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Gary A. Stern, Ph.D.
Managing Director, State Regulatory Operations

September 10, 2019
ADVICE 4072-E
(U 338-E)
PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA
ENERGY DIVISION
SUBJECT:

Implementation of Decision 19-08-022, Modifying Power
Charge Indifference Adjustment Rates for Pre-2009 Vintage
Departing Load Customers on October 1, 2019

Southern California Edison Company (SCE) hereby submits for approval by the
California Public Utilities Commission (Commission) the following changes to its tariffs
and proposed monthly report template. The revised tariffs are listed on Attachment A,
and are attached hereto.
PURPOSE
Decision (D.)19-08-022 adopts a two-step implementation process and schedule: Step
1, which is the subject of this Advice Letter, is to cease billing the Power Charge
Indifference Adjustment (PCIA) to pre-2009 vintage departing load (DL) customers for
the above-market costs of Legacy Utility-Owned Generation (UOG) resources on
October 1, 2019. Step 2, which will be the subject of a separate Tier 2 Advice Letter to
be submitted in mid-October, is to refund the pre-2009 vintage DL customers for PCIA
charges over-collected since January 1, 2017, the retroactive effective date of the
Settlement Agreement approved in D.19-08-022 (Settlement).1
The purpose of this advice letter is to modify the PCIA rates paid by pre-2009 vintage
DL customers so that they no longer include the above-market costs of Legacy UOG
(which are the only generation resource costs currently in those customers’ PCIA rates).
SCE clarifies that, consistent with the Settlement, the PCIA rates listed in Attachment A
continue to reflect the pass-through of certain one-time net refunds, as described below.
BACKGROUND
1

Parties to the Settlement, referred to hereinafter collectively as the Settling Parties, include:
Alliance for Retail Energy Markets/Direct Access Customer Coalition (AReM/DACC),
California Large Energy Consumers Association (CLECA), Public Agency Coalition (PAC),
and SCE.

P.O. Box 800

8631 Rush Street

Rosemead, California 91770

(626) 302-9645

Fax (626) 302-6396





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ADVICE 4072-E (U 338-E) -2- September 10, 2019 Included below is a summary of the PCIA rate changes since January 1, 2017, layered on top of the procedural history of Application (A.)16-05-001. This summary is intended to provide context to what is in current PCIA rates for pre-2009 vintage DL customers and identify what sub-components should be removed on October 1, 2019. 2017 ERRA Forecast Phase 1 SCE filed A.16-05-001, its 2017 Energy Resource Recovery Account (ERRA) Forecast Application on May 2, 2016. Among other things, SCE proposed a PCIA for pre-2009 vintage DL customers that included (1) San Onofre Nuclear Generating Station (SONGS)-related UOG costs; (2) the above-market costs of all non-SONGS Legacy UOG; and (3) various one-time Energy Crisis-related refunds and costs pursuant to D.15-10-037. The Commission issued D.16-12-054 authorizing SCE to implement its proposed 2017 PCIA rates for pre-2009 vintage DL customers on January 1, 2017 on an interim basis, subject to refund, and establishing a consolidated second phase of the proceeding to resolve the pre-2009 vintage PCIA issue (2017 ERRA Phase 2) for all three Investor-Owned Utilities (IOUs) in a consistent manner. 2018 ERRA Forecast Prior to submitting its November Update testimony in A.17-05-006, SCE reached an informal resolution of the PCIA for pre-2009 vintage DL customers issue with DACC/AReM and PAC. Accordingly, SCE proposed in its November Update to (1) exclude the above-market costs of all non-SONGS Legacy UOG from the 2018 PCIA for pre-2009 vintage DL customers (i.e., but continue to include SONGS-related UOG costs and one-time refunds and costs); and (2) provide pre-2009 vintage DL customers with a refund to effectuate a January 1, 2017 retroactive implementation date. Despite acknowledging that SCE’s proposal for pre-2009 vintage DL customers was “likely reasonable,” D.17-12-018 directed SCE and parties to file its proposed resolution as a settlement agreement in the 2017 ERRA Phase 2, and to implement a “status quo” 2018 PCIA for pre-2009 vintage DL customers that included the above-market costs of non-SONGS Legacy UOG on an interim basis, subject to refund.2 2017 ERRA Forecast Phase 2 Settlement Agreement On February 1, 2018, SCE, on behalf of the Settling Parties, filed a Motion for Approval of the Settlement that fully resolved the pre-2009 vintage PCIA rates issue for SCE. The Settlement specified that, retroactive to January 1, 2017, the PCIA for pre-2009 vintage DL customers should consist of only SONGS-related net legacy UOG costs and Energy Crisis litigation-related refunds and costs, and that the resulting PCIA revenues over-collected since January 1, 2017 should be refunded to those customers with interest. 2 See D.17-12-018 at pp. 21-22.
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ADVICE 4072-E (U 338-E) -3- September 10, 2019 2018 Final SONGS Settlement On August 2, 2018, the Commission issued D.18-07-037 approving a separate settlement that addressed how to deal with legacy SONGS-related costs (Final SONGS Settlement).3 The Final SONGS Settlement provides that SONGS-related costs should stop being collected from customers as of December 20, 2017 and requires that SONGS-related costs collected after that date be refunded to customers by October 1, 2018. SCE implemented the Final SONGS Settlement on August 27, 2018 by removing all SONGS-related costs from rates (including PCIA rates for pre-2009 vintage DL customers), and refunding over-collected SONGS amounts to customers between August 27, 2018 and October 1, 2018. That process is now complete. Accordingly, customers (including the pre-2009 vintage DL customers) no longer owe any SONGSrelated costs, nor are they owed any SONGS-related refunds. 2019 ERRA Forecast On March 4, 2019, the Commission issued D.19-02-024 approving SCE’s 2019 ERRA Forecast Application, including 2019 PCIA rates for pre-2009 vintage DL customers that included the above-market costs of Legacy UOG (i.e., status quo, pending Commission approval of the Settlement Agreement in the 2017 ERRA Phase 2), and requiring a partial “true-up” of PCIA amounts paid by 2017 DL vintage and earlier customers in 2018 (Brown Power True-Up). The Brown Power True-Up, which was implemented in Advice 3972-E, is intended to true-up 2018 PCIA rates for eligible customers to reflect the fact that actual energy and ancillary services revenues earned by SCE’s PCIAeligible resources in 2018 were higher than the forecast revenues used to set rates (i.e., the actual 2018 above-market costs were lower than the forecast 2018 above-market costs collected from DL customers). As such, the 2019 PCIA rates for pre-2009 vintage DL customers implemented on June 1, 2019 through Advice 3972-E include: (1) the above-market costs of non-SONGS Legacy UOG; (2) one-time Energy Crisis-related refunds and costs; and (3) a Brown Power True-up credit for the 2018 over-collection related to Legacy UOG.4 2017 ERRA Forecast Phase 2 Final Decision Approving Settlement Agreement On August 16, 2019, the Commission issued D.19-08-022 approving the Settlement in its entirety. Additionally, D.19-08-022 adopted the Settling Parties’ proposed two-step implementation process: Step 1, which is the subject of this Advice Letter, is to cease 3 4 See January 30, 2018 Joint Motion for Adoption of Settlement Agreement in Investigation (I.)12-10-013. Parties to the Final SONGS Settlement include: the Alliance for Nuclear Responsibility, CLECA, California State University, Citizens Oversight doing business as (dba) Coalition to Decommission San Onofre, the Coalition of California Utility Employees, the Direct Access Customer Coalition, Ruth Henricks, the Office of Ratepayer Advocates, San Diego Gas & Electric Company, SCE, The Utility Reform Network, and Women’s Energy Matters. As described on page 7 of Advice 3972-E, the Brown Power True-up credit also refunds overcollection related to the Competition Transition Charge (CTC)-eligible resources.
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ADVICE 4072-E (U 338-E) -4- September 10, 2019 billing the PCIA to pre-2009 vintage DL customers for the above-market costs of Legacy UOG on October 1, 2019 (as discussed above, SONGS costs are no longer relevant). Step 2, which will be the subject of a separate Tier 2 Advice Letter to be filed in midOctober, is to refund the pre-2009 vintage DL customers for amounts over-collected since January 1, 2017. PROPOSED TARIFF CHANGES Pursuant to D.19-08-022, SCE proposes to modify the currently-effective PCIA rates5 paid by pre-2009 vintage DL customers so that they no longer recover the abovemarket costs of Legacy UOG. Additionally, SCE proposes to modify the “Brown Power True-Up Credit” reflected in the PCIA rates paid by pre-2009 vintage DL customers so that it no longer includes a TrueUp credit for Legacy UOG. As described above, the Brown Power True-Up Credit provides a partial refund for PCIA paid by eligible customers in 2018. Because pursuant to the Settlement pre-2009 DL customers were not obligated to pay for Legacy UOG in 2018, the entire 2018 PCIA amount associated with those resources will be refunded in Step 2 of the D.19-08-022 implementation process. It would not be appropriate to additionally refund the 2018 Brown Power True Up Credit associated with those resources to those customers, as that would result in a “double refund.” Accordingly, SCE proposes to cease including the Brown Power True-Up Credit for Legacy UOG in pre-2009 vintage DL customers’ rates on October 1, 2019.6 Attachment B includes SCE’s full set of “Standard PCIA Workpapers.” Modifications to the Standard PCIA Workpapers, which are limited to the final rate calculation-related workpapers, have been annotated in red and are described below. • • 5 6 The first three pages of SCE’s Standard PCIA Workpapers, which show the derivation of the above-market costs of SCE’s vintaged PCIA-eligible portfolio, remain unchanged from those approved in D.19-02-020 and modified in Advice 4012-E to incorporate SCE’s 2018 GRC authorized generation-related revenue requirement. These pages are not impacted by D.19-08-022. The fourth page of SCE’s Standard PCIA Workpapers is the “Indifference Rate Calculation.” The first two tables on this page, which show the calculation of the “Incremental Rate” for each portfolio of resources, remain unchanged. The last The currently-effective PCIA rates are the 2019 ERRA Forecast PCIA rates approved in D.19-02-024, as modified in Advice 4012-E and implemented in Advice 4043-E to incorporate changes pursuant to D.19-05-020, the Decision approving SCE’s 2018 General Rate Case (GRC). As will be described in further detail in SCE’s “Step 2” advice letter, pre-2009 vintage DL customers will be fully refunded for all Legacy UOG-related PCIA payments made in 2018. As such, any Legacy UOG-related 2018 Brown Power True-Up refunds that have been issued-to-date will be similarly reversed.
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ADVICE 4072-E (U 338-E) • • • -5- September 10, 2019 table, which shows the calculation of the cumulative rate for which each vintage of customers is responsible, has been modified to reflect the fact the 2001 and 2004 vintage (i.e., pre-2009 vintage) DL customers are no longer responsible for the Legacy UOG Incremental Rate. The fifth page of SCE’s Standard PCIA Workpapers is the “Final Cost Responsibility Surcharge (CRS) Rates” table, prior to specific 2019 surcharges or refunds (Base PCIA Rates, prior to surcharges/refunds). This table simply reflects changes made to the Indifference Rate Calculation page. The sixth page of Attachment B is the rate calculation of SCE’s 2018 Brown Power True-Up, which was originally provided in Advice 3972-E pursuant to D.19-02-024. 7 Like the Indifference Rate Calculation page, the first two tables, which show the “incremental” Brown Power True-Up rate calculation for each portfolio of resources, remain unchanged. The last table, which shows the calculation of the cumulative Brown Power True-Up rate for which each vintage of customers is responsible, has been modified to reflect the fact the 2001 and 2004 vintage DL customers are no longer eligible for the Legacy UOG Brown Power True-Up rate. The seventh page of Attachment B is the final rates summary page. This page reflects the final Base PCIA Rates and final 2018 Brown Power True-Up Rates, as modified above, and shows the calculation of the true final PCIA rates. No other rates (i.e., PCIA rates for the post-2009 vintage DL customers and bundled service customer generation rates) are being modified in this Advice Letter. Additionally, SCE provides in Attachment C the October 1, 2019 Billed Revenues Percentage Allocation Table, which reflects the modifications to the PCIA rates paid by pre-2009 DL customers discussed in this Advice Letter. The percentage allocation factors for all other groups of customers (i.e., post-2009 vintage DL customers and bundled service customers) remain unchanged from those provided in Advice 4043-E. TIER DESIGNATION Pursuant to General Rule 5.1 of General Order (GO) 96-B, this advice letter is submitted with a Tier 1 designation. EFFECTIVE DATE Pursuant to page 14 of D.19-08-022, this advice letter is effective October 1, 2019. 7 The Brown Power True-Up rate calculation sheet is not a part of SCE’s Standard PCIA Workpapers.
