or winter partial-peak for at least one month over the previous 12 months. Eligible customers include those receiving partial standby service or services pursuant to one or more of the Net Energy Metering Service schedules except NEMCCSF. Customers participating in Peak Day Pricing (PDP) rate option who were enrolled prior to October 26, 2018 at their subscribed megawatt level as of November 29, 2018 or Scheduled Load Reduction Program (SLRP) are eligible to participate in Schedule E-BIP. (N) I (N) Customers receiving power from third parties (other than DA and CCA) and customers billed by full standby service are not eligible for Schedule E-BIP. Customers may participate with third-party aggregators in Schedule E-BIP; however, neither those third-party aggregators nor the customers themselves may be the Demand Response Provider (DRP) of record for those customers and may not bid the associated capacity from those customers into the CAISO market. Also, customers are prohibited from participating in Schedule E-BIP if the customer is participating in another capacity-based program, even if PG&E is the DRP such as the Capacity Bidding Program. Effective January 1, 2019, Schedule E-BIP customers will not be eligible to receive demand response incentives for using a prohibited resource to reduce load during a demand response event, as provided in the Section on the Use of Prohibited Resources within this tariff. PG&E, acting as a Demand Response Provider (DRP), must be able to register customers who are participating in the Schedule E-BIP into the California Independent System Operator’s (CAISO) Demand Response Registration System (DRRS), which requires Load Serving Entity (LSE) approval. To the extent that PG&E is unable to register the customer and/or the customer’s LSE does not allow the customer to be registered, the customer will be ineligible to participate in the Schedule E-BIP. (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43924-E 42645-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM ENROLLMENT: Sheet 2 A customer may enroll directly with PG&E or with a DR aggregator subject to the reliability cap management process. A DR aggregator is an entity, appointed by a customer, to act on behalf of said customer with respect to all aspects of the Program, including but not limited to: a) the receipt of notices from PG&E under this Program; b) the receipt of incentive payments from PG&E; and c) the payment of Excess Energy Charges to PG&E. (N) (N) Each customer, both directly enrolled and those in a DR aggregator’s portfolio, must designate a FSL of kW to which it will reduce its load down to or below during a Program curtailment event. The FSL must be no more than 85 percent of each customer’s highest monthly maximum demand during the summer on–peak and winter partial-peak periods over the past 12 months with a minimum load reduction of 100kW. During the enrollment process, customers must demonstrate their ability to meet the designated FSL by participating in a curtailment test. The curtailment test will last up to the maximum event duration and will take place prior to enrollment being completed. As part of its application, each new applicant is required to submit an event action plan detailing specific actions taken to reduce its load down to or below the applicant’s proposed FSL within the 30-minute response time and for the maximum event duration. If a customer is attesting to the use of a Prohibited Resource(s) to reduce load during a demand response event under E-BIP, then the customer must set the FSL at no less than the sum of the faceplate capacity values of such Prohibited Resources, known as the Default Adjustment Value (DAV), as explained in the Section on the Use of Prohibited Resources within this tariff, if applicable An applicant’s effective start date shall be determined by PG&E and shall be set after PG&E has determined the application has met the eligibility rules, the load reduction demonstration was successful and PG&E has approved the applicant’s load reduction plan. Customers on the Program may not have, or obtain, any insurance for the purpose of paying Excess Energy Charges for willful failure to comply with requests for curtailments. Customers with such a policy will be terminated and required to pay back any incentives received for the period covered by the insurance. If the period cannot be determined, the recovery shall be for the entire period the customer was on the Program. Customers who are deemed essential under the Electric Emergency Plan as adopted in Decision 01-04-006 must acknowledge that they are voluntarily electing to participate in the Program for part or all of their load based on adequate backup generation or other means to interrupt load upon request by PG&E, while continuing to meet its essential needs. In addition, an essential customer may commit no more than 50 percent of its average peak load to the Program. Customers participating directly with PG&E must enroll using PG&E’s demand response enrollment website. DR aggregators must enroll customers by submitting a fully executed Notice to Add or Delete Customers Participating in the Base Interruptible Program (Form 79-1080). (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43925-E 42655-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM PROGRAM TRIGGERS: Sheet 12 1) The CAISO issues a market award or dispatch instruction by CAISO subLAP pursuant to CAISO Operating Procedure 4420. 2) PG&E in its sole discretion may dispatch one or more customers to address transmission or distribution reliability needs. Customers, both directly-enrolled and those in a DR aggregator’s portfolio, may increase their FSL or discontinue participation in the Program once annually by providing a 30-day written notice for the direct enrolled and Add or Delete form for the aggregator enrolled during the month of November, unless the change in the customer’s FSL is due to an update to its attestation of the Prohibited Resource(s), subject to PG&E’s approval. The adjustment of the FSL due to a change in attestation will be effective on the next regularly scheduled meter read date after PG&E approval. Cancellation will be effective January of the following year. CONTRACTS: (T) I (T) (D) (D) DR aggregators must submit a signed Agreement For Aggregators Participating in the Base Interruptible Program (Form 79-1079). RELIABILITY CAP: D. 18-11-029 established a new reliability cap management process. When the available capacity is below 50% of an individual utility’s allocated two-percent reliability cap, enrollment is based on a first-come; first-served approach. However, this process provides for an annual lottery in April when the available capacity (“headroom”) is between 50%-95% of an individual utility’s allocated two-percent reliability cap. New enrollments and decreases in the Firm-Service Level would occur after the results of the lottery are determined. When a utility utilizes the lottery, the following prioritization preference applies: 1) third-party resources from Local Capacity Areas that have deficiencies pursuant to CAISO; 2) utility resources from Local Capacity Areas that have deficiencies pursuant to CAISO, 3) all other third-party resources, and 4) all other utility resources. (N) I I I I I I I I I I I I (N) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43926-E 42656-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM AGGREGATOR’S PORTFOLIO: Sheet 13 DR aggregators must submit a Notice to Add or Delete Customers Participating in the Base Interruptible Program (Form 79-1080) signed by the aggregated customer to add or delete a customer from its portfolio. PG&E will review and approve each SA before enrollment under the aggregator’s portfolio. Each SA may be included in only one portfolio