Details for: PGE Substitute Sheets for AL 5702-E.pdf


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Pacific Gas and Electric Company
77 Beale St., Mail Code B13U
P.O. Box 770000
San Francisco, CA 94177
Fax: 415.973.3582

January 24, 2020
California Public Utilities Commission
Energy Division
ED Tariff Unit
505 Van Ness Avenue, 4th Floor
San Francisco, CA 94102
Re:

Substitute Sheets for Advice 5702-E

Dear Energy Division Tariff Unit:
An original and 1 copy of substitute sheets are attached for Advice 5702-E,
“Update to the Base Incentive Program (BIP) Tariff to Reflect New TOU rates,
Clarification of Performance Calculation for a Power Safety Power Shut-off
Event, and Other Miscellaneous Updates.,” submitted on December 2, 2019.
In PG&E’s Advice Letter 5702-E, PG&E inadvertently used the word “partial”
peak instead of “on-peak” in its tariff update for the redline version that was
included in the filing. 1 Specifically, PG&E is requesting that the following
sentence on Sheet 2 of the BIP tariff be updated as shown below. 2
For customers on new C&I and Agricultural TOU rates, 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 on–peak periods over the past 12 months with a minimum load reduction of 100kW.

In accordance with GO 96-B, Section 7.5.1, this substitute sheet is being served
in the same manner as the original advice letter. For administrative convenience,
a new Sheet 2 (redline version) of the BIP tariff is attached. Please discard the
previously submitted Sheet 2 (redline version).
Please call me at (415) 973-4587 should you have any questions regarding the
substitute sheets.
_/S/ Kimberly Loo

Kimberly Loo
Regulatory Relations
The clean version of the CBP tariff on Sheet 2 correctly presented the information. It
was only the redline version that contained the incorrect word.
2
Strike-through indicates removal of word; bold indicates addition of word.
1





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Attachment cc: Garima Vashistha, CPUC Service Lists A. 17-01-012, R.13-09-011
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 44494-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. For customers on legacy C&I and Agricultural TOU rates, Tthe 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. For customers on new C&I and Agricultural TOU rates, 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 on–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 (Continued) Advice Decision 5493-E-A 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution June 19, 2019 March 11, 2019
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Cancelling U 39 Revised Revised Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No. 44494-E 42645-E San Francisco, California ELECTRIC SCHEDULE E-BIP BASE INTERRUPTIBLE PROGRAM Sheet 2 the Base Interruptible Program (Form 79-1080). (Continued) Advice Decision 5493-E-A 18-11-029 Issued by Robert S. Kenney Vice President, Regulatory Affairs Submitted Effective Resolution June 19, 2019 March 11, 2019
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