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ADVICE 4072-E (U 338-E) -6- September 10, 2019 NOTICE Anyone wishing to protest this advice letter may do so by letter via U.S. Mail, facsimile, or electronically, any of which must be received no later than 20 days after the date of this advice letter. Protests should be submitted to: CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California 94102 E-mail: EDTariffUnit@cpuc.ca.gov Copies should also be mailed to the attention of the Director, Energy Division, Room 4004 (same address above). In addition, protests and all other correspondence regarding this advice letter should also be sent by letter and transmitted via facsimile or electronically to the attention of: Gary A. Stern, Ph.D. Managing Director, State Regulatory Operations Southern California Edison Company 8631 Rush Street Rosemead, California 91770 Telephone (626) 302-9645 Facsimile: (626) 302-6396 E-mail: AdviceTariffManager@sce.com Laura Genao Managing Director, State Regulatory Affairs c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2030 San Francisco, California 94102 Facsimile: (415) 929-5544 E-mail: Karyn.Gansecki@sce.com There are no restrictions on who may submit a protest, but the protest shall set forth specifically the grounds upon which it is based and must be received by the deadline shown above. In accordance with General Rule 4 of GO 96-B, SCE is serving copies of this advice letter to the interested parties shown on the attached GO 96-B and R.18-10-007 service lists. Address change requests to the GO 96-B service list should be directed by electronic mail to AdviceTariffManager@sce.com or at (626) 302-4039. For changes to all other service lists, please contact the Commission’s Process Office at (415) 703-2021 or by electronic mail at Process_Office@cpuc.ca.gov.
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ADVICE 4072-E (U 338-E) -7- September 10, 2019 Further, in accordance with Public Utilities Code Section 491, notice to the public is hereby given by submitting and keeping the advice letter at SCE’s corporate headquarters. To view other SCE advice letters submitted with the Commission, log on to SCE’s web site at https://www.sce.com/wps/portal/home/regulatory/advice-letters. For questions, please contact Desiree Wong at (626) 302-1421 or by electronic mail at desiree.wong@sce.com. Southern California Edison Company /s/ Gary A. Stern, Ph.D. Gary A. Stern, Ph.D. GAS:dw:cm Enclosures
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ADVICE LETTER SUMMARY ENERGY UTILITY MUST BE COMPLETED BY UTILITY (Attach additional pages as needed) Company name/CPUC Utility No.: Southern California Edison Company (U 338-E) Utility type: ELC GAS PLC HEAT ELC = Electric PLC = Pipeline WATER Contact Person: Darrah Morgan Phone #: (626) 302-2086 E-mail: AdviceTariffManager@sce.com E-mail Disposition Notice to: AdviceTariffManager@sce.com EXPLANATION OF UTILITY TYPE GAS = Gas WATER = Water HEAT = Heat (Date Submitted / Received Stamp by CPUC) Tier Designation: 1 Advice Letter (AL) #: 4072-E Subject of AL: Implementation of Decision 19-08-022, Modifying Power Charge Indifference Adjustment Rates for Pre-2009 Vintage Departing Load Customers on October 1, 2019 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 #: Decision 19-08-022 Does AL replace a withdrawn or rejected AL? If so, identify the prior AL: Summarize differences between the AL and the prior withdrawn or rejected AL: Confidential treatment requested? Yes No If yes, specification of confidential information: Confidential information will be made available to appropriate parties who execute a nondisclosure agreement. Name and contact information to request nondisclosure agreement/ access to confidential information: Resolution required? Yes No Requested effective date: 10/1/19 No. of tariff sheets: -14- Estimated system annual revenue effect (%): Estimated system average rate effect (%): 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: See Attachment A Service affected and changes proposed1: Pending advice letters that revise the same tariff sheets: None 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: Gary A. Stern, Ph.D. Title: Managing Director, State Regulatory Operations Utility Name: Southern California Edison Company Address: 8631 Rush Street City: Rosemead Zip: 91770 State: California Telephone (xxx) xxx-xxxx: (626) 302-9645 Facsimile (xxx) xxx-xxxx: (626) 302-6396 Email: advicetariffmanager@sce.com Name: Laura Genao c/o Karyn Gansecki Title: Managing Director, State Regulatory Affairs Utility Name: Southern California Edison Company Address: 601 Van Ness Avenue, Suite 2030 City: San Francisco State: California Zip: 94102 Telephone (xxx) xxx-xxxx: (415) 929-5515 Facsimile (xxx) xxx-xxxx: (415) 929-5544 Email: karyn.gansecki@sce.com Clear Form
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ENERGY Advice Letter Keywords Affiliate Direct Access Preliminary Statement Agreements Disconnect Service Procurement Agriculture ECAC / Energy Cost Adjustment Qualifying Facility Avoided Cost EOR / Enhanced Oil Recovery Rebates Balancing Account Energy Charge Refunds Baseline Energy Efficiency Reliability Bilingual Establish Service Re-MAT/Bio-MAT Billings Expand Service Area Revenue Allocation Bioenergy Forms Rule 21 Brokerage Fees Franchise Fee / User Tax Rules CARE G.O. 131-D Section 851 CPUC Reimbursement Fee GRC / General Rate Case Self Generation Capacity Hazardous Waste Service Area Map Cogeneration Increase Rates Service Outage Compliance Interruptible Service Solar Conditions of Service Interutility Transportation Standby Service Connection LIEE / Low-Income Energy Efficiency Storage Conservation LIRA / Low-Income Ratepayer Assistance Street Lights Consolidate Tariffs Late Payment Charge Surcharges Contracts Line Extensions Tariffs Core Memorandum Account Taxes Credit Metered Energy Efficiency Text Changes Curtailable Service Metering Transformer Customer Charge Customer Owned Generation Mobile Home Parks Name Change Transition Cost Transmission Lines Decrease Rates Non-Core Transportation Electrification Demand Charge Non-firm Service Contracts Transportation Rates Demand Side Fund Nuclear Undergrounding Demand Side Management Oil Pipelines Voltage Discount Demand Side Response PBR / Performance Based Ratemaking Wind Power Deposits Portfolio Withdrawal of Service Depreciation Power Lines Clear Form
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Public Utilities Commission 4072-E Cal. P.U.C. Sheet No. Title of Sheet Attachment A Cancelling Cal. P.U.C. Sheet No. Revised 68002-E Revised 68003-E Schedules CCA-CRS Schedules CCA-CRS Revised 67426-E Revised 67787-E Revised 68004-E Revised 68005-E Schedules CGDL-CRS Schedules CGDL-CRS Revised 57286-E Revised 67791-E Revised 68006-E Revised 68007-E Schedules DA-CRS Schedules DA-CRS Revised 67437-E Revised 67792-E Revised 68008-E Revised 68009-E Schedules NMDL Schedules NMDL Revised 64407-E Revised 67807-E Revised 68010-E Revised 68011-E Schedules TMDL Schedules TMDL Revised 64420-E Revised 67813-E Revised 68012-E Revised 68013-E Revised 68014-E Revised 68015-E Table of Contents Table of Contents Table of Contents Table of Contents Revised 67990-E Revised 67991-E Revised 67975-E Revised 67976-E 1
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule CCA-CRS COMMUNITY CHOICE AGGREGATION COST RESPONSIBILITY SURCHARGE (Continued) 68002-E 67426-E Sheet 2 RATES Composition of Rate: This rate is composed of the following components: 1. DWRBC is the Department of Water Resources Bond Charge to recover the interest and principal of DWR bonds. 2. CTC is the Ongoing Competition Transition Charge, which recovers the CPUC-approved market price limit for legacy electricity contracts (signed prior to 1998), as well as statutorilyauthorized costs that are related to restructuring of California’s electric industry prior to the energy crisis. 3. Power Charge Indifference Adjustment (PCIA): Either a charge or credit, designed to maintain bundled customer indifference associated with other customers departing bundled utility service. The PCIA is determined residually by subtracting the authorized CTC revenue component of the CRS revenues from the Indifference Amount developed in accordance with Decision (D.) 06-07-030, and D.11-12-018, as modified by D. 18-10-019. The Indifference Amount reflects the extent to which the average cost of the SCE total generation portfolio, differs from a Market Price Benchmark developed by the Commission. The Indifference Amount is negative when the departure of a customer for DA service results in lower resource costs for the remaining bundled service customers. Pursuant to D.19-08-022, beginning (N) October 1, 2019 and retroactive to January 1, 2017, the 2001 and 2004 PCIA Vintage factors | in the following rate tables will no longer include the above-market costs of legacy Utility (N) Owned Generation (UOG). With the exception of the CTC and DWRBC, all charges, terms, and conditions of the customer’s Otherwise Applicable Tariff (OAT), or contract rate shall apply. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 2D8 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule CCA-CRS COMMUNITY CHOICE AGGREGATION COST RESPONSIBILITY SURCHARGE (Continued) 68003-E 67787-E Sheet 5 RATES (Continued) Rate Group Domestic1 GS-12 TC-13 GS-24 TOU-GS-35 TOU-8-Sec6 TOU-8-Pri6 TOU-8-Sub6 Small AG7 Large AG8 St. Lighting9 Standby - Sec10 Standby - Pri10 Standby - Sub10 PCIA 2001 Vintage (0.00211) (I) (0.00165) (I) (0.00151) (I) (0.00167) (I) (0.00159) (I) (0.00156) (I) (0.00153) (I) (0.00144) (I) (0.00157) (I) (0.00151) (I) (0.00143) (I) (0.00149) (I) (0.00151) (I) (0.00143) (I) PCIA 2004 Vintage (0.00211) (I) (0.00165) (I) (0.00151) (I) (0.00167) (I) (0.00159) (I) (0.00156) (I) (0.00153) (I) (0.00144) (I) (0.00157) (I) (0.00151) (I) (0.00143) (I) (0.00149) (I) (0.00151) (I) (0.00143) (I) PCIA 2009 Vintage 0.00792 0.00611 0.00559 0.00622 0.00590 0.00575 0.00561 0.00528 0.00576 0.00557 0.00527 0.00550 0.00559 0.00523 1 Includes Schedules D, D-SDP, D-SDP-O, D-CARE, DE, D-FERA, DM, DMS-1, DMS-2, DMS-3, TOUD, TOU-D-T, TOU-D-PRIME, TOU-Default 1 (4-9 pm), TOU-Default 2 (5-8 pm), and TOU-EV-1. 2 Includes Schedules GS-1, TOU-GS-1, and TOU-GS-1-RTP, AL-2 (On-Peak), and LS-3 Option B (OnPeak), TOU-EV-7. 3 Includes Schedules TC-1, Wi-Fi-1, and WTR. 4 Includes Schedules GS-2, TOU-EV-8, TOU-GS-2, and TOU-GS-2-RTP. 5 Includes Schedules TOU-GS-3, TOU-GS-3-RTP 6 Includes Schedules TOU-EV-9, TOU-8, TOU-8-RBU, and TOU-8-RTP. 7 Includes Schedules PA-1, PA-2, TOU-PA-2, TOU-PA-2-RTP 8. Includes Schedules TOU-PA-3, TOU-PA-3-RTP 9. Includes Schedules AL-2-(Off-Peak), DWL, LS-1, LS-2, LS-3, LS-3 Option B (Off-Peak), and OL-1. 10. Includes Schedules TOU-8-RTP-S, and TOU-8-S. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 5D12 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. 