at a time. PG&E will only add a new customer to a DR aggregator’s portfolio after all necessary equipment is installed and all requirements have been met. Metering equipment (including telephone line, cellular, or radio control communication device) must be in operation for at least 45 days prior to participating in the Program. The terms and conditions of the agreement governing the relationship between the DR aggregator and a customer, with respect to such customer’s participation in the Program through such a DR aggregator, are independent of PG&E. Any disputes arising between DR aggregator and such customer shall be resolved by the parties. SPECIAL CONDITIONS FOR COMMUNITY CHOICE AGGREGATION SERVICE (CCA SERVICE) CUSTOMERS AND DIRECT ACCESS (DA) CUSTOMERS: DA/CCA Service customers enrolling directly with PG&E must make the necessary arrangements with their ESP/CCA before enrolling in this Program. INTERACTION WITH CUSTOMER’S OTHER APPLICABLE PROGRAMS AND CHARGES: Consistent with Decision 11-18-029, customers who participate in a third party sponsored interruptible load program must immediately notify PG&E of such activity. Aggregators must make the necessary arrangements with the ESP and CCA before enrolling DA or CCA Service customers in this Program. Aggregators must notify the ESP/CCA of its DA/CCA Service customers. Customers enrolled in the Program may also participate in one of the following PG&E DR programs: Scheduled Load Reduction Program (Schedule E-SLRP), or the Peak Day Pricing (PDP) rate option if dual enrollment in BIP and PDP occurred prior to October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. (T) (N) I I (N) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM Sheet 2 Cancelling U 39 43927-E 31306-E San Francisco, California RATES: A customer’s monthly electric bill will continue to be calculated in accordance with the otherwise applicable rate schedule. DEVICE OPTIONS: Customers may elect that PG&E install, free of charge, one of the following two devices at their premise, subject to availability and Program device subscription limits: 1. A/C Cycling Switch: The A/C Cycling switch will generally be installed outdoors, on or adjacent to the customer’s A/C unit. When activated by PG&E, the switch will turn off or cycle the A/C unit up for approximately 33% of the time over each subsequent 30 minute interval. This is called a “cycle.” Program events will be limited to no more than six hours each day. An A/C unit can be cycled no more than 100 hours each year. 2. Programmable Controllable Thermostat (PCT): A PCT is a thermostat that can be programmed and operated or activated remotely by a signal. When the program is called, PG&E will activate the device one of two ways: (1) the thermostat temperature will be incrementally increased up to four degrees or, (2) the device will cycle the A/C unit for approximately 33% of the time over each 30 minute interval, similar to the switch, until the event is complete. Program events will be limited to no more than six hours each day. A PCT can be activated no more than 100 hours each year. PG&E understands that there may be times that a temperature increase, however modest, may inconvenience customers. PG&E will provide its customers with a toll free telephone number and/or a dedicated website to override, without penalty, PG&E’s control of their device for a program event absent rotating block outages. DEVICE CALL OPTION: Customers on PDP may request PG&E to activate their A/C Cycling switch or PCT when the customer is participating solely in an event associated with that rate. This provision applies to customers who are eligible to be enrolled in both programs based on Special Condition 10 below. SPECIAL CONDITIONS: 1. Devices may be activated by PG&E based on system peak loading conditions, peak prices, or transmission or distribution system loading conditions. PG&E may on a limited basis conduct operational tests on a segment of customer devices. 2. Program events will occur during PG&E’s summer season, which runs from May 1 through October 31 each year. 3. Customers must remain on the Program for 12 months. 4. PG&E will furnish, install, operate, and maintain an A/C Cycling switch or PCT at no cost to the customer for as long as the customer remains on this Program. Ownership of the installed devices will vest with the property owner. As a condition of participating in this Program, customer and property owner must agree to not deface, remove or otherwise interfere with the device or its operation while the customer is enrolled in this Program. 5. PG&E will install specialized metering on a small sample of participants’ A/C units to facilitate program impact estimates. PG&E will retain ownership of the specialized meters. 6. (T) (N) I (N) Customer participation is limited to equipment and installation availability. (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM Sheet 3 Cancelling U 39 43928-E 27302-E San Francisco, California 7. Program participation must be authorized by a property owner at the premise. Renters or lease holders may participate with the owner’s written approval. 8. Customers with multiple air conditioning units at one premise must have all units controlled in order to participate in this program. 9. SPECIAL CONDITIONS: (Cont’d.) The ability to override device may not be available in the event of an extreme emergency, such as a rotating block outage. 10. Pursuant to D.18-11-029, dual enrollment as of October 26, 2018 is no longer available between PDP and SmartAC or any other demand response program provided by PG&E or another third-party demand response provider. Customers on SmartAC and PDP may continue to participate in both programs if dual enrolled prior to October 26, 2018. Participation is capped at the customer’s subscribed megawatt level as of November 29, 2018. CUSTOMER INCENTIVE: Advice Decision (N) I I I I (N) Following program enrollment and installation of an A/C Cycling switch or PCT, customers will receive a one-time financial incentive of up to $100.00, depending on fund availability and PG&E’s program marketing in effect at the time of installation. 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. ELECTRIC SCHEDULE E-RSAC RESIDENTIAL SMART A/C PROGRAM Sheet 2 Cancelling U 39 San Francisco, California SPECIAL CONDITIONS: (Cont’d.) 6. PG&E understands that operation of this program can cause a temperature increase in their home and, may inconvenience customers. PG&E will provide its customers with the ability to override, without penalty. 7. Customers on SmartRate may request PG&E to activate their A/C cycling technology when the customer is participating solely in an event associated with that rate. This provision applies to customers who are eligible to be enrolled in both programs based on Special Condition 13. 8. Program participation must be authorized by a property owner at the premise. Renters or lease holders may participate with the owner’s written approval. 9. Customers who participate will receive a one-time financial incentive of $50.00 upon successful enrollment which may include verification of A/C cycling technology at the premise. 10. As a condition of participating in this Program, customer and property owner must agree to continue to keep the A/C cycling equipment operational and must contact PG&E in the event it is not operational, removed or replaced. PG&E will, from time to time, conduct inspections of A/C cycling equipment to assess health and operational readiness and may, dependent on the current program offer, or provide upgraded technology. 