68004-E 57286-E Sheet 3 Schedule CGDL-CRS CUSTOMER GENERATION DEPARTING LOAD COST RESPONSIBILITY SURCHARGE (Continued) RATES (Continued) CRS Components and Calculation: DWR Bond Charge: The DWR Bond Charge is calculated by multiplying the kWh for the billing period served by CG by the DWR Bond Charge as shown in the RATES section for the Otherwise Applicable Tariff (OAT). Departing Load (DL) that began to receive service from CG on or before February 1, 2001, shall be exempt from the DWR Bond Charge except for any period the DL returned to Bundled Service, Direct Access, or CCA Service. See Special Condition 4 for CG load exemption for a Continuous DA Customer. Competition Transition Charge (CTC): The CTC is calculated by multiplying the kWh for the billing period by the average rate for the CTC as shown in the Rate Components table below. Power Charge Indifference Adjustment (PCIA): The PCIA reflects the departing customers’ share of stranded generation costs as determined pursuant to the methodology adopted in D.06-07-030, as modified by D.11-12-018. The PCIA is determined residually by subtracting the authorized CTC component of CGDL-CRS from the indifference rate developed in accordance with the DA CRS Working Group report. Pursuant to D.08-09-012 and Resolution E-4226, the PCIA applicable to non-exempt CGDL customers does not include the new generation non-bypassable charges authorized by D.0412-048 and implemented as a component of the CRS. Pursuant to D.08-09-012, new generation includes generation from both fossil fueled and renewable resources contracted for or constructed by the investor owned utilities subsequent to January 1, 2003. Pursuant to D.19-08-022, beginning October 1, 2019 and retroactive to January 1, 2017, the 2001 PCIA Vintage factors in the following rate tables will no longer include the above-market costs of legacy Utility Owned Generation (UOG). (N) | (N) (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 3D5 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. 68005-E 67791-E Sheet 4 Schedule CGDL-CRS CUSTOMER GENERATION DEPARTING LOAD COST RESPONSIBILITY SURCHARGE (Continued) RATES (Continued) 2001 Vintage ($/kWh) DWRBC CTC 0.00503 0.00055 Rate Group Domestic [1] PCIA (0.00211) (I) Total 0.00347 (I) GS-1 [2] 0.00503 0.00042 (0.00165) (I) 0.00380 (I) TC-1 [3] 0.00503 0.00039 (0.00151) (I) 0.00391 (I) GS-2 [4] 0.00503 0.00043 (0.00167) (I) 0.00379 (I) TOU-GS-3 [5] 0.00503 0.00041 (0.00159) (I) 0.00385 (I) TOU-8-Sec [6] 0.00503 0.00040 (0.00156) (I) 0.00387 (I) TOU-8-Pri [6] 0.00503 0.00039 (0.00153) (I) 0.00389 (I) TOU-8-Sub [6] 0.00503 0.00037 (0.00144) (I) 0.00396 (I) TOU-8-Standby-Sec [7] 0.00503 0.00038 (0.00149) (I) 0.00392 (I) TOU-8-Standby-Pri [7] 0.00503 0.00039 (0.00151) (I) 0.00391 (I) TOU-8-Standby-Sub [7] 0.00503 0.00036 (0.00143) (I) 0.00396 (I) PA-1 [8] 0.00503 0.00040 (0.00157) (I) 0.00386 (I) PA-2 [9] 0.00503 0.00040 (0.00157) (I) 0.00386 (I) TOU-PA-2 [10] 0.00503 0.00040 (0.00157) (I) 0.00386 (I) TOU-PA-3 [11] 0.00503 0.00039 (0.00151) (I) 0.00391 (I) St. Lighting [12] 0.00503 0.00036 (0.00143) (I) 0.00396 (I) 1 Includes Schedules D, D-APS, D-APS-E, D-CARE, DE, D-FERA, DM, DMS-1, DMS-2, DMS-3, DS, TOU-D, TOU-D-1, TOU-D-2, TOU-D-T, TOU-D-TEV, and TOU-EV-1. 2 Includes Schedules GS-1, GS-APS-E, TOU-EV-3, TOU-GS-1, and TOU-GS-1-RTP. 3 Includes Schedules TC-1 and WTR. 4 Includes Schedules GS-2, GS-APS-E, TOU-EV-4, TOU-GS-2, and TOU-GS-2-RTP. 5 Includes Schedules TOU-GS-3, TOU-GS-3-RTP, and TOU-GS-3-SOP 6 Includes Schedules TOU-8, TOU-8-RBU, and TOU-8-RTP. 7 Includes Schedules PA-1, PA-RTP, TOU-PA, TOU-PA-2, TOU-PA-2-RTP, TOU-PA-ICE, and TOU-PA-SOP. 8. Includes Schedules PA-2, TOU-PA-3, TOU-PA-3-RTP, and TOU-PA-5. 9. Includes Schedules AL-2, DWL, LS-1, LS-2, LS-3, and OL-1. 10. Includes Schedule TOU-8-RTP-S, and TOU-8-S (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 4D11 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule DA-CRS DIRECT ACCESS COST RESPONSIBILITY SURCHARGE 68006-E 67437-E Sheet 2 (Continued) RATES Composition of Rate: This rate is composed of the following components: 1. DWRBC is the Department of Water Resources Bond Charge to recover the interest and principal of DWR bonds. 2. CTC is the Ongoing Competition Transition Charge, which recovers the CPUC-approved market price limit for legacy electricity contracts (signed prior to 1998), as well as statutorilyauthorized costs that are related to restructuring of California’s electric industry prior to the energy crisis. 3. Power Charge Indifference Adjustment (PCIA): Either a charge or credit, designed to maintain bundled customer indifference associated with other customers departing bundled utility service. The PCIA is determined residually by subtracting the authorized CTC revenue component of the CRS revenues from the Indifference Amount developed in accordance with Decision (D.) 06-07-030, and D.11-12-018, as modified by D. 18-10-019. The Indifference Amount reflects the extent to which the average cost of the SCE total generation portfolio, differs from a Market Price Benchmark developed by the Commission. The Indifference Amount is negative when the departure of a customer for DA service results in lower resource costs for the remaining bundled service customers. Pursuant to D.19-08-022, beginning October 1, 2019 and retroactive to January 1, 2017, the 2001 PCIA Vintage factors in the following rate tables will no longer include the above-market costs of legacy Utility Owned Generation (UOG). With the exception of the CTC and DWRBC, all charges, terms, and conditions of the customer’s Otherwise Applicable Tariff (OAT), or contract rate shall apply. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 2D7 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution (N) | | (N)
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule DA-CRS DIRECT ACCESS COST RESPONSIBILITY SURCHARGE 68007-E 67792-E Sheet 5 (Continued) RATES (Continued) PCIA 2001 Vintage Rate Group Domestic 1 PCIA 2004 Vintage PCIA 2009 Vintage (0.00211) (I) (0.00211) (I) 0.00792 2 (0.00165) (I) (0.00165) (I) 0.00611 3 (0.00151) (I) (0.00151) (I) 0.00559 (0.00167) (I) (0.00167) (I) 0.00622 (0.00159) (I) (0.00159) (I) 0.00590 (0.00156) (I) (0.00156) (I) 0.00575 (0.00153) (I) (0.00153) (I) 0.00561 (0.00144) (I) (0.00144) (I) 0.00528 (0.00157) (I) (0.00157) (I) 0.00576 (0.00151) (I) (0.00151) (I) 0.00557 (0.00143) (I) (0.00143) (I) 0.00527 (0.00149) (I) (0.00149) (I) 0.00550 (0.00151) (I) (0.00151) (I) 0.00559 (0.00143) (I) (0.00143) (I) 0.00523 GS-1 TC-1 GS-2 4 5 TOU-GS-3 6 TOU-8-Sec TOU-8-Pri 6 6 TOU-8-Sub 7 Small AG Large AG 8 9 St. Lighting Standby - Sec Standby - Pri 10 10 10 Standby - Sub 1 Includes Schedules D, D-SDP, D-SDP-O, D-CARE, DE, D-FERA, DM, DMS-1, DMS-2, DMS-3, TOUD, TOU-D-T, TOU-D-PRIME, TOU-Default 1 (4-9 pm), TOU-Default 2 (5-8 pm), and TOU-EV-1. 2 Includes Schedules GS-1, TOU-GS-1, and TOU-GS-1-RTP, AL-2 (On-Peak), and LS-3 Option B (OnPeak), TOU-EV-7. 3 Includes Schedules TC-1, Wi-Fi-1, and WTR. 4 Includes Schedules GS-2, TOU-EV-8, TOU-GS-2, and TOU-GS-2-RTP. 5 Includes Schedules TOU-GS-3, TOU-GS-3-RTP 6 Includes Schedules TOU-EV-9, TOU-8, TOU-8-RBU, and TOU-8-RTP. 7 Includes Schedules PA-1, PA-2, TOU-PA-2, TOU-PA-2-RTP 8. Includes Schedules TOU-PA-3, TOU-PA-3-RTP 9. Includes Schedules AL-2-(Off-Peak), DWL, LS-1, LS-2, LS-3, LS-3 Option B (Off-Peak), and OL-1. 10. Includes Schedules TOU-8-RTP-S, and TOU-8-S. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 5D11 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Schedule NMDL NEW MUNICIPAL DEPARTING LOAD Cal. PUC Sheet No. Cal. PUC Sheet No. 68008-E 64407-E Sheet 1 APPLICABILITY This Schedule is applicable to consumers as defined in Special Condition 1.c. that have New Municipal Departing Load (NMDL) as defined in Special Condition 1.a. below and in Preliminary Statement Part W.1.a, but who take service from a Tribal Utility as defined in Special Condition 1.e. or a local publicly owned electric utility as defined in Special Condition 1.b (each a POU). TERRITORY Applicable to SCE’s service territory as it existed on February 01, 2001. RATES Except for the exemptions(s) listed in Special Condition Section 2 of this Schedule, NMDL consumers are responsible for both Departing Load (DL) Nonbypassable Charges (NBC) and the Cost Responsibility Surcharge (CRS) components listed below. NMDL consumers are responsible for the following DL NBC components: (1) Nuclear Decommissioning Charge (NDC), (2) Public Purpose Programs Charge (PPPC), and (3) the ongoing Competition Transition Charge (CTC). The DL NBC is applicable to NMDL consumers that are located in SCE’s service territory (as that territory existed on or after December 20, 1995). The DL NBC will be billed as described below. 1. The NDC bill component is calculated by multiplying the kWh for the billing period by the applicable NDC. 2. The PPPC bill component, if applicable, is calculated by multiplying the kWh for the billing period by the applicable PPPC. 3. The CTC bill component is calculated by multiplying the kWh for the billing period by the applicable CTC. NMDL consumers are responsible for the following CRS Components: (1) DWR Bond Charge, and (2) DWR Power Charge. On July 1, 2006, the Power Charge Indifference Adjustment (PCIA) superseded and replaced the DWRPC such that after July 1, 2006, applicable consumers no longer incur additional DWR Power Charges but instead incur PCIA charges. 1. The DWR Bond Charge bill component is calculated by multiplying the kWh for the billing period by the applicable DWR Bond Charge. 2. The DWR Power Charge or the PCIA bill component, as appropriate, is calculated by multiplying the kWh for the billing period by the applicable PCIA charge. Pursuant to D.19-08-022, beginning October 1, 2019 and retroactive to January 1, 2017, the 2001 PCIA Vintage factors in the following MDL CRS rate table will no longer include the above-market costs of legacy Utility Owned Generation (UOG). (N) | (N) (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 1D5 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule NMDL NEW MUNICIPAL DEPARTING LOAD 68009-E 67807-E Sheet 6 (Continued) RATES (Continued) The following chart displays the current CTC and PCIA components by rate group. MDL CRS ($/kWh)* MDL CRS 2001 Vintage ($/kWh) CTC 0.00055 Rate Group Domestic [1] PCIA (0.00211) (I) GS-1 [2] 0.00042 (0.00165) (I) TC-1 [3] 0.00039 (0.00151) (I) GS-2 [4] 0.00043 (0.00167) (I) TOU-GS-3 [5] 0.00041 (0.00159) (I) TOU-8-Sec [6] 0.00040 (0.00156) (I) TOU-8-Pri [6] 0.00039 (0.00153) (I) TOU-8-Sub [6] 0.00037 (0.00144) (I) TOU-8-Standby-Sec [7] 0.00036 (0.00143) (I) TOU-8-Standby-Pri [7] 0.00040 (0.00157) (I) TOU-8-Standby-Sub [7] 0.00036 (0.00143) (I) PA-1 [8] 0.00040 (0.00157) (I) PA-2 [9] 0.00040 (0.00157) (I) TOU-PA-2 [10] 0.00040 (0.00157) (I) TOU-PA-3 [11] 0.00039 (0.00151) (I) St. Lighting [12] 0.00036 (0.00143) (I) 1 Includes Schedules D, D-SDP, D-CARE, DE, D-FERA, DM, DMS-1, DMS-2, DMS-3, TOU-D, TOU-D-T, and TOU-EV-1. 2 Includes Schedules GS-1, AL-2 (On-Peak), TOU-EV-7, TOU-GS-1, TOU-GS-1-D-RTP. 3 Includes Schedules TC-1, Wi-Fi-1, and WTR. 4 Includes Schedules GS-2, TOU-EV-8, TOU-GS-2, and TOU-GS-2-D-RTP. 5 Includes Schedules TOU-GS-3, and TOU-GS-3-D-RTP. 6 Includes Schedules TOU-EV-9, TOU-8, TOU-8-RBU, and TOU-8-D-RTP. 7 Includes Schedules TOU-8-Standby and TOU-8-D-Standby-RTP. 8 Includes Schedule PA-1 9] Includes Schedule PA-2 10 Includes Schedules TOU-PA-2 and TOU-PA-2-D-RTP. 11 Includes Schedules TOU-PA-3, and TOU-PA-3-D-RTP, . 12 Includes Schedules AL-2 (Off-Peak), AL-2-F, DWL, LS-1, LS-2, LS-3, and OL-1. * The consumer will not be billed a negative PCIA if the sum of the CTC and PCIA charges results in a negative value. If the total indifference rate (i.e. the sum of the CTC and PCIA) is less than zero, the negative indifference amount will be used to offset future positive indifference amounts after September 1, 2006. The resulting CRS will not produce a net payment or credit to the NMDL consumer. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 6D11 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule TMDL TRANSFERRED MUNICIPAL DEPARTING LOAD 68010-E 64420-E Sheet 1 APPLICABILITY This Schedule is applicable to customers that have Transferred Municipal Departing Load (TMDL) as defined in Special Condition 1.a. below and in Preliminary Statement Part W.1.a., and who will have all or a portion of their load served by a Tribal Utility as defined in Special Condition 1.d. or a local publicly-owned electric utility as defined in Special Condition 1.b (each a POU). This Schedule is also applicable to “New Party” customers who assume responsibility for TMDL as defined in Special Condition 1.c. TERRITORY Applicable to SCE’s service territory as it existed on February 01, 2001. RATES Except for the exemption(s) listed in Special Condition 2 of this Schedule, TMDL customers are responsible for both the Departing Load (DL) Nonbypassable Charges (NBC) and the Cost Responsibility Surcharges (CRS) listed below. DL NBC and CRS are also the responsibility of any new person or entity (party) occupying a premises having TMDL. The load of a New Party in a change of TMDL customer situation is not new load but existing load. The rate components for Department of Water Resources Bond Charge (DWRBC), Nuclear Decommissioning Charge (NDC), Public Purpose Programs Charge (PPPC), are set forth in the RATES section for the TMDL customer’s Otherwise Applicable Tariff (OAT). The rate components for ongoing Competition Transition Charge (CTC) and Power Charge Indifference Adjustment (PCIA) are set forth herein. On July 1, 2006, the PCIA superseded and replaced the DWR Power Charge (DWRPC) such that after July 1, 2006, applicable customers no longer incur additional DWR Power Charges but instead incur PCIA charges. Pursuant to D.19-08-022, beginning October 1, 2019 and retroactive to January 1, 2017, the 2001 PCIA Vintage factors in the following TMDL CRS rate table will no longer include the above-market costs of legacy Utility Owned Generation (UOG). (N) | (N) (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 1D5 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised Cal. PUC Sheet No. Cal. PUC Sheet No. Schedule TMDL TRANSFERRED MUNICIPAL DEPARTING LOAD 68011-E 67813-E Sheet 4 (Continued) RATES (Continued) The following chart displays the current CTC and PCIA components by rate group. TMDL CRS ($/kWh)* TMDL CRS 2001 Vintage ($/kWh) CTC 0.00055 PCIA (0.00211) (I) GS-1 [2] 0.00042 (0.00165) (I) TC-1 [3] 0.00039 (0.00151) (I) GS-2 [4] 0.00043 (0.00167) (I) TOU-GS-3 [5] 0.00041 (0.00159) (I) TOU-8-Sec [6] 0.00040 (0.00156) (I) TOU-8-Pri [6] 0.00039 (0.00153) (I) TOU-8-Sub [6] 0.00037 (0.00144) (I) TOU-8-Standby-Sec [7] 0.00038 (0.00149) (I) TOU-8-Standby-Pri [7] 0.00039 (0.00151) (I) TOU-8-Standby-Sub [7] 0.00036 (0.00143) (I) PA-1 [8] 0.00040 (0.00157) (I) PA-2 [9] 0.00040 (0.00157) (I) TOU-PA-2 [10] 0.00040 (0.00157) (I) TOU-PA-3 [11] 0.00039 (0.00151) (I) St. Lighting [12] 0.00036 (0.00143) (I) Rate Group Domestic [1] 1. Includes Schedules D, D-CARE, DE, D-FERA, D-SDP, DM, DMS-1, DMS-2, DMS-3, TOU-D, TOU-D-T, and TOU-EV-1. 2 Includes Schedules GS-1, TOU-EV-7, TOU-GS-1, and TOU-GS-1-D-RTP, and AL-2 (On-Peak). Includes Schedules TC-1, Wi-Fi-1 and WTR. Includes Schedules GS-2, TOU-EV-8, TOU-GS-2, and TOU-GS-2-D-RTP. Includes Schedules TOU-GS-3, and TOU-GS-3-D-RTP. Includes Schedules TOU-EV-9, TOU-8, TOU-8-RBU, TOU-8-D-RTP. Includes Schedules TOU-8-S, and TOU-8-D-RTP-S. Includes Schedules PA-1 Includes Schedules PA-2 Includes Schedules TOU-PA-2, TOU-PA-2-D-RTP. Includes Schedules TOU-PA-3, TOU-PA-3-D-RTP. . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12 . Includes Schedules AL-2 (Off-Peak), AL-2-F, DWL, LS-1, LS-2, LS-3, and OL-1. * The consumer will not be billed a negative PCIA if the sum of the CTC and PCIA charges results in a negative value. If the total indifference rate (i.e. the sum of the CTC and PCIA) is less than zero, the negative indifference amount will be used to offset future positive indifference amounts after September 1, 2006. The resulting CRS will not produce a net payment or credit to the TMDL consumer. (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 4D11 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Cal. PUC Sheet No. Cal. PUC Sheet No. 68012-E 67990-E Sheet 1 Cal. P.U.C. Sheet No. TITLE PAGE ............................................................................................................................. 11431-E TABLE OF CONTENTS - RATE SCHEDULES ....68012-67973-67340-67869-67870-67871-67872-E ........................................................................................................... 68013-68014-68015-E TABLE OF CONTENTS - LIST OF CONTRACTS AND DEVIATIONS ................................... 67976-E TABLE OF CONTENTS - RULES ................................................................................. 67977-64043-E TABLE OF CONTENTS-INDEX OF COMMUNITIES, MAPS, BOUNDARY DESCRIPTIONS 62213-E TABLE OF CONTENTS - SAMPLE FORMS.. ........................ 62-64447-61576-67878-67879-61631-E ........................................................................................................... 67880-67881-63296-E PRELIMINARY STATEMENT: A. B. C. D. E. F. G. H. I. J. K. L. M. N. O. P. Territory Served ......................................................................................................... 22909-E Description of Service ................................................................................................ 22909-E Procedure to Obtain Service ..................................................................................... 22909-E Establishment of Credit and Deposits ....................................................................... 22909-E General .......................................................................... 45178-45179-45180-53818-45182-E Symbols ..................................................................................................................... 45182-E Gross Revenue Sharing Mechanism .......26584-26585-26586-26587-27195-27196-54092-E .................................................................................................. 51717-53819-27200-27201-E Baseline Service ........................................................... 52027-52028-52029-52030-52031-E Charge Ready Program Balancing Account ................................................... 65510-65511-E Not In Use ............................................................................................................................. -E Nuclear Decommissioning Adjustment Mechanism ........................................ 36582-57779-E Purchase Agreement Administrative Costs Balancing Account ........... 55207-51922-55208-E Income Tax Component of Contributions ....................................................... 58419-58420-E Memorandum Accounts.... 21344-67638-67412-58221-49492-61165-61166-61167-53821-E ........ 50418-42841-61168-64869-64870-44950-44951-44952-44953-42849-42850-42851-E ........ 65677-65678-55623-61171-42856-61172-61173-52033-50419-55048-61174-42863-E ........ 42864-67639-67640-51235-45920-51236-61175-50209-42872-42873-50421-46539-E ........ 42876-42877-42878-42879-42880-42881-42882-54534-53371-56253-44959-42887-E ........ 53321-53322-61176-52551-52552-49928-56235-56236-56237-55144-55145-44029-E ........ 53016-57156-57157-51163-51164-51165-51166-67414-51168-51169-51170-51171-E ................................ 51244-55806-56393-56394-56395-56396-56397-56398-56399-58978E California Alternate Rates for Energy (CARE) Adjustment Clause ................. 34705-41902-E .................................................................................................. 36472-38847-56788-67665-E Tree Mortality Non-Bypassable Charge Balancing Account………...65929-65930-65931-E (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 1D8 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution (T) (T)
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Schedule No. Cal. PUC Sheet No. Cal. PUC Sheet No. 68013-E 67991-E Sheet 8 (Continued) RATE SCHEDULES (Continued) Cal. P.U.C. Title of Sheet Sheet No. OTHER BG-NEM Experimental Biogas Net Energy Metering ........ 53878-43574-56092-43576-54290-E ....................................................................................... 50514-49164-53349-54291-E Bio MAT Bioenergy Market Adjusting Tariff.65690-66591-62400-62401-65692-65693-65694-E ……………. 65695-65696-65697-65698-65699-65700-65701-65702-65703-65704-E ............................................................................................................. 65705-65706-E BSC-IMO Bundled Service Customer-Interval Meter Ownership .............. 45197-53879-53880-E CBP Capacity Bidding Program ........... 65879-64008-64106-64107-64011-64399-64108-E ..........................................63335-63336-64109-64110-64111-64112-65880-64125-E CCA-CRS Community Choice Aggregation Cost Responsibility Surcharge ........ 57614-68002-E ........ 67293-67294-68003-67788-67789-67790-67299-67300-67301-67302-67303-E CCA-INFO Community Choice Aggregation-Information Fees ................... 49642-37965-37966-E ............................................................................................................. 37967-47438-E CCA-SF Community Choice Aggregation Service Fees .................................... 51283-51284-E ................................................................ 51285-51286-57389-57390-57391-57392-E CC-DSF Customer Choice - Discretionary Service Fees ............. 58913-53882-51291-53883-E ........................................................................... 51293-51294-51295-51296-55660-E CGDL-CRS Customer Generation Departing Load – Cost Responsibility Surcharge ....... 47058-E ......................................... 49451-68004-68005-67965-67966-56427-46677-46678-E CHP Combined Heat and Power Excess Energy Purchase . 57615-47251-50428-47253-E ........................................................................................................................ 50951-E CPP Critical Peak Pricing ........................................... 65881-66512-66513-66514-66515-E CRPP Charge Ready Program Pilot .................. 58584-58585-65512-58587-65513-58589-E CRTP Charge Ready Transport Program ..........64895-64896-64897-64898-64899-64900-E ........................................................................................................................ 64901-E CREST California Renewable Energy Small Tariff .................... 57617-44057-52962-52963-E DA-CRS Direct Access – Cost Responsibility Surcharge 56739-68006-67305-67306-68007-E ................... 67793-67794-67795-67311-67312-67313-67314-67315-67316-67317-E ....... 67318-67319-67320-67321-67322-67323-67324-67325-67326-67327-63051-E DAEBSC-CRS Direct Access Eligible Bundled Service Customers-Cost Responsibility Surcharge .... ...................................................................................... 42969-58933-42971-46947-E DA-LRATC Direct Access Local Resource Adequacy Transfer Credit ........ 47211-47212-47213-E DA-RCSC Direct Access Revenue Cycle Services Credits ........... 40004-41590-44164-44165-E .................................................................................................. 41593-41594-51080-E DBP Demand Bidding Program ............57044-57045-57046-57047-53046-57333-57334-E DL-NBC Departing Load - Nonbypassable Charges .......................................... 57618-43777-E DR-CRPP Demand Response – Charge Ready Program Pilot ................ 65721-63809-63810-E ............................................................................................................. 63811-63812-E DRP-SF Demand Response Provider Service Fees ........ 56904-56905-56906-56907-56908-E ...................................................................................... 56909-56910-56911-56912-E EITE Emissions-Intensive and Trade-Exposed Customer Greenhouse ................................ Gas Allowance Revenue Provisions ......................................... 56238-56239-56240-E ESP-DSF Energy Service Provider - Discretionary Service Fees ............. 67796-67797-67798-E ..................................................................................... 67799-67800-67801-67802--E ESP-NDSF Energy Service Provider - Non Discretionary Service Fees ................ 67803-67804-E FC-NEM Fuel Cell Electrical Generating Facility NEM & Interconnection Agreement ................ ................... 53887-51140-56093-51142-54293-66579-51145-57619-57620-54294-E GMS Generation Municipal Surcharge .................................................................... 67805-E GTSR-CR Green Tariff Shared Renewables Community Renewables ..... 65158-67988-59543-E .....................................................56743-59544-61100-59546-56747-56748-56749-E GTSR-GR Green Tariff Shared Renewables Green Rate ... 65159-67989-59549-56753-59550-E .................................................................................................. 56755-61103-56757-E (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 8D9 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution (T) (T) (T) (T)