11. Customers not enrolled in the SmartAC program who move into a premise (location) that already has a functioning SmartAC device may have their premise (location) auto-enrolled into the SmartAC program with the option to opt-out. 12. Customers currently enrolled in the SmartAC program who move to a new premise (location) that has a functioning SmartAC device may continue to be enrolled in the SmartAC program unless they chose to unenroll. 13. Pursuant to D.18-11-029, dual enrollment as of October 26, 2018 is no longer available between SmartRate and SmartAC or any other demand response program offered by PG&E or another third-party demand response provider. Customers on SmartRate and SmartAC may continue to participate in both programs if dual enrolled prior to October 26, 2018. Participation is capped at the customer’s subscribed megawatt level as of November 29, 2018. Advice Decision 43929-E 41741-E 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (L) I I (L) (T)/(L) (L) (N)/(L) (N)/(L) (L) I I I I I I I I I I I I I I I I I I I I I I (L) (N)/(L) I I I I (N)/(L) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43930-E 26394-E San Francisco, California ELECTRIC SCHEDULE E-RSMART RESIDENTIAL SMARTRATE PROGRAM Sheet 5 PROGRAM TERM: The SmartRate program will remain open until terminated or superceded by action of the Commission. BILLLING: Monthly bills are calculated in accordance with the customer’s OAS and the rates contained herein. The amount under the SmartRate program will appear on the customer’s bill as an additional charge or credit. BILL PROTECTION: Bill Protection: A customer will be provided with a bill protection transitional incentive through the first full Summer Season (May 1 through October 31). Under the bill protection transitional incentive, the customer will not pay more under the SmartRate program than it would pay under its OAS for the first full summer and, if applicable, any preceding partial summer, during the initial bill protection period. Bill protection benefits will be computed on a cumulative basis at the end of each Summer Season and any applicable credits will be applied to the customer’s account on the next regular bill. If the customer terminates their participation in the SmartRate program before the end of the Summer season and during the initial bill protection period, the customer will receive bill protection up to the date the customer terminates its participation in the SmartRate program. Any applicable credits will be applied to the customer’s account on the next regular bill following the end of their participation in the SmartRate program. After the customer has completed its first full Summer season, bill protection will no longer apply. The customer will be notified twice that bill protection no longer applies by the following: 60 to 90 days before the customer’s first Summer season without bill protection begins, and During the month of May of the customer’s first Summer season without bill protection. These notices will be prepared in accordance with Ordering Paragraph 6 of Decision 0607-027. INTERACTION WITH OTHER DEMAND RESPONSE PROGRAMS: Advice Decision Pursuant to Decision 18-11-029, participants in the SmartRate program may no longer dual enroll in other demand response programs offered by PG&E or a third-party demand response provider. Participants who were dual enrolled in both SmartRate and SmartAC prior to October 26, 2018 may continue to participate in both programs at their subscribed megawatt level as of November 29, 2018, but shall not receive energy payment for performance under those programs during the SmartDay High-Price Period. 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution (N) I I I (N) March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43931-E 43875-E San Francisco, California ELECTRIC TABLE OF CONTENTS Sheet 1 TABLE OF CONTENTS SCHEDULE CAL P.U.C. SHEET NO. TITLE OF SHEET Title Page ............................................................................................................................... 43931-E Rate Schedules ..............................43876,43932,43933,43879,43880,43934,41779,43935,43936-E Preliminary Statements ...................................... 43883,40534,42856*,43670,41723,40591,43686-E Rules ................................................................................................................ 43022,43023,43210-E Maps, Contracts and Deviations ............................................................................................ 37960-E Sample Forms ... 40925*,37631,41151*,41573*, 37632,41152*,41153,37769,43644,36059,37169-E (T) (T) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43932-E 43877-E San Francisco, California ELECTRIC TABLE OF CONTENTS SCHEDULE Sheet 3 CAL P.U.C. SHEET NO. TITLE OF SHEET Rate Schedules Residential (Cont’d) E-AMDS E-FERA E-RSMART EE E-EFLIC E-TOU E-TOU-C3 E-TOUPP EL-TOU EL-TOUPP EL-TOU-C3 EL-1 EL-6 EM EM-TOU EML EML-TOU ES ESL ESR ESRL ET ETL Experimental Access to Meter Data Services ................................................................... 28367-E Family Electric Rate Assistance ................................................................. 40216,42201,29288-E Residential SMARTRATE Program ...................................... 40857,40051,35350,35351,43930-E Service to Company Employees ...................................................................................... 24091-E Energy Financing Line Item Charge (EFLIC) Pilot ................ 35599,35600,35601,35602,35603-E Residential Time-of-Use Service ........................................................ 40861,43789,43790,43791, ..................................................................................................... 43413,36504,40864,43792-E Residential Time-Of-Use (Peak Pricing 4 - 9 p.m. Every Day) ..................... 42075,43793,43794, ................................................................................43414,42079,43054,43795,43056,43057-E Residential Time-of-Use Pilot Project Service .................................... 36419,43538,43539,43540, ................................................................................43540,43541,37426,36661,36662,36663-E Residential CARE Program Time-of-Use Service .............................. 36507,43802,43803,43804, ..................................................................................................... 43418,36512,40873,43805-E Residential CARE Program Time-of-Use Pilot Project Service .......... 36428,43552,43553,43554, ................................................................................43555,43556,37427,36670,36671,36672-E Residential CARE Program Time-Of-Use (Peak Pricing 4 - 9 p.m. Every Day) ....... 42084,43806, ..................................................................... 43807,43419,42088,43058,43808,43060,42092-E Residential CARE Program Service ..................................... 43796,43797,43416,40867,43798-E Residential CARE Time-of-Use Service .......... 36614,43799,43800,43417,36519,40869,43801-E Master-Metered Multifamily Service ...........................43809,43810,43421,20648,43811,28723-E Residential Time of Use Service ................................35229,43812,43813,43422,40879,43814-E Master-Metered Multifamily CARE Program Service ............ 43815,43816,43423,43817,28768-E Residential CARE Program Time of Use ....................28217,43818,43819,43424,40884,43820-E Multifamily Service......................................................43821,43822,43425,28207,43823,28727-E Multifamily CARE Program Service ............................43824,43825,43426,40891,43826,28773-E Residential RV Park and Residential Marina Service ..................................................................... ................................................................................... 43827,43828,43427,20657,43829,28731-E Residential RV Park and Residential Marina CARE Program Service ........................................... ................................................................................43830,43831,43428,40897,43832,28778-E Mobilehome Park Service................................ 43833,43834,43429,28208,43835,35231,28736-E Mobilehome Park CARE Program Service ......................................... 43836,43837,43430,28216, ................................................................................................................ 43838,35232,28783-E (T) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43933-E 43878-E San Francisco, California ELECTRIC TABLE OF CONTENTS TITLE OF SHEET SCHEDULE Sheet 4 CAL P.U.C. SHEET NO. Rate Schedules Commercial/Industrial A-1 A-6 A-10 A-15 E-19 E-20 E-31 E-37 E-CARE E-CSAC E-PWF E-REMAT E-SRG EDR EITE Small General Service ............................................................. 43286,41408,43718,43719,43720, ......................................................................... 31249,40834,43721,31252,43153,31254,43916-E Small General Time-of-Use Service ........................................ 36652,43290,43730,43731,25981*, ...............................................................................................43732,35784,43159,43160,43918-E Medium General Demand-Metered Service ........................... 35410,43287,43722,43723,43724, ...................................... 43725,29081,29082,40836,43726,29085,29086,43156,43157,43917-E Direct-Current General Service ........................................................ 43727,43728,31442,43729-E Medium General Demand-Metered Time-of-Use Service ....... 29090,43295,43296,43758,43759, ....................................... 43760,43761,43762,43763,35054,35055,37144,35057,35058,35059, ............................................... 43764,35392,35062,43169,40726,43921,42860,43675,43676-E Service to Customers with Maximum Demands of 1,000 Kilowatts or More ............ 43299,42861, .............................................................43765,43766,43767,43768,35069,35070,37145,35072, .......................................................... 43769,35393,43171,40730,43922,42863,43677,43678-E Distribution Bypass Deferral Rate ...............................................................20620,24899,20622-E Medium General Demand-Metered Time-of-Use Service to Oil and Gas Extraction Customers 35787,41420,31288,43770,43771,31291,31292,31293,40850,43772-E CARE Program Service for Qualified Nonprofit Group-Living and Qualified Agricultural Employee Housing Facilities ............................................................................................ 43776-E Commercial Smart A/C Program ................................................................32823,43927,43928-E Section 399.20 PPA ...................................................................................32735, 30264,30759-E Renewable Market Adjusting Tariff (ReMAT) .......................... 32736,32737,32738,32739,32740, ..................................................................... 32741,32742,32743,32744,32745,32746,32747-E Small Renewable Generator PPA ...............................................................32748,30266,30760-E Economic Development Rate .......................... 43025,43026,43027,43028,43029,43030,43031-E Emissions-Intensive and Trade-Exposed Customer Greenhouse Gas Allowance Revenue Provisions ....................................................................................35091,35092,35093-E (T) (T) (T) (T) (T) (T) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43934-E 43881-E San Francisco, California ELECTRIC TABLE OF CONTENTS SCHEDULE Sheet 7 CAL P.U.C. SHEET NO. TITLE OF SHEET Rate Schedules Other NEMVMASH NEM2VMSH E-ERA RES-BCT E-OBF E-OBR E-SOP PEVSP PEVSP 2 Net Energy Metering – Virtual Net Energy Metering ........................ 31625,33922*,42064,33923, .................................................................................. 33924,33925,31630,36567,31632,31633, ..................................................................... 36568,31635,42065,31637,33217,31639,42066-E Virtual Net Energy Metering For Multifamily Affordable Housing (MASH/NSHP) With Solar Generator(s) ...............37847,37848,42051,37850,37851,37852,37853,37854,37855, .................................... 37856,37857,37858,37859,37860,42052,37862,37863,42053,42054-E Energy Rate Adjustments.................................................................43779,43780,43781,43782-E Schedule for Local Government Renewable Energy Self-Generation Bill Credit Transfer......................................... 37782,37783,37784,37785,37786, ....................................................................................... 37787,37788,37789,37790-37791-E E On-Bill Financing Balance Account (OBFBA) .............................................40227,40228,40229-E On-Bill Repayment (OBR) Pilots .................... 34527,34528,34529,34530,34531,34532, 34533-E Residential Electric SmartMeterTM Opt-Out Program ............................................ 35105,40860-E Plug-In Electric Vehicle Submetering Pilot – Phase 1 ........... 36571,35261,34249,35262,35263-E Plug-In Electric Vehicle Submetering Pilot – Phase 2 ......................... 37688,37689,37690,37691 .................................................................... 37692,37693,37694,37695,37696,37697, 37698-E Rate Schedules Agricultural AG-1 AG-R AG-V AG-4 AG-5 AG-ICE Agricultural Power ................................ 34541,43733,43734,24221,24222,24223,43735,25425-E Split-Week Time-of-Use Agricultural Power ................................ 35785,43166,43293,43749, ................................................................................... 43750,31267,31268,31269,43751,31271-E Short-Peak Time-of-Use Agricultural Power ....................................... 35786,43167,31273,43752, ........................................................... 43753,31276,31277,31278,31279,31280,43754,31282-E Time-of-Use Agricultural Power .................................. 25909,35411,43162,43736 ,41827,43737, ................................................................................... 43738,43739,30992,30993,30994,30995, ................................................................................. 30996,43740,30998,43163,31000,43919-E (T) Large Time-of-Use Agricultural Power ......................... 25911,35412,43164,43741,43742,43743, ........................................................................ 43744,43745,31007,31008,31009,31010,31011, ..................................................................... 43746,43673, 43674,43165,31016,35345,43920-E (T) Agricultural Internal Combustion Engine Conversion Incentive Rate – Expiration Transition Rate ........ 36458,36459,43747,38144,43748,36463,36464,36465-E (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43935-E 43322-E San Francisco, California ELECTRIC TABLE OF CONTENTS SCHEDULE Sheet 9 CAL P.U.C. SHEET NO. TITLE OF SHEET Rate Schedules Curtailment Options E-BIP E-OBMC E-SLRP E-CBP Base Interruptible Program ............................. 43923,43924,42646**,42647,42648,42649 ............................................... 42650,42651,42652,42653,42654,43925,43926,42657-E Optional Binding Mandatory Curtailment Plan ................................... 37149,29520,28623, .......................................................................................... 29521,18431,23001,29522-E Scheduled Load Reduction Program .........................28624,27285,27286,26287,29523-E Capacity Bidding Program ................................ 42658,42147,42148,42149,42150,42659, ............ 23269, 42152,42153,42154,43320,42156,42660*,42661,42662,42663,42664-E (T) (T) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 43936-E 43882-E San Francisco, California ELECTRIC TABLE OF CONTENTS TITLE OF SHEET SCHEDULE Sheet 10 CAL P.U.C. SHEET NO. Rate Schedules Energy Charge Rate E-FFS E-RSAC Franchise Fee Surcharge................................................................. 43783,43784,43785,43786-E Residential Smart A/C Program .................................................................. 41739,43929,41741-E (T) (Continued) Advice Decision 5493-E 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution March 11, 2019