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Cal. PUC Sheet No. Cal. PUC Sheet No. 68014-E 67975-E Sheet 9 (Continued) RATE SCHEDULES (Continued) Schedule No. Title of Sheet Cal. P.U.C. Sheet No. OTHER (Continued) EnvestSCE Equipment Service ................................. 17880-17881-17882-17883-E Multifamily Affordable Solar Housing – Virtual Net Metering ......... 58701-57405--E ... 60419-63424-60421-66580-60422-57741-53570-53571-60423-63484-63485-E .............................................................................................. 63486-63487-63488-E MASH-VNM-ST Multifamily Affordable Solar Housing – Virtual Net Metering Successor Tariff ........ ......................................................................................................... 60427-66516-E ............. 58706-58707-58708--58709-58710-58711-60428-66581-63426-60431-E ............... 60432-60433-60434-60435-60436-63489-63490-63491-63492-63493-E ME Maritime Entities at the Port of Long Beach ............. 54406-54407-54408-54409-E ......................................................................................................... 54410-54411-E NEM Net Energy Metering ... 60441-60442-55420-60443-60444-55423-60445-60446-E ............... 66582-60447-60448-60449-55670-55671-60450-60451-60452-63494-E ............... 63495-63496-63497-63498-63488-63500-63501-63502-63503-63504-E NEM-ST Net Energy Metering Successor Tariff ..................................................................... ..................................... 67967-66518-58730-65281-60464-61587-67968-65283-E ............... 65284-65285-65286-65287-65288-65289-65290-66583-65292-65293-E ... 65294-65295-65296-65297-65298-65299-65300-65301-65302-65303-67969-E .................................................................................................................... 65305-E NEM-V Virtual Net Energy Metering for Multi-Tenant and Multi-Meter Properties ............... ... 58755-53578-49802-60448-60489-63428-60491-60492-66584-66585-66586-E ............... 66587-66588-66589-66590-66591-66592-66593-66594-66595-66596-E NEM-V-ST Virtual Net Energy Metering for Multi-Tenant and Multi-Meter Properties Successor Tariff .................................... 60503-66519-58760-58761-58762-58763 .......................... 58764-58765-58766-60504-60505-66597-63430-60508-60509-E ..................................... 60510-60511-60512-63516-63517-63518-63519-63520-E NMDL New Municipal Departing Load .......... 68008-67806-49954-52450-54678-68009-E ..................................... 62453-52454-52455-52456-52457-52458-52459-52460-E OBF On-Bill Financing Program .............................................................. 41743-41744-E OBF-2 On-Bill Financing Program 2 ........................................................... 51597-51598-E OBMC Optional Binding Mandatory Curtailment ...... 65883-65884-63589-63590-65885-E OBR On-Bill Repayment Pilot Program ...... 53933-53944-53935-53936-53937-53938-E .............................................................................................. 53939-56928-56929-E PARF …………………………………………………………………………………,…67808-E PC-TBS Procurement Charge Transitional Bundled Service 57621-49964-49965-38146-E PCT Programmable Communicating Thermostat ............ 45826-44278-50143-45287-E PVS Experimental Photovoltaic Service.................................................. 47451-47452-E PVS-2 On-Grid Photovoltaic Service ......................................................... 19518-19519-E GSN MASH-VNM (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 9D9 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution (T)
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Southern California Edison Rosemead, California (U 338-E) Cancelling Revised Revised TABLE OF CONTENTS Cal. PUC Sheet No. Cal. PUC Sheet No. 68015-E 67976-E Sheet 10 (Continued) RATE SCHEDULES (Continued) Schedule No. Title of Sheet OTHER (Continued) Cal. P.U.C. Sheet No. RES-BCT Renewable Energy Self-Generation Bill Credit Transfer .......... 66520-58777-59485-E .....................................................60752-60753-60754-60755-66521-66522-66523-E Re-MAT Renewable Market Adjusting Tariff ......... 52964-52965-61890-52967-61891-52969-E .....................................................52970-52971-61892-52973-55678-61893-61894-E RF-E Surcharge to Fund Public Utilities Commission Reimbursement Fee ............ 66849-E S Standby – 500 kW and Below 66524-66525-67809-67810-67811-66529-66530-E ................... 66531-66532-66533-66534-66535-66536-66537-66538-66539-66540-E SC Service Connection Charge ............................................................................ 67812-E SLRP Scheduled Load Reduction Program ...... 53895-47456-47977-47978-47979-53896-E ...................................................................................... 47980-47981-47982-47983-E SOMAH-VNM-ST Solar On Multifamily Affordable Housing Virtual Net Metering Successor Tariff… …….63547-63548-63549-63550-63551-63552-63553-63554-66598-63556-63557-E …….63558-63559-63560-63561-63562-63563-63564-63565-63566-63567-63568-E SPSS Station Power Self-Supply ................................. 58778-55488-57625-55490-44851-E TMDL Transferred Municipal Departing Load ... 68010-56051-67333-68011-49968-49969-E .......................... 49970-49971-49972-49973-49974-49975-49976-49977-49978-E UCLT Utility-Controlled Load Tests .......................................................................... 57627-E V2G PILOT SCE Vehicle To Grid Experimental Pilot ................................... 52577-52578-52579-E WATER Water Agency Tariff for Eligible Renewables................ 57628-44061-52978-52979-E WI-FI-1 Schedule WI-FI Pilot Wireless Fidelity Rate ................. 67814-43036-43037-43038-E WTR Wireless Technology Rate ................................. 67815-67816-66855-51997-51998-E (T) LIST OF CONTRACTS AND DEVIATIONS LIST OF CONTRACTS AND DEVIATIONS .........55503-60165-55016-51858-67971-60167-62228-E ......... 53971-51863-51864-51865-51866-51867-51868-60641-51870-54426-57936-E .......................................................................................................................... 54428-E (Continued) (To be inserted by utility) Advice 4072-E Decision 19-08-022 10D9 Issued by Kevin Payne Chief Executive Officer (To be inserted by Cal. PUC) Date Submitted Sep 10, 2019 Effective Resolution
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Attachment B
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IOU Total Portfolio Summary 2019 ERRA Forecast ‐ November Update; July 2019 Update to Reflect D.19‐05‐020 Incremental by Year 1. 2. 3. 4. 5. 6. 7. CRS Eligible Portfolio Costs ($000) CRS Eligible Non‐Renewable Supply at Customer Meter (GWh) CRS Eligible Renewable Supply at Customer Meter (GWh) CRS Eligible Total Net Qualifying Capacity (MW) CRS Eligible System NQC (System only, No flex or local) CRS Eligible Local NQC (System and local, with or without flex) CRS Eligible Flexible NQC (System and flex only, No local) Pre‐2002 CTC‐Eligible Legacy UOG $        184,355                   536                  1,761                   348                     246                       102 $        555,561                6,932                     480                1,661                   643                  1,018 2004‐2009 2010 2011 2012 Vintage Portfolios 2013 2014 $     1,133,695 $        284,964 $        328,354 $        105,187 $            48,312 $        236,932                3,057                    ‐                      ‐                      ‐                      ‐                      ‐                  4,803                2,254                2,755                1,031                     557                3,428 This sheet is not impacted by the 10/1/19 implementation of D.19‐08‐022.                1,446                     233                   254                      13                      35                   269                       399                   223                   254                      10                      26                   259                        1,047                      10                    ‐                          3                        9                      10 2015 2016 2017 2018 $        275,088                    ‐                  4,581                1,157                1,149                        8 $        117,837                   226                        53                2,452                     363                2,089 $             6,534                    ‐                        24                    ‐                      ‐                      ‐   $            11,386                    ‐                     171                      ‐                      ‐                      ‐   2019 $                 ‐                    ‐                      ‐                      ‐                      ‐                      ‐   Total $          3,288,205                 10,751                   21,897                       7,868                     3,573                     4,295
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Indifference Calculation Inputs and Sources 2019 ERRA Forecast ‐ November Update; July 2019 Update to Reflect D.19‐05‐020 Line No. 1. 2. 3. 4. 5. Description On Peak SP 15 Price ($/MWh) Off Peak SP 15 Price ($/MWh) On Peak Load Weight (%) Off Peak Load Weight (%) Load Weighted Average Price ($/MWh) Source of Data Platt's Platt's Y‐1 Recorded Load ‐ On Peak Hours Y‐1 Recorded Load ‐ Off Peak Hours Line 1 x Line 3 + Line 2 x Line 4 Value 62% 38% $41.97 6. 7. REC Benchmark ($/MWh) This sheet is not impacted by the 10/1/19 implementation of D.19‐08‐022. Platt's (2019); Energy Division (2020 and beyond) Total "Green" Benchmark ($/MWh) Line 6 + Line 5 $18.00 $59.97 8. 9. 10. System RA Benchmark ($/kW‐Year) Local RA Benchmark ($/kW‐Year) Flexible RA Benchmark ($/kW‐Year) Energy Division Energy Division Energy Division $37.08 $37.08 $0.00 11. Line Loss Adjustment Factor Resolution E‐4475 12. Franchise Fees and Uncollectibles Factor D.19‐05‐020 1.053 0.988746