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Advice 5493-E March 11, 2019 Attachment 2 Redline Tariffs
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE A-1 SMALL GENERAL SERVICE PEAK DAY PRICING DETAILS (CONT’D): 40711-E 35339-E Sheet 12 g. Program Options: Customers may customize their PDP participation by choosing either a) no limit on the number of consecutive PDP events or b) every other PDP event. Customers electing every other PDP event will be divided into two groups and only be subject to a maximum of one-half of the PDP events called and the corresponding PDP rate credits will be reduced by 50%. Customers that do not elect an option will be defaulted to the no limit on the number of consecutive PDP events. The duration of PDP Event Operations for both options will be from 2:00 p.m. to 6:00 p.m. (four-hour window). h. Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted on PG&E’s PDP Website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during its initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5106-E 15-08-005 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, cCustomers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. as established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) I I (N) June 28, 2017 July 1, 2017
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. San Francisco, California ELECTRIC SCHEDULE A-10 MEDIUM GENERAL DEMAND-METERED SERVICE PEAK DAY PRICING DETAILS (continued) 40714-E 35343-E h. Sheet 15 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5106-E 15-08-005 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer availableas established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) I I (N) June 28, 2017 July 1, 2017
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 40717-E 35341-E San Francisco, California ELECTRIC SCHEDULE A-6 SMALL GENERAL TIME-OF-USE SERVICE PEAK DAY PRICING DETAILS (continued) h. Sheet 10 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down by 2°F over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5106-E 15-08-005 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11-029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. as established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) I I I (N) June 28, 2017 July 1, 2017
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 40720-E 35344-E San Francisco, California ELECTRIC SCHEDULE AG-4 TIME-OF-USE AGRICULTURAL POWER 16. PEAK DAY PRICING DETAILS (CONT’D): Sheet 18 g. Program Options: Customers may customize their PDP participation by choosing either a) no limit on the number of consecutive PDP events or b) every other PDP event. Customers electing every other PDP event will be divided into two groups and only be subject to a maximum of one-half of the PDP events called and the corresponding PDP rate credits will be reduced by 50%. Customers that do not elect an option will be defaulted to the no limit on the number of consecutive PDP events. The duration of PDP Event Operations for both options will be from 2:00 p.m. to 6:00 p.m. (four-hour window). h. Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5106-E 15-08-005 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer availableas established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) I I (N) June 28, 2017 July 1, 2017
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 40723-E 31018-E San Francisco, California ELECTRIC SCHEDULE AG-5 LARGE TIME-OF-USE AGRICULTURAL POWER 17. PEAK DAY PRICING DETAILS (CONT’D): i. Sheet 20 Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5106-E 15-08-005 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available as established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) I I (N) June 28, 2017 July 1, 2017
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42859-E 40727-E San Francisco, California ELECTRIC SCHEDULE E-19 MEDIUM GENERAL DEMAND-METERED TOU SERVICE 19. PEAK DAY PRICING DETAILS: (cont.) h. Sheet 21 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website or on PG&E’s PDP website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. as established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. (L) I I I I I I I I I I I I I I I I I (L) Advice Decision 5352-E 14-12-080 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution August 8, 2018 September 7, 2018
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42862-E 40731-E San Francisco, California ELECTRIC SCHEDULE E-20 SERVICE TO CUSTOMERS WITH MAXIMUM DEMANDS of 1000 KILOWATTS or MORE 17. PEAK DAY PRICING DETAILS (continued): h. Sheet 15 Event Trigger: PG&E will trigger a PDP event when the day-ahead temperature forecast trigger is reached. The trigger will be the average of the day-ahead maximum temperature forecasts for San Jose, Concord, Red Bluff, Sacramento and Fresno. Beginning May 1 of each summer season, the PDP events on non-holiday weekdays will be triggered at 98 degrees Fahrenheit (°F), and will be triggered at 105°F on holidays and weekends. If needed, PG&E will adjust the non-holiday weekday trigger up or down over the course of the summer to achieve the range of 9 to 15 PDP events in any calendar year. Such adjustments would be made no more than twice per month and would be posted to the demand response operations website. PDP events may also be initiated as warranted on a day-ahead basis by 1) extreme system conditions such as special alerts issued by the California Independent System Operator, 2) under conditions of high forecasted California spot market power prices, 3) to meet annual PDP event limits for a calendar year, or 4) for testing/evaluation purposes. i. Program Terms: A customer may opt-out anytime during their initial 12 months on a PDP rate. After the initial 12 months, customer’s participation will be in accordance with Electric Rule 12. Customers may opt-out of a PDP rate at anytime to enroll in another demand response program beginning May 1, 2011. j. Advice Decision 5352-E 14-12-080 Interaction with Other PG&E Demand Response Programs: Pursuant to D.18-11029, Customers on a PDP rate may no longer participate in another day-of dispatchable demand response program offered by PG&E or a third-party demand response provider as of October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available.as established in D.09-08-027. If a NEM customer is on PDP, the customer cannot participate in a third party Demand Response program unless it ceases to be a PDP customer. If a third party signs a NEM customer up under Rule 24 at the CAISO, the customer is automatically removed from PDP. Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution August 8, 2018 September 7, 2018