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Indifference Amount Calculation 2019 ERRA Forecast ‐ November Update; July 2019 Update to Reflect D.19‐05‐020 Line No. Description Equation Unit CTC-Eligible One-Time Refunds/Costs Legacy UOG Applicable to All Customers 555,561 2004-2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 Cost of Portfolio 1. CRS Eligible Portfolio Costs Portfolio Summary Line 1 $000 184,355 2. 3. 4. 5. 6. CRS Eligible Non-Renewable Supply at Customer Meter CRS Eligible Renewable Supply at Customer Meter CRS Eligible System NQC CRS Eligible LA Basin NQC CRS Eligible Flexible NQC Portfolio Summary Line 2 Portfolio Summary Line 3 Portfolio Summary Line 5 Portfolio Summary Line 6 Portfolio Summary Line 7 GWh GWh MW MW MW 536 1,761 246 102 - Line 1 / (Line 2 + Line 3) $/MWh $ 80.26 $ 74.96 $ 144.24 $ 126.43 $ 119.19 $ 102.00 $ 86.72 $ 69.12 $ 60.05 $ 421.88 $ 271.59 $ 66.75 7. Portfolio $/MWh Cost 105,187 48,312 236,932 275,088 117,837 6,932 3,057 480 4,803 2,254 2,755 1,031 643 399 223 254 10 1,018 1,047 10 3 This sheet is not impacted by the 10/1/19 implementation of D.19‐08‐022. - 1,133,695 284,964 328,354 557 26 9 - 3,428 259 10 - 4,581 1,149 8 - 226 53 363 2,089 - 6,534 11,386 24 - - 171 - - NA 8. Market Value of Portfolio 9. 10. 11. 12. Market Value of Brown Portfolio Non-Renewable Energy Platt's Weighted Price (Brown Benchmark) Market Value of Brown Portfolio Line 2 Input Line 5 Line 10 x Line 11 GWh $/MWh $000 $ $ 536 41.97 22,500 $ $ 6,932 41.97 290,927 $ $ 3,057 41.97 128,294 $ $ 41.97 - $ $ 41.97 - $ $ 41.97 - $ $ 41.97 - $ $ 41.97 - $ $ 41.97 - $ $ 226 41.97 9,501 $ $ 41.97 - $ $ 41.97 - $ $ 41.97 - 13. 14. 15. 16. Market Value of Green Portfolio Renewable Energy Weighted Average Green Benchmark Market Value of Green Portfolio Line 3 Input Line 7 Line 14 x Line 15 GWh $/MWh $000 $ $ 1,761 59.97 105,593 $ $ 480 59.97 28,775 $ $ 4,803 59.97 288,030 $ $ 2,254 59.97 135,171 $ $ 2,755 59.97 165,206 $ $ 1,031 59.97 61,842 $ $ 557 59.97 33,409 $ $ 3,428 59.97 205,552 $ $ 4,581 59.97 274,706 $ $ 53 59.97 3,174 $ $ 24 59.97 1,443 $ $ 171 59.97 10,230 $ $ 59.97 - 17. 18. 19. Capacity Adder Average Monthly System NQC System RA Benchmark Line 4 Input Line 8 MW $/kW-Year $ 246 37.08 $ 643 37.08 $ 399 37.08 $ 223 37.08 $ 254 37.08 $ 10 37.08 $ 26 37.08 $ 259 37.08 $ 1,149 37.08 $ 363 37.08 $ 37.08 $ 37.08 $ 37.08 20. 21. Average Monthly Local NQC (Big Creek and LA Basin) Local RA Benchmark Line 5 Input Line 9 MW $/kW-Year $ 102 37.08 $ 1,018 37.08 $ 1,047 37.08 $ 10 37.08 $ 37.08 $ 3 37.08 $ 9 37.08 $ 10 37.08 $ 8 37.08 $ 2,089 37.08 $ 37.08 $ 37.08 $ 37.08 22. 23. Average Monthly Flexible NQC Flexible RA Benchmark MW $/kW-Year $ - $ - $ - $ - $ - $ - $ - $ - $ - $ - $ - $ - $ - 24. Market Value of Capacity Line 6 Input Line 10 Sum (Lines 18 x 19, 20 x 21, 22 x 23) $000 $ 12,901 $ 61,598 $ 53,605 $ 8,630 $ 9,432 $ 468 $ 1,304 $ 9,992 $ 42,898 $ 90,913 $ - $ - $ - 25. Portfolio Market Value 26. Line Loss Adjusted Portfolio Market value Line 12 + Line 16 + Line 24 $000 Line 25 x Input Line 11 $000 $ $ 140,995 148,468 $ $ 381,299 401,508 $ $ 469,929 494,835 $ $ 143,802 151,423 $ $ 174,638 183,894 $ $ 62,310 65,613 $ $ 34,713 36,553 $ $ 215,544 226,968 $ $ 317,604 334,437 $ $ 103,588 109,078 $ $ 1,443 1,519 $ $ 10,230 10,772 $ $ - 27. Indifference Amount 28. Portfolio Total Cost 29. Portfolio Market Value 30. Total Indifference Amount (Unadjusted) Line 1 Line 26 Line 28 - Line 29 $000 $000 $000 $ $ $ 184,355 148,468 35,887 $ $ $ 555,561 401,508 154,053 $ 1,133,695 $ 494,835 $ 638,859 $ $ $ 284,964 151,423 133,540 $ $ $ 328,354 183,894 144,460 $ $ $ 105,187 65,613 39,574 $ $ $ 48,312 36,553 11,760 $ $ $ 236,932 226,968 9,964 $ $ $ 275,088 $ 334,437 $ (59,348) $ 117,837 109,078 8,759 $ $ $ 6,534 1,519 5,015 $ $ $ 11,386 10,772 615 $ $ $ - - - $ $ - - $ $ $ 5,015 5,072 (29,443) (28,828) (29,157) $ $ 8,759 8,859 $ $ $ $ $ $ $ $ $ - 31. 32. 33. 34. 35. 36. DWR Revenue Requirement 1/ One-Time Adjustments (if applicable) 2018 GRC Revenue Requirement Memorandum Account Adjustment PABA Year-End Balance Sum (Lines 28:31) Vintaged PABA Revenue Requirement Line 28/Input Line 13 Vintaged PABA Rev Req with FF&U $000 $000 $000 $000 $000 $001 $ $ $ $ 35,887 36,296 (67,813) $ $ $ $ (67,813) $ (68,585) $ $ $ (67,146) $ $ 86,906 $ 87,896 $ 1/ One-Time Adjustment of: $68M in Energy Crisis-related refunds $32M to reflect the market value of the 2019 RECs associated with the Caithness contract/Shell Offtake agreement (i.e. ~1,800 GWh RECs x $18/MWh) - (32,189) (18,491) 588,179 594,873 $ $ $ $ $ 133,540 135,060 $ $ $ $ $ 144,460 146,105 $ $ - $ $ - $ $ - $ $ $ $ $ 39,574 40,024 $ $ $ 11,760 11,894 $ $ $ 9,964 10,077 $ $ $ $ $ $ (59,348) $ (60,024) $
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Indifference Rate Calculation 2019 ERRA Forecast ‐ Revised Pursuant to D.19‐02‐024; July 2019 Update to Reflect D.19‐05‐020; October 2019 Update to Reflect 2017 ERRA Phase 2 Settlement for Pre‐2009 Customers PABA Revenue Requirement Allocation to Rate Groups -- Vintaged Revenue Requirement x Column B Rate Group Generation Revenue Allocator (See Rate Design by Vintage tab) Total Indifference Amounts by Vintage Domestic GS-1 TC-1 GS-2 TOU-GS-3 TOU-8-Sec TOU-8-Pri TOU-8-Sub TOU-PA-2 TOU-PA-3 St. Lighting Standby - Sec Standby - Pri Standby - Sub CTC Indifference One-Time Refunds and/or Costs Legacy UOG 2004-2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 $ 40.72% 6.88% 0.06% 15.46% 8.75% 8.82% 5.89% 5.94% 1.99% 1.53% 0.70% 0.24% 0.84% 2.18% 36,296 $ (68,585) $ 87,896 $ 594,873 $ 135,060 $ 146,105 $ 40,024 $ 11,894 $ 10,077 $ (60,024) $ 8,859 $ 5,072 $ (29,157) $ - $ $ $ $ $ $ $ $ $ $ $ $ $ $ 14,780 2,499 22 5,610 3,175 3,202 2,139 2,155 724 555 255 87 303 790 $ $ $ $ $ $ $ $ $ $ $ $ $ $ (27,929) (4,722) (42) (10,600) (5,999) (6,050) (4,042) (4,072) (1,368) (1,048) (482) (164) (573) (1,493) 35,793 6,051 54 13,585 7,689 7,754 5,180 5,218 1,753 1,343 617 210 735 1,913 $ 242,245 $ 40,955 $ 366 $ 91,944 $ 52,036 $ 52,479 $ 35,055 $ 35,316 $ 11,866 $ 9,091 $ 4,177 $ 1,422 $ 4,972 $ 12,949 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 16,299 2,756 25 6,186 3,501 3,531 2,359 2,376 798 612 281 96 335 871 $ $ $ $ $ $ $ $ $ $ $ $ $ $ 4,843 819 7 1,838 1,040 1,049 701 706 237 182 84 28 99 259 $ $ $ $ $ $ $ $ $ $ $ $ $ $ 4,104 694 6 1,558 881 889 594 598 201 154 71 24 84 219 $ $ $ $ $ $ $ $ $ $ $ $ $ $ (24,443) (4,132) (37) (9,277) (5,250) (5,295) (3,537) (3,563) (1,197) (917) (421) (143) (502) (1,307) 3,607 610 5 1,369 775 782 522 526 177 135 62 21 74 193 $ $ $ $ $ $ $ $ $ $ $ $ $ $ 2,065 349 3 784 444 447 299 301 101 78 36 12 42 110 $ $ $ $ $ $ $ $ $ $ $ $ $ $ (11,873) (2,007) (18) (4,506) (2,550) (2,572) (1,718) (1,731) (582) (446) (205) (70) (244) (635) - $ $ $ $ $ $ $ $ $ $ $ $ $ $ Rate Group 54,999 9,298 83 20,875 11,814 11,915 7,959 8,018 2,694 2,064 948 323 1,129 2,940 59,497 10,059 90 22,582 12,780 12,889 8,610 8,674 2,914 2,233 1,026 349 1,221 3,180 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Forecast Sales of Those Responsible for Each Portfolio of Resources (GWh) Forecast Sales Forecast of Those system sales Responsible for CTC Domestic GS-1 TC-1 GS-2 TOU-GS-3 TOU-8-Sec TOU-8-Pri TOU-8-Sub TOU-PA-2 TOU-PA-3 St. Lighting Standby - Sec Standby - Pri Standby - Sub Total Sales 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 Rate Group CTC Rate Domestic GS-1 TC-1 GS-2 TOU-GS-3 TOU-8-Sec TOU-8-Pri TOU-8-Sub TOU-PA-2 TOU-PA-3 St. Lighting Standby - Sec Standby - Pri Standby - Sub $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.00055 0.00042 0.00039 0.00043 0.00041 0.00040 0.00039 0.00037 0.00040 0.00039 0.00036 0.00038 0.00039 0.00036 Forecast Sales of Those Responsible for OneTime Refunds/Cos ts 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 Legacy UOG 2004-2009 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2010 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2011 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 DWR Energy Credit $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ CTC 0.00055 0.00042 0.00039 0.00043 0.00041 0.00040 0.00039 0.00037 0.00040 0.00039 0.00036 0.00038 0.00039 0.00036 0.00045 -0.00007 2013 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2014 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2015 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2016 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2017 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 Incremental Rate for Each Portfolio of Resources (Vintage Indifference Amount by Rate Group / Forecast Sales by Rate Group) One-Time Legacy Refunds/Cos 2004-2009 2010 2011 2012 2013 2014 2015 2016 UOG ts $ (0.00103) $ 0.00133 $ 0.00897 $ 0.00204 $ 0.00220 $ 0.00060 $ 0.00018 $ 0.00015 $ (0.00090) $ 0.00013 $ (0.00080) $ 0.00103 $ 0.00694 $ 0.00158 $ 0.00170 $ 0.00047 $ 0.00014 $ 0.00012 $ (0.00070) $ 0.00010 $ (0.00073) $ 0.00094 $ 0.00635 $ 0.00144 $ 0.00156 $ 0.00043 $ 0.00013 $ 0.00011 $ (0.00064) $ 0.00009 $ (0.00081) $ 0.00104 $ 0.00705 $ 0.00160 $ 0.00173 $ 0.00047 $ 0.00014 $ 0.00012 $ (0.00071) $ 0.00010 $ (0.00077) $ 0.00099 $ 0.00669 $ 0.00152 $ 0.00164 $ 0.00045 $ 0.00013 $ 0.00011 $ (0.00068) $ 0.00010 $ (0.00075) $ 0.00097 $ 0.00654 $ 0.00149 $ 0.00161 $ 0.00044 $ 0.00013 $ 0.00011 $ (0.00066) $ 0.00010 $ (0.00074) $ 0.00094 $ 0.00639 $ 0.00145 $ 0.00157 $ 0.00043 $ 0.00013 $ 0.00011 $ (0.00064) $ 0.00010 $ (0.00069) $ 0.00089 $ 0.00601 $ 0.00137 $ 0.00148 $ 0.00040 $ 0.00012 $ 0.00010 $ (0.00061) $ 0.00009 $ (0.00076) $ 0.00097 $ 0.00655 $ 0.00149 $ 0.00161 $ 0.00044 $ 0.00013 $ 0.00011 $ (0.00066) $ 0.00010 $ (0.00073) $ 0.00093 $ 0.00632 $ 0.00143 $ 0.00155 $ 0.00043 $ 0.00013 $ 0.00011 $ (0.00064) $ 0.00009 $ (0.00069) $ 0.00088 $ 0.00598 $ 0.00136 $ 0.00147 $ 0.00040 $ 0.00012 $ 0.00010 $ (0.00060) $ 0.00009 $ (0.00072) $ 0.00092 $ 0.00624 $ 0.00142 $ 0.00153 $ 0.00042 $ 0.00012 $ 0.00011 $ (0.00063) $ 0.00009 $ (0.00073) $ 0.00094 $ 0.00634 $ 0.00144 $ 0.00156 $ 0.00043 $ 0.00013 $ 0.00011 $ (0.00064) $ 0.00009 $ (0.00069) $ 0.00088 $ 0.00594 $ 0.00135 $ 0.00146 $ 0.00040 $ 0.00012 $ 0.00010 $ (0.00060) $ 0.00009 10/1/19 Rate Change:  PCIA 2001/2004 Vintage equation modified to only include Incremental Rate associated with "One‐Time Refunds/Costs" Rate Group Domestic GS-1 TC-1 GS-2 TOU-GS-3 TOU-8-Sec TOU-8-Pri TOU-8-Sub TOU-PA-2 TOU-PA-3 St. Lighting Standby - Sec Standby - Pri Standby - Sub System Average 2012 2018 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2017 $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.00008 0.00006 0.00005 0.00006 0.00006 0.00006 0.00005 0.00005 0.00006 0.00005 0.00005 0.00005 0.00005 0.00005 2019 27,012 5,903 58 13,047 7,777 8,023 5,489 5,871 1,811 1,438 698 228 784 2,179 80,317 2018 $ $ $ $ $ $ $ $ $ $ $ $ $ $ (0.00044) (0.00034) (0.00031) (0.00035) (0.00033) (0.00032) (0.00031) (0.00029) (0.00032) (0.00031) (0.00029) (0.00031) (0.00031) (0.00029) 2019 $ $ $ $ $ $ $ $ $ $ $ $ $ $ - Final Cumulative Rates PCIA 2001 Vintage PCIA 2004 Vintage PCIA 2009 Vintage PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage PCIA 2018 Vintage PCIA 2019 Vintage $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ (0.00103) (0.00080) (0.00073) (0.00081) (0.00077) (0.00075) (0.00074) (0.00069) (0.00076) (0.00073) (0.00069) (0.00072) (0.00073) (0.00069) (0.00085) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ (0.00103) (0.00080) (0.00073) (0.00081) (0.00077) (0.00075) (0.00074) (0.00069) (0.00076) (0.00073) (0.00069) (0.00072) (0.00073) (0.00069) (0.00085) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.00926 0.00716 0.00656 0.00728 0.00691 0.00675 0.00659 0.00621 0.00676 0.00653 0.00618 0.00645 0.00655 0.00614 0.00765 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01130 0.00874 0.00800 0.00888 0.00843 0.00824 0.00804 0.00758 0.00825 0.00796 0.00753 0.00786 0.00799 0.00748 0.00933 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01350 0.01044 0.00956 0.01061 0.01007 0.00985 0.00961 0.00905 0.00986 0.00951 0.00900 0.00940 0.00955 0.00894 0.01115 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01410 0.01091 0.00999 0.01108 0.01052 0.01029 0.01004 0.00946 0.01030 0.00994 0.00940 0.00982 0.00998 0.00934 0.01165 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01428 0.01105 0.01012 0.01122 0.01066 0.01042 0.01017 0.00958 0.01043 0.01006 0.00952 0.00994 0.01010 0.00946 0.01179 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01443 0.01117 0.01023 0.01134 0.01077 0.01053 0.01028 0.00968 0.01054 0.01017 0.00963 0.01005 0.01021 0.00956 0.01192 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01353 0.01047 0.00959 0.01063 0.01009 0.00987 0.00963 0.00907 0.00988 0.00953 0.00902 0.00942 0.00957 0.00896 0.01117 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01366 0.01057 0.00968 0.01074 0.01019 0.00996 0.00973 0.00916 0.00998 0.00963 0.00911 0.00951 0.00966 0.00905 0.01128 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01374 0.01063 0.00973 0.01080 0.01025 0.01002 0.00978 0.00921 0.01004 0.00968 0.00916 0.00956 0.00972 0.00910 0.01135 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01330 0.01029 0.00942 0.01045 0.00992 0.00970 0.00947 0.00892 0.00972 0.00937 0.00887 0.00926 0.00941 0.00881 0.01098 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ 0.01330 0.01029 0.00942 0.01045 0.00992 0.00970 0.00947 0.00892 0.00972 0.00937 0.00887 0.00926 0.00941 0.00881 0.01098