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42644-E 40233-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM APPLICABILITY: Sheet 1 This rate schedule is available until modified or terminated in the rate design phase of the next general rate case or in another proceeding. The E-BIP (Program) is intended to provide load reductions on PG&E’s system. Customers enrolled in the Program will be required to reduce their load down to their Firm Service Level (FSL). Pursuant to Decision 10-06-034, which placed a Megawatt (MW) cap on emergency demand response programs, the Program may at any time be subject to a cap for new participants. See the “Reliability Cap” section for details on the current process for administering the cap. TERRITORY: The Program is available throughout PG&E’s electric service area. ELIGIBILITY: Schedule E-BIP is available to PG&E customers receiving bundled-service, Community Choice Aggregation (CCA) service, or Direct Access (DA) service and being billed on a PG&E commercial, industrial, or agricultural electric rate schedule. Each customer, both directly enrolled and those enrolled in a DR aggregator’s portfolio, must take service under the provisions of a demand time-of-use rate schedule to participate in the Program and have at least 100 kilowatt (kW) or higher maximum demand during the summer on-peak or winter partial-peak for at least one month over the previous 12 months. Eligible customers include those receiving partial standby service or services pursuant to one or more of the Net Energy Metering Service schedules except NEMCCSF. Customers participating in Peak Day Pricing (PDP) rate option who were enrolled prior to October 26, 2018 at their subscribed megawatt level as of November 29, 2018 or Scheduled Load Reduction Program (SLRP) are eligible to participate in Schedule E-BIP. Customers receiving power from third parties (other than DA and CCA) and customers billed by full standby service are not eligible for Schedule E-BIP. Customers may participate with third-party aggregators in Schedule E-BIP; however, neither those third-party aggregators nor the customers themselves may be the Demand Response Provider (DRP) of record for those customers and may not bid the associated capacity from those customers into the CAISO market. Also, customers are prohibited from participating in Schedule E-BIP if the customer is participating in another capacity-based program, even if PG&E is the DRP such as the Capacity Bidding Program. Effective January 1, 2019, Schedule E-BIP customers will not be eligible to receive demand response incentives for using a prohibited resource to reduce load during a demand response event, as provided in the Section on the Use of Prohibited Resources within this tariff. (N) I I (N) PG&E, acting as a Demand Response Provider (DRP), must be able to register customers who are participating in the Schedule E-BIP into the California Independent System Operator’s (CAISO) Demand Response Registration System (DRRS), which requires Load Serving Entity (LSE) approval. To the extent that PG&E is unable to register the customer and/or the customer’s LSE does not allow the customer to be registered, the customer will be ineligible to participate in the Schedule E-BIP. (L) I I (L) (Continued) Advice Decision 4991-E-C 16-09-056 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution July 23, 2018 July 23, 2018
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42645-E 37948-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM ENROLLMENT: Sheet 2 A customer may enroll directly with PG&E or with a DR aggregator subject to the reliability cap management process. A DR aggregator is an entity, appointed by a customer, to act on behalf of said customer with respect to all aspects of the Program, including but not limited to: a) the receipt of notices from PG&E under this Program; b) the receipt of incentive payments from PG&E; and c) the payment of Excess Energy Charges to PG&E. (L) I I I I (L) Each customer, both directly enrolled and those in a DR aggregator’s portfolio, must designate a FSL of kW to which it will reduce its load down to or below during a Program curtailment event. The FSL must be no more than 85 percent of each customer’s highest monthly maximum demand during the summer on–peak and winter partial-peak periods over the past 12 months with a minimum load reduction of 100kW. During the enrollment process, customers must demonstrate their ability to meet the designated FSL by participating in a curtailment test. The curtailment test will last up to the maximum event duration and will take place prior to enrollment being completed. As part of its application, each new applicant is required to submit an event action plan detailing specific actions taken to reduce its load down to or below the applicant’s proposed FSL within the 30-minute response time and for the maximum event duration. If a customer is attesting to the use of a Prohibited Resource(s) to reduce load during a demand response event under E-BIP, then the customer must set the FSL at no less than the sum of the faceplate capacity values of such Prohibited Resources, known as the Default Adjustment Value (DAV), as explained in the Section on the Use of Prohibited Resources within this tariff, if applicable (N) I I I (N) An applicant’s effective start date shall be determined by PG&E and shall be set after PG&E has determined the application has met the eligibility rules, the load reduction demonstration was successful and PG&E has approved the applicant’s load reduction plan. Customers on the Program may not have, or obtain, any insurance for the purpose of paying Excess Energy Charges for willful failure to comply with requests for curtailments. Customers with such a policy will be terminated and required to pay back any incentives received for the period covered by the insurance. If the period cannot be determined, the recovery shall be for the entire period the customer was on the Program. Customers who are deemed essential under the Electric Emergency Plan as adopted in Decision 01-04-006 must acknowledge that they are voluntarily electing to participate in the Program for part or all of their load based on adequate backup generation or other means to interrupt load upon request by PG&E, while continuing to meet its essential needs. In addition, an essential customer may commit no more than 50 percent of its average peak load to the Program. Customers participating directly with PG&E must enroll using PG&E’s demand response enrollment website. DR aggregators must enroll customers by submitting a fully executed Notice to Add or Delete Customers Participating in the Base Interruptible Program (Form 79-1080). (L) (Continued) Advice Decision 4991-E-C 16-09-056 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution July 23, 2018 July 23, 2018
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42655-E 37953-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM PROGRAM TRIGGERS: Sheet 12 1) The CAISO issues a market award or dispatch instruction by CAISO subLAP pursuant to CAISO Operating Procedure 4420. 2) PG&E in its sole discretion may dispatch one or more customers to address transmission or distribution reliability needs. CONTRACTS: Customers, both directly-enrolled and those in a DR aggregator’s portfolio, may increasere-designate theirincrease their FSL or discontinue participation in the Program once annually by providing a 30-day written notice for the direct enrolled and Add or Delete form for the aggregator enrolled during the month of November, unless the change in the customer’s FSL is due to an update to its attestation of the Prohibited Resource(s), subject to PG&E’s approval. The adjustment of the FSL due to a change in attestation will be effective on the next regularly scheduled meter read date after PG&E approval. Cancellation will be effective January of the following year. Customers may de-enroll prior to the end of the first year if they do so to participate in the 2016 Demand Response Auction Mechanism Pilot, as directed by the California Public Utilities Commission in Resolution E-4728. DR aggregators must submit a signed Agreement For Aggregators Participating in the Base Interruptible Program (Form 79-1079). RELIABILITY CAP: (L) I I I I I I (L) (L) I (L) (N) I (N) (L) I I I I I (L) D. 18-11-029 established a new reliability cap management process. When the available capacity is below 50% of an individual utility’s allocated two-percent reliability cap, enrollment is based on a first-come; first-served approach. However, this process provides for an annual lottery in April when the available capacity (“headroom”) is between 50%-95% of an individual utility’s allocated two-percent reliability cap. New enrollments and decreases in the Firm-Service Level would occur after the results of the lottery are determined. When a utility utilizes the lottery, the following prioritization preference applies: 1) third-party resources from Local Capacity Areas that have deficiencies pursuant to CAISO; 2) utility resources from Local Capacity Areas that have deficiencies pursuant to CAISO, 3) all other third-party resources, and 4) all other utility resources. (Continued) Advice Decision 4991-E-C 16-09-056 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution July 23, 2018 July 23, 2018