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ERRA CRS Rates 2019 ERRA Forecast ‐ Revised Pursuant to D.19‐02‐024, Includes DWR Energy Credit of ‐$0.00007; July 2019 Update to Reflect D.19‐05‐020, October 2019 Update to Reflect  2017 ERRA Phase 2 Settlement for Pre‐2009 Vintage Customers Rate Group DWRBC (All CTC (For 1/ Vintages) All Vintages) PCIA 2001 Vintage PCIA 2004 Vintage PCIA 2009 Vintage PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage PCIA 2018 Vintage PCIA 2019 Vintage Domestic 0.00503 0.00055 (0.00110) (0.00110) 0.00919 0.01123 0.01343 0.01403 0.01421 0.01436 0.01346 0.01359 0.01367 0.01323 0.01323 GS-1 0.00503 0.00042 (0.00087) (0.00087) 0.00709 0.00867 0.01037 0.01084 0.01098 0.01110 0.01040 0.01050 0.01056 0.01022 0.01022 TC-1 0.00503 0.00039 (0.00080) (0.00080) 0.00649 0.00793 0.00949 0.00992 0.01005 0.01016 0.00952 0.00961 0.00966 0.00935 0.00935 GS-2 0.00503 0.00043 (0.00088) (0.00088) 0.00721 0.00881 0.01054 0.01101 0.01115 0.01127 0.01056 0.01067 0.01073 0.01038 0.01038 TOU-GS-3 0.00503 0.00041 (0.00084) (0.00084) 0.00684 0.00836 0.01000 0.01045 0.01059 0.01070 0.01002 0.01012 0.01018 0.00985 0.00985 TOU-8-Sec 0.00503 0.00040 (0.00082) (0.00082) 0.00668 0.00817 0.00978 0.01022 0.01035 0.01046 0.00980 0.00989 0.00995 0.00963 0.00963 TOU-8-Pri 0.00503 0.00039 (0.00081) (0.00081) 0.00652 0.00797 0.00954 0.00997 0.01010 0.01021 0.00956 0.00966 0.00971 0.00940 0.00940 TOU-8-Sub 0.00503 0.00037 (0.00076) (0.00076) 0.00614 0.00751 0.00898 0.00939 0.00951 0.00961 0.00900 0.00909 0.00914 0.00885 0.00885 Small AG 0.00503 0.00040 (0.00083) (0.00083) 0.00669 0.00818 0.00979 0.01023 0.01036 0.01047 0.00981 0.00991 0.00997 0.00965 0.00965 Large AG 0.00503 0.00039 (0.00080) (0.00080) 0.00646 0.00789 0.00944 0.00987 0.00999 0.01010 0.00946 0.00956 0.00961 0.00930 0.00930 St. Lighting 0.00503 0.00036 (0.00076) (0.00076) 0.00611 0.00746 0.00893 0.00933 0.00945 0.00956 0.00895 0.00904 0.00909 0.00880 0.00880 Standby - Sec 0.00503 0.00038 (0.00079) (0.00079) 0.00638 0.00779 0.00933 0.00975 0.00987 0.00998 0.00935 0.00944 0.00949 0.00919 0.00919 Standby - Pri 0.00503 0.00039 (0.00080) (0.00080) 0.00648 0.00792 0.00948 0.00991 0.01003 0.01014 0.00950 0.00959 0.00965 0.00934 0.00934 Standby - Sub 0.00503 0.00036 (0.00076) (0.00076) 0.00607 0.00741 0.00887 0.00927 0.00939 0.00949 0.00889 0.00898 0.00903 0.00874 0.00874 0.00045 (0.00085) (0.00085) 0.00765 0.00933 0.01115 0.01165 0.01179 0.01192 0.01117 0.01128 0.01135 0.01098 0.01098 System Average (Across Classes)
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2018 "True‐Up" per D.19‐02‐024 Surcharge/Refund Calculation (Alternate Implementation Approach); October 2019 Update to Reflect 2017 ERRA Phase 2 Settlement for Pre‐2009 Vintage Customers Comparison of Forecast vs. "Actual" Indifference Amounts CTC-Eligible Legacy UOG Original "Adjusted Indifference Amounts with FF&U" ($000) ‐‐ Incremental "Actual" "Adjusted Indifference Amounts with  FF&U" ($000) ‐‐ Incremental 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 $       47,106 $        223,058 $        503,967 $        138,103 $             151,939 $              28,415 $              (10,152) $              (26,036) $              (37,327) $          (36,372) $                 359 $              ‐ $      (19,786) $        156,115 $        553,669 $        128,268 $             141,217 $              30,689 $              (26,929) $              (41,768) $              (47,465) $          (57,562) $                 503 $              ‐ Incremental "True‐Up" Amount by Vintage Portfolio (Positive = Undercollection and Surcharge; Negative  = Overcollection and Refund) $      (66,892) $          (66,942) $          49,702 $           (9,835) $              (10,723) $                2,274 $              (16,777) $              (15,732) $              (10,138) $          (21,191) $                 144 $              ‐ "True‐Up Surcharge/Refund" For Each Incremental Portfolio of Resources Final 2018 GRC  Phase 2 System  Generation  Revenue  "True‐Up Surcharge/Refund" for Each Incremental  Allocation  Portfolio of Resources Factors ‐‐ Same  as those used  for "Base" 2019  PCIA Rates Domestic 40.72% GS-1 6.88% TC-1 0.06% GS-2 15.46% TOU-GS-3 8.75% TOU-8-Sec 8.82% TOU-8-Pri 5.89% TOU-8-Sub 5.94% TOU-PA-2 1.99% TOU-PA-3 1.53% St. Lighting 0.70% Standby - Sec 0.24% Standby - Pri 0.84% Standby - Sub 2.18% System‐ Level kWh  Sales ‐‐  Same as  CTC-Eligible Legacy UOG 2009 Portfolio 2010 Portfolio 2011 Portfolio Portfolio those used  Portfolio for "Base"  2019 PCIA  Rates 2012 Portfolio 2013 Portfolio 2014 Portfolio 2015 Portfolio 2016 Portfolio 2017 Portfolio            27,012              5,903                  58            13,047              7,777              8,023              5,489              5,871              1,811              1,438                698                228                784              2,179               0.00003               0.00003               0.00002               0.00003               0.00003               0.00003               0.00002               0.00002               0.00003               0.00002               0.00002               0.00002               0.00002               0.00002               (0.00025)               (0.00020)               (0.00018)               (0.00020)               (0.00019)               (0.00018)               (0.00018)               (0.00017)               (0.00018)               (0.00018)               (0.00017)               (0.00018)               (0.00018)               (0.00017)               (0.00024)               (0.00018)               (0.00017)               (0.00019)               (0.00018)               (0.00017)               (0.00017)               (0.00016)               (0.00017)               (0.00017)               (0.00016)               (0.00017)               (0.00017)               (0.00016)               (0.00015)               (0.00012)               (0.00011)               (0.00012)               (0.00011)               (0.00011)               (0.00011)               (0.00010)               (0.00011)               (0.00011)               (0.00010)               (0.00011)               (0.00011)               (0.00010)        (0.00101)        (0.00078)        (0.00071)        (0.00079)        (0.00075)        (0.00074)        (0.00072)        (0.00068)        (0.00074)        (0.00071)        (0.00067)        (0.00070)        (0.00071)        (0.00067)           (0.00101)           (0.00078)           (0.00072)           (0.00079)           (0.00075)           (0.00074)           (0.00072)           (0.00068)           (0.00074)           (0.00071)           (0.00067)           (0.00070)           (0.00071)           (0.00067)           0.00075           0.00058           0.00053           0.00059           0.00056           0.00055           0.00053           0.00050           0.00055           0.00053           0.00050           0.00052           0.00053           0.00050           (0.00015)           (0.00011)           (0.00011)           (0.00012)           (0.00011)           (0.00011)           (0.00011)           (0.00010)           (0.00011)           (0.00010)           (0.00010)           (0.00010)           (0.00010)           (0.00010)               (0.00016)               (0.00013)               (0.00011)               (0.00013)               (0.00012)               (0.00012)               (0.00012)               (0.00011)               (0.00012)               (0.00011)               (0.00011)               (0.00011)               (0.00011)               (0.00011) Final Brown Power True‐Up Surcharge/Refund (Cumulative, sums up all surcharges/refunds for the vintage portfolios that the customer is responsible for ‐‐ e.g., PCIA 2001 Vintage reflects sum of true‐up rates for CTC‐eligible and Legacy UOG Portfolios; PCIA 2009 Vintage  reflects true‐up rates for CTC‐eligible, Legacy UOG, and 2009 vintage portfolios) PCIA 2001 Vintage Domestic GS-1 TC-1 GS-2 TOU-GS-3 TOU-8-Sec TOU-8-Pri TOU-8-Sub TOU-PA-2 TOU-PA-3 St. Lighting Standby - Sec Standby - Pri Standby - Sub PCIA 2004 Vintage PCIA 2009 Vintage              (0.00101)              (0.00078)              (0.00071)              (0.00079)              (0.00075)              (0.00074)              (0.00072)              (0.00068)              (0.00074)              (0.00071)              (0.00067)              (0.00070)              (0.00071)              (0.00067)        (0.00101)        (0.00078)        (0.00071)        (0.00079)        (0.00075)        (0.00074)        (0.00072)        (0.00068)        (0.00074)        (0.00071)        (0.00067)        (0.00070)        (0.00071)        (0.00067)        (0.00127)        (0.00098)        (0.00090)        (0.00099)        (0.00094)        (0.00093)        (0.00091)        (0.00086)        (0.00093)        (0.00089)        (0.00084)        (0.00088)        (0.00089)        (0.00084) PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage           (0.00142)           (0.00109)           (0.00101)           (0.00111)           (0.00105)           (0.00104)           (0.00102)           (0.00096)           (0.00104)           (0.00099)           (0.00094)           (0.00098)           (0.00099)           (0.00094)           (0.00158)           (0.00122)           (0.00112)           (0.00124)           (0.00117)           (0.00116)           (0.00114)           (0.00107)           (0.00116)           (0.00110)           (0.00105)           (0.00109)           (0.00110)           (0.00105)           (0.00155)           (0.00119)           (0.00110)           (0.00121)           (0.00114)           (0.00113)           (0.00112)           (0.00105)           (0.00113)           (0.00108)           (0.00103)           (0.00107)           (0.00108)           (0.00103) 10/1/19 Rate Change:  2001/2004 Vintage Portfolios' equation modified to only include Incremental BPTU Rate associated with CTC‐eligible Portfolio PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage               (0.00180)               (0.00139)               (0.00128)               (0.00141)               (0.00133)               (0.00131)               (0.00130)               (0.00122)               (0.00131)               (0.00126)               (0.00120)               (0.00125)               (0.00126)               (0.00120)               (0.00204)               (0.00157)               (0.00145)               (0.00160)               (0.00151)               (0.00148)               (0.00147)               (0.00138)               (0.00148)               (0.00143)               (0.00136)               (0.00142)               (0.00143)               (0.00136)               (0.00219)               (0.00169)               (0.00156)               (0.00172)               (0.00162)               (0.00159)               (0.00158)               (0.00148)               (0.00159)               (0.00154)               (0.00146)               (0.00153)               (0.00154)               (0.00146)               (0.00251)               (0.00194)               (0.00179)               (0.00197)               (0.00186)               (0.00182)               (0.00181)               (0.00169)               (0.00182)               (0.00177)               (0.00167)               (0.00175)               (0.00177)               (0.00167)               (0.00251)               (0.00194)               (0.00179)               (0.00197)               (0.00186)               (0.00182)               (0.00181)               (0.00169)               (0.00182)               (0.00177)               (0.00167)               (0.00175)               (0.00177)               (0.00167)           (0.00032)           (0.00025)           (0.00023)           (0.00025)           (0.00024)           (0.00023)           (0.00023)           (0.00021)           (0.00023)           (0.00023)           (0.00021)           (0.00022)           (0.00023)           (0.00021)                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐                    ‐ 2018 Portfolio                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐                   ‐
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Final 2019 ERRA CRS Rates (2019 ERRA, 2018 GRC, 2017 ERRA Phase 2 for Pre‐2009 Customers) Rate Group Domestic GS-1 DWRBC (All Vintages) 1/ 0.00503 CTC (For All Vintages) 0.00055 0.00503 0.00042 Base 2019 Rates PCIA 2001 Vintage PCIA 2004 Vintage PCIA 2009 Vintage PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage PCIA 2018 Vintage PCIA 2019 Vintage (0.00110) (0.00110) 0.00919 0.01123 0.01343 0.01403 0.01421 0.01436 0.01346 0.01359 0.01367 0.01323 0.01323 (0.00087) (0.00087) 0.00709 0.00867 0.01037 0.01084 0.01098 0.01110 0.01040 0.01050 0.01056 0.01022 0.01022 TC-1 0.00503 0.00039 (0.00080) (0.00080) 0.00649 0.00793 0.00949 0.00992 0.01005 0.01016 0.00952 0.00961 0.00966 0.00935 0.00935 GS-2 0.00503 0.00043 (0.00088) (0.00088) 0.00721 0.00881 0.01054 0.01101 0.01115 0.01127 0.01056 0.01067 0.01073 0.01038 0.01038 TOU-GS-3 0.00503 0.00041 (0.00084) (0.00084) 0.00684 0.00836 0.01000 0.01045 0.01059 0.01070 0.01002 0.01012 0.01018 0.00985 0.00985 TOU-8-Sec 0.00503 0.00040 (0.00082) (0.00082) 0.00668 0.00817 0.00978 0.01022 0.01035 0.01046 0.00980 0.00989 0.00995 0.00963 0.00963 TOU-8-Pri 0.00503 0.00039 (0.00081) (0.00081) 0.00652 0.00797 0.00954 0.00997 0.01010 0.01021 0.00956 0.00966 0.00971 0.00940 0.00940 TOU-8-Sub 0.00503 0.00037 (0.00076) (0.00076) 0.00614 0.00751 0.00898 0.00939 0.00951 0.00961 0.00900 0.00909 0.00914 0.00885 0.00885 0.00965 Small AG 0.00503 0.00040 (0.00083) (0.00083) 0.00669 0.00818 0.00979 0.01023 0.01036 0.01047 0.00981 0.00991 0.00997 0.00965 Large AG 0.00503 0.00039 (0.00080) (0.00080) 0.00646 0.00789 0.00944 0.00987 0.00999 0.01010 0.00946 0.00956 0.00961 0.00930 0.00930 St. Lighting 0.00503 0.00036 (0.00076) (0.00076) 0.00611 0.00746 0.00893 0.00933 0.00945 0.00956 0.00895 0.00904 0.00909 0.00880 0.00880 Standby - Sec 0.00503 0.00038 (0.00079) (0.00079) 0.00638 0.00779 0.00933 0.00975 0.00987 0.00998 0.00935 0.00944 0.00949 0.00919 0.00919 Standby - Pri 0.00503 0.00039 (0.00080) (0.00080) 0.00648 0.00792 0.00948 0.00991 0.01003 0.01014 0.00950 0.00959 0.00965 0.00934 0.00934 Standby - Sub 0.00503 0.00036 (0.00076) (0.00076) 0.00607 0.00741 0.00887 0.00927 0.00939 0.00949 0.00889 0.00898 0.00903 0.00874 0.00874 Surcharges and Refunds to be Added to PCIA Rates 2018 ERRA Under‐ collection Surcharge 2018 Brown Power True‐Up Refund PCIA 2001 Vintage Rate Group PCIA 2004 Vintage PCIA 2009 Vintage PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage PCIA 2018 Vintage PCIA 2019 Vintage Domestic (0.00101) (0.00101) (0.00127) (0.00142) (0.00158) (0.00155) (0.00180) (0.00204) (0.00219) (0.00251) (0.00251) 0.01388 0.01388 GS-1 (0.00078) (0.00078) (0.00098) (0.00109) (0.00122) (0.00119) (0.00139) (0.00157) (0.00169) (0.00194) (0.00194) 0.01337 0.01337 TC-1 (0.00071) (0.00071) (0.00090) (0.00101) (0.00112) (0.00110) (0.00128) (0.00145) (0.00156) (0.00179) (0.00179) 0.01087 0.01087 GS-2 (0.00079) (0.00079) (0.00099) (0.00111) (0.00124) (0.00121) (0.00141) (0.00160) (0.00172) (0.00197) (0.00197) 0.01242 0.01242 TOU-GS-3 (0.00075) (0.00075) (0.00094) (0.00105) (0.00117) (0.00114) (0.00133) (0.00151) (0.00162) (0.00186) (0.00186) 0.01115 0.01115 TOU-8-Sec (0.00074) (0.00074) (0.00093) (0.00104) (0.00116) (0.00113) (0.00131) (0.00148) (0.00159) (0.00182) (0.00182) 0.01028 0.01028 TOU-8-Pri (0.00072) (0.00072) (0.00091) (0.00102) (0.00114) (0.00112) (0.00130) (0.00147) (0.00158) (0.00181) (0.00181) 0.01010 0.01010 TOU-8-Sub (0.00068) (0.00068) (0.00086) (0.00096) (0.00107) (0.00105) (0.00122) (0.00138) (0.00148) (0.00169) (0.00169) 0.00924 0.00924 TOU-PA-2 (0.00074) (0.00074) (0.00093) (0.00104) (0.00116) (0.00113) (0.00131) (0.00148) (0.00159) (0.00182) (0.00182) 0.01183 0.01183 TOU-PA-3 (0.00071) (0.00071) (0.00089) (0.00099) (0.00110) (0.00108) (0.00126) (0.00143) (0.00154) (0.00177) (0.00177) 0.01025 0.01025 St. Lighting (0.00067) (0.00067) (0.00084) (0.00094) (0.00105) (0.00103) (0.00120) (0.00136) (0.00146) (0.00167) (0.00167) 0.00687 0.00687 Standby - Sec (0.00070) (0.00070) (0.00088) (0.00098) (0.00109) (0.00107) (0.00125) (0.00142) (0.00153) (0.00175) (0.00175) 0.01288 0.01288 Standby - Pri (0.00071) (0.00071) (0.00089) (0.00099) (0.00110) (0.00108) (0.00126) (0.00143) (0.00154) (0.00177) (0.00177) 0.01043 0.01043 Standby - Sub (0.00067) (0.00067) (0.00084) (0.00094) (0.00105) (0.00103) (0.00120) (0.00136) (0.00146) (0.00167) (0.00167) 0.00994 0.00994 PCIA 2018 Vintage PCIA 2019 Vintage Rate Group Domestic GS-1 DWRBC (All Vintages) 1/ 0.00503 CTC (For All Vintages) 0.00055 0.00503 0.00042 Final 2019 CRS Rates PCIA 2001 Vintage PCIA 2004 Vintage PCIA 2009 Vintage PCIA 2010 Vintage PCIA 2011 Vintage PCIA 2012 Vintage PCIA 2013 Vintage PCIA 2014 Vintage PCIA 2015 Vintage PCIA 2016 Vintage PCIA 2017 Vintage (0.00211) (0.00211) 0.00792 0.00981 0.01185 0.01248 0.01241 0.01232 0.01127 0.01108 0.01116 0.02711 0.02711 (0.00165) (0.00165) 0.00611 0.00758 0.00915 0.00965 0.00959 0.00953 0.00871 0.00856 0.00862 0.02359 0.02359 TC-1 0.00503 0.00039 (0.00151) (0.00151) 0.00559 0.00692 0.00837 0.00882 0.00877 0.00871 0.00796 0.00782 0.00787 0.02022 0.02022 GS-2 0.00503 0.00043 (0.00167) (0.00167) 0.00622 0.00770 0.00930 0.00980 0.00974 0.00967 0.00884 0.00870 0.00876 0.02280 0.02280 TOU-GS-3 0.00503 0.00041 (0.00159) (0.00159) 0.00590 0.00731 0.00883 0.00931 0.00926 0.00919 0.00840 0.00826 0.00832 0.02100 0.02100 TOU-8-Sec 0.00503 0.00040 (0.00156) (0.00156) 0.00575 0.00713 0.00862 0.00909 0.00904 0.00898 0.00821 0.00807 0.00813 0.01991 0.01991 TOU-8-Pri 0.00503 0.00039 (0.00153) (0.00153) 0.00561 0.00695 0.00840 0.00885 0.00880 0.00874 0.00798 0.00785 0.00790 0.01950 0.01950 TOU-8-Sub 0.00503 0.00037 (0.00144) (0.00144) 0.00528 0.00655 0.00791 0.00834 0.00829 0.00823 0.00752 0.00740 0.00745 0.01809 0.01809 0.02148 Small AG 0.00503 0.00040 (0.00157) (0.00157) 0.00576 0.00714 0.00863 0.00910 0.00905 0.00899 0.00822 0.00809 0.00815 0.02148 Large AG 0.00503 0.00039 (0.00151) (0.00151) 0.00557 0.00690 0.00834 0.00879 0.00873 0.00867 0.00792 0.00779 0.00784 0.01955 0.01955 St. Lighting 0.00503 0.00036 (0.00143) (0.00143) 0.00527 0.00652 0.00788 0.00830 0.00825 0.00820 0.00749 0.00737 0.00742 0.01567 0.01567 Standby - Sec 0.00503 0.00038 (0.00149) (0.00149) 0.00550 0.00681 0.00824 0.00868 0.00862 0.00856 0.00782 0.00769 0.00774 0.02207 0.02207 Standby - Pri 0.00503 0.00039 (0.00151) (0.00151) 0.00559 0.00693 0.00838 0.00883 0.00877 0.00871 0.00796 0.00782 0.00788 0.01977 0.01977 Standby - Sub 0.00503 0.00036 (0.00143) (0.00143) 0.00523 0.00647 0.00782 0.00824 0.00819 0.00813 0.00743 0.00731 0.00736 0.01868 0.01868
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Attachment C
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October 1, 2019 Billed Revenues Allocation Percentages Table Description Final Rate-PCIA for DL (includes BPTU and ERRA UC), Generation Rate for Bundled Authorized Revenue Requirement ($000) Adopted Forecast kWh Sales (GWh) System Average Rate ($/kWh) $ $ $ 2001 Vintage Customers $ 2004 Vintage Customers $ 2009 Vintage Customers $ 2010 Vintage Customers $ 2011 Vintage Customers $ 2012 Vintage Customers $ 2013 Vintage Customers $ 2014 Vintage Customers $ 2015 Vintage Customers $ 2016 Vintage Customers $ 2017 Vintage Customers $ 2018 Vintage Customers $ 2019 Vintage Customers $ Bundled Service Customers PABA CTCEligible 36,296 $ 80,317 0.00045 $ NA (100% of (0.00175) CTC Revenues) NA (100% of (0.00175) CTC Revenues) NA (100% of 0.00653 CTC Revenues) NA (100% of 0.00809 CTC Revenues) NA (100% of 0.00978 CTC Revenues) NA (100% of 0.01030 CTC Revenues) NA (100% of 0.01025 CTC Revenues) NA (100% of 0.01018 CTC Revenues) NA (100% of 0.00930 CTC Revenues) NA (100% of 0.00915 CTC Revenues) NA (100% of 0.00921 CTC Revenues) NA (100% of 0.02314 CTC Revenues) NA (100% of 0.02314 CTC Revenues) 0.08359 ERRA (Residual energy costs, ERRA (Brown ERRA (Brown resources ERRA Power TruePower TrueUp Cost to (Undercollecti ineligible for PABA 2010 PABA 2011 PABA 2012 PABA 2013 PABA 2014 PABA 2015 PABA 2016 PABA 2017 PABA 2018 PABA 2019 Up Refund to PABA, and on Bundled DL Surcharge) Imputed Service Customers) Costs for Customers) RECs and RA) 594,872 $ 135,060 $ 146,104 $ 40,024 $ 11,894 $ 10,077 $ (60,024) $ 8,859 $ 5,072 $ (29,157) $ $ (15,659) $ 15,659 $ 824,898 3,545,285 Vintage80,317 80,317 80,317 80,317 80,317 80,317 80,317 80,317 80,317 80,317 80,317 59,396 67,520 59,396 Specific 0.00741 $ 0.00168 $ 0.00182 $ 0.00050 $ 0.00015 $ 0.00013 $ (0.00075) $ 0.00011 $ 0.00006 $ (0.00036) $ $ 0.00026 $ 0.01222 $ 0.05969 PABA OneTime Refunds PABA Legacy PABA 2004/Costs DWR Energy UOG 2009 Applicable to Credit All Customers (5,500) $ 80,317 (0.00007) $ (68,585) $ 80,317 (0.00085) $ 3.99% 48.49% 47.51% 3.99% 48.49% 47.51% -1.07% -13.01% 16.69% 113.43% -0.87% -10.51% 13.47% 91.59% 20.77% -0.72% -8.69% 11.15% 75.79% 17.18% 18.62% -0.68% -8.25% 10.58% 71.91% 16.30% 17.66% 4.85% -0.68% -8.30% 10.64% 72.32% 16.40% 17.76% 4.88% 1.46% -0.69% -8.35% 10.71% 72.79% 16.50% 17.88% 4.91% 1.47% 1.28% -0.75% -9.14% 11.72% 79.64% 18.06% 19.56% 5.37% 1.61% 1.40% -8.06% -0.77% -9.29% 11.91% 80.98% 18.36% 19.89% 5.46% 1.64% 1.42% -8.20% 1.20% -0.76% -9.23% 11.83% 80.44% 18.24% 19.76% 5.43% 1.63% 1.41% -8.14% 1.19% 0.65% -0.30% -3.67% 4.71% 32.02% 7.26% 7.87% 2.16% 0.65% 0.56% -3.24% 0.48% 0.26% -1.56% -0.30% -3.67% 4.71% 32.02% 7.26% 7.87% 2.16% 0.65% 0.56% -3.24% 0.48% 0.26% -1.56% 0.00% -1.02% 1.30% 8.86% 2.01% 2.18% 0.60% 0.18% 0.16% -0.90% 0.13% 0.07% -0.43% 0.00% NA (100% of 0.54% DWREC Revenues) 87,895 $ 80,317 0.00109 $ Non-UOGrelated Base Revenue Requirement Balancing Account Items $ (1,295) 59,396 (0.00002) -16.04% -14.46% -13.33% -12.37% -14.48% -16.50% -19.41% -22.62% -22.45% 52.81% 52.81% 0.31% 14.62% 71.41% -0.02%
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