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 42656-E 37954-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM AGGREGATOR’S PORTFOLIO: Sheet 13 DR aggregators must submit a Notice to Add or Delete Customers Participating in the Base Interruptible Program (Form 79-1080) signed by the aggregated customer to add or delete a customer from its portfolio. PG&E will review and approve each SA before enrollment under the aggregator’s portfolio. Each SA may be included in only one portfolio at a time. PG&E will only add a new customer to a DR aggregator’s portfolio after all necessary equipment is installed and all requirements have been met. Metering equipment (including telephone line, cellular, or radio control communication device) must be in operation for at least 45 days prior to participating in the Program. The terms and conditions of the agreement governing the relationship between the DR aggregator and a customer, with respect to such customer’s participation in the Program through such a DR aggregator, are independent of PG&E. Any disputes arising between DR aggregator and such customer shall be resolved by the parties. SPECIAL CONDITIONS FOR COMMUNITY CHOICE AGGREGATION SERVICE (CCA SERVICE) CUSTOMERS AND DIRECT ACCESS (DA) CUSTOMERS: DA/CCA Service customers enrolling directly with PG&E must make the necessary arrangements with their ESP/CCA before enrolling in this Program. INTERACTION WITH CUSTOMER’S OTHER APPLICABLE PROGRAMS AND CHARGES: Consistent with Decision 11-18-029, Customers who participate in a third party sponsored interruptible load program must immediately notify PG&E of such activity. Aggregators must make the necessary arrangements with the ESP and CCA before enrolling DA or CCA Service customers in this Program. Aggregators must notify the ESP/CCA of its DA/CCA Service customers. Customers enrolled in the Program may also participate in one of the following PG&E DR programs: Scheduled Load Reduction Program (Schedule E-SLRP), or the Peak Day Pricing (PDP) rate option if dual enrollment in BIP and PDP occurred prior to October 26, 2018. If dual enrolled in BIP and PDP prior to October 26, 2018 then participation will be capped at the customer’s subscribed megawatt level as of November 29, 2018. New dual enrollment in BIP and PDP as of October 26, 2018 is no longer available. (L) I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I (L) (Continued) Advice Decision 4991-E-C 16-09-056 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution July 23, 2018 July 23, 2018
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Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM Sheet 2 Cancelling U 39 31306-E 30094-E San Francisco, California RATES: A customer’s monthly electric bill will continue to be calculated in accordance with the otherwise applicable rate schedule. DEVICE OPTIONS: Customers may elect that PG&E install, free of charge, one of the following two devices at their premise, subject to availability and Program device subscription limits: 1. A/C Cycling Switch: The A/C Cycling switch will generally be installed outdoors, on or adjacent to the customer’s A/C unit. When activated by PG&E, the switch will turn off or cycle the A/C unit up for approximately 33% of the time over each subsequent 30 minute interval. This is called a “cycle.” Program events will be limited to no more than six hours each day. An A/C unit can be cycled no more than 100 hours each year. 2. Programmable Controllable Thermostat (PCT): A PCT is a thermostat that can be programmed and operated or activated remotely by a signal. When the program is called, PG&E will activate the device one of two ways: (1) the thermostat temperature will be incrementally increased up to four degrees or, (2) the device will cycle the A/C unit for approximately 33% of the time over each 30 minute interval, similar to the switch, until the event is complete. Program events will be limited to no more than six hours each day. A PCT can be activated no more than 100 hours each year. PG&E understands that there may be times that a temperature increase, however modest, may inconvenience customers. PG&E will provide its customers with a toll free telephone number and/or a dedicated website to override, without penalty, PG&E’s control of their device for a program event absent rotating block outages. DEVICE CALL OPTION: Customers on PDPtime-varying rates may request PG&E to activate their A/C Cycling switch or PCT when the customer is participating solely in an event associated with that rate. This provision applies to customers who are eligible to be enrolled in both programs based on Special Condition 10 below. SPECIAL CONDITIONS: 1. Devices may be activated by PG&E based on system peak loading conditions, peak prices, or transmission or distribution system loading conditions. PG&E may on a limited basis conduct operational tests on a segment of customer devices. 2. Customers must remain on the Program for 12 months. 4. PG&E will furnish, install, operate, and maintain an A/C Cycling switch or PCT at no cost to the customer for as long as the customer remains on this Program. Ownership of the installed devices will vest with the property owner. As a condition of participating in this Program, customer and property owner must agree to not deface, remove or otherwise interfere with the device or its operation while the customer is enrolled in this Program. 5. PG&E will install specialized metering on a small sample of participants’ A/C units to facilitate program impact estimates. PG&E will retain ownership of the specialized meters. 6. (T) Program events will occur during PG&E’s summer season, which runs from May 1 through October 31 each year. 3. (T) (T) Customer participation is limited to equipment and installation availability. (Continued) Advice Decision 4001-E 11-01-036 Issued by Brian K. Cherry Vice President Regulation and Rates Date Filed Effective Resolution February 1, 2012 March 2, 2012
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Original U 39 Cal. P.U.C. Sheet No. 27302-E San Francisco, California ELECTRIC SCHEDULE E-CSAC COMMERCIAL SMART A/C PROGRAM SPECIAL CONDITIONS: (Cont’d.) Sheet 3 7. Program participation must be authorized by a property owner at the premise. Renters or lease holders may participate with the owner’s written approval. 8. Customers with multiple air conditioning units at one premise must have all units controlled in order to participate in this program. 9. The ability to override device may not be available in the event of an extreme emergency, such as a rotating block outage. (L) | | | | | | (L) 10. Pursuant to D.18-11-029, dual enrollment as of October 26, 2018 is no longer available between PDP and SmartAC or any other demand response program provided by PG&E or another third-party demand response provider. Customers on SmartAC and PDP may continue to participate in both programs if dual enrolled prior to October 26, 2018. Participation will beis capped at theirthe customer’s subscribed megawatt level as of November 29, 2018. CUSTOMER INCENTIVE: Advice Decision Following program enrollment and installation of an A/C Cycling switch or PCT, customers will receive a one-time financial incentive of up to $100.00, depending on fund availability and PG&E’s program marketing in effect at the time of installation. 3214-E-A 08-02-009 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution (N) | (N) March 19, 2008 March 1, 2008
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Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. ELECTRIC SCHEDULE E-RSAC RESIDENTIAL SMART A/C PROGRAM Sheet 2 Cancelling U 39 41740-E 35621-E San Francisco, California SPECIAL CONDITIONS: (Cont’d.) 6. PG&E understands that operation of this program can cause a temperature increase in their home and, may inconvenience customers. PG&E will provide its customers with the ability to override, without penalty. 7. Customers on SmartRate time varying rates may request PG&E to activate their A/C cycling technology when the customer is participating solely in an event associated with that rate. This provision applies to customers who are eligible to be enrolled in both programs based on Special Condition 13. 8. Program participation must be authorized by a property owner at the premise. Renters or lease holders may participate with the owner’s written approval. 9. Customers who participate will receive a one-time financial incentive of $50.00 upon successful enrollment which may include verification of A/C cycling technology at the premise. 10. As a condition of participating in this Program, customer and property owner must agree to continue to keep the A/C cycling equipment operational and must contact PG&E in the event it is not operational, removed or replaced. PG&E will, from time to time, conduct inspections of A/C cycling equipment to assess health and operational readiness and may, dependent on the current program offer, or provide upgraded technology. 11. Customers not enrolled in the SmartAC program who move into a premise (location) that already has a functioning SmartAC device may have their premise (location) auto-enrolled into the SmartAC program with the option to opt-out. 12. Customers currently enrolled in the SmartAC program who move to a new premise (location) that has a functioning SmartAC device may continue to be enrolled in the SmartAC program unless they chose to unenroll. 13. (N) I I I I I I I I I I I I I I I I I I I I I I I I I I I I (N) Pursuant to D.18-11-029, dual enrollment as of October 26, 2018 is no longer available between SmartRate and SmartAC or any other demand response program offered by PG&E or another third-party demand response provider. Customers on SmartRate and SmartAC may continue to participate in both programs if dual enrolled prior to October 26, 2018. Participation will be is capped at thei customer’sr subscribed megawatt level as of November 29, 2018. (D) I I I I I I I I I I I I (Continued) Advice Decision 5217-E 17-12-003 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution January 22, 2018 May 1, 2018
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Cancelling U 39 Revised Original Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 26394-E 26106-E San Francisco, California ELECTRIC SCHEDULE E-RSMART RESIDENTIAL SMARTRATE PROGRAM Sheet 5 PROGRAM TERM: The SmartRate program will remain open until terminated or superceded by action of the Commission. BILLLING: Monthly bills are calculated in accordance with the customer’s OAS and the rates contained herein. The amount under the SmartRate program will appear on the customer’s bill as an additional charge or credit. BILL PROTECTION: Bill Protection: A customer will be provided with a bill protection transitional incentive through the first full Summer Season (May 1 through October 31). Under the bill protection transitional incentive, the customer will not pay more under the SmartRate program than it would pay under its OAS for the first full summer and, if applicable, any preceding partial summer, during the initial bill protection period. Bill protection benefits will be computed on a cumulative basis at the end of each Summer Season and any applicable credits will be applied to the customer’s account on the next regular bill. If the customer terminates their participation in the SmartRate program before the end of the Summer season and during the initial bill protection period, the customer will receive bill protection up to the date the customer terminates its participation in the SmartRate program. Any applicable credits will be applied to the customer’s account on the next regular bill following the end of their participation in the SmartRate program. After the customer has completed its first full Summer season, bill protection will no longer apply. The customer will be notified twice that bill protection no longer applies by the following: 60 to 90 days before the customer’s first Summer season without bill protection begins, and During the month of May of the customer’s first Summer season without bill protection. These notices will be prepared in accordance with Ordering Paragraph 6 of Decision 0607-027. INTERACTION WITH OTHER DEMAND RESPONSEDUCT ION PROGRAMS: Advice Decision Pursuant to Decision. 18-11-029, Pparticipants in the SmartRate program may no longer also dual enrollparticipate in other applicable demand responseduction programs offered by PG&E or a third-party demand response provider. as of October 26, 2018., Participants who were dual enrolled in both SmartRate and SmartAC prior to October 26, 2018 may continue to participate in both programs at their subscribed megawatt level as of November 29, 2018, in both the SmartRate and the demand response program,,at their current subscribed megawatt level. as of November 29, 2018, but shall not receive energy payment for performance under those programs during the SmartDay High-Price Period. 3058-E 06-07-027 Issued by Robert S. Kenney Vice President, Regulatory Affairs Date Filed Effective Resolution May 31, 2007 May 1, 2008
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PG&E Gas and Electric Advice Filing List General Order 96-B, Section IV AT&T Albion Power Company Alcantar & Kahl LLP Alta Power Group, LLC Anderson & Poole Atlas ReFuel BART Barkovich & Yap, Inc. P.C. CalCom Solar 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 City of Palo Alto City of San Jose Clean Power Research Coast Economic Consulting Commercial Energy County of Tehama - Department of Public Works Crossborder Energy Crown Road Energy, LLC Davis Wright Tremaine LLP Day Carter Murphy Dept of General Services Don Pickett & Associates, Inc. Douglass & Liddell Downey & Brand East Bay Community Energy Ellison Schneider & Harris LLP Energy Management Service Evaluation + Strategy for Social Innovation GenOn Energy, Inc. Goodin, MacBride, Squeri, Schlotz & Ritchie Green Charge Networks Green Power Institute Hanna & Morton ICF International Power Technology Intestate Gas Services, Inc. Kelly Group Ken Bohn Consulting Keyes & Fox LLP Leviton Manufacturing Co., Inc. Linde Los Angeles County Integrated Waste Management Task Force Los Angeles Dept of Water & Power MRW & Associates Manatt Phelps Phillips Marin Energy Authority McKenzie & Associates Modesto Irrigation District Morgan Stanley NLine Energy, Inc. NRG Solar Office of Ratepayer Advocates OnGrid Solar Pacific Gas and Electric Company Pioneer Community Energy Praxair 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 Utility Specialists Verizon Water and Energy Consulting Wellhead Electric Company Western Manufactured Housing Communities Association (WMA) Yep Energy
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