December 19, Click on the Regulatory Information link at the bottom right of the page;

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1 Robin Meidhof Senior Attorney Edward Randolph Director of the Energy Division California Public Utilities Commission 505 Van Ness Avenue San Francisco, CA December 19, 2018 Re: R , A et al, and A et al Report of Southern California Edison Company (U 338-E) on Interruptible Load Programs and Demand Response Programs Dear Mr. Randolph: Enclosed is Southern California Edison Company s ( SCE ) Report on Interruptible Load Programs and Demand Response Programs pursuant to Ordering Paragraph No. 39 of Decision This monthly report also contains SCE s emergency activities and expenses in response to the natural gas leak at the Aliso Canyon Storage Facility, in compliance with the Administrative Law Judge s Ruling Granting Southern California Edison Company s Request to Defer Monthly Reporting of Aliso Canyon Activities, dated April 13, 2016 in proceeding R SCE s report, presented in Appendix A, follows the reporting requirements and uses the approved template from Energy Division. It is posted on a publicly available website: Go to Click on the Regulatory Information link at the bottom right of the page; Select CPUC Open Proceedings ; Enter R in the search box; Locate and select the R SCE Monthly ILP and DRP Report links to access associated documents. 2 Very truly yours, /s/ Robin Meidhof Robin Meidhof 1 Ordering Paragraph No. 39 requires PG&E and the other utilities to use a consistent monthly report format approved by Energy Division staff, and provide these monthly reports to the Director of the Commission s Energy Division, with service on the most recent service list in this proceeding. 2 If you have trouble accessing the document using this process, you should be able to find the document using this link: 011&SearchMax=1000&Key1=1&Key2=25. If you still cannot access the documents with this link, please contact Ania Wojtyna-Machon, SCE s CPUC Regulatory Paralegal, at (626) or anna.wojtyna-machon@sce.com. P.O. Box Walnut Grove Ave. Rosemead, California (626) Fax (626)

2 Edward Randolph Director of the Energy Division Page 2 cc: ALJ Kelly Hymes ALJ Nilgun Atamturk Aloke Gupta All Parties of Record in A et al and A et al, and R via Enclosure(s)

3 Appendix A SCE WG2 Monthly Enhanced Report For November 2018

4 Monthly Program Enrollment and Load Impacts (1) Table I 1 SCE Supply Side Demand & Subscription Statistics Program and s 2018 January February March April May June Eligible Accounts Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) as of Jan 1, 2018 Agricultural & Pumping Interruptible (API) 1, , , , , , ,636 Base Interruptible Program (BIP) 15 Minute Option ,457 Base Interruptible Program (BIP) 30 Minute Option ,457 Capacity Bidding Program (CBP) Day Ahead ,870 Capacity Bidding Program (CBP) Day Of ,870 Smart Energy Program (SEP) 48, , , , , , ,800,000 '(4) Summer Discount Plan Program (SDP) Commercial 10, , , , , , ,473 Summer Discount Plan Program (SDP) Residential 246, , , , , , ,169,565 Sub Total 306, , , , , , Critical Peak Pricing (CPP) 3, , , , , , ,921,656 Optional Binding Mandatory Curtailment (OBMC) N/A Real Time Pricing (RTP) (4.1) ,196 Scheduled Load Reduction Program (SLRP) ,008 (5) Sub Total 3, , , , , , Total All Programs 310, , , , , , July August September October November December Eligible Accounts Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) Accounts (2) (3) as of Jan 1, 2018 Agricultural & Pumping Interruptible (API) 1, , , , , ,636 Base Interruptible Program (BIP) 15 Minute Option ,457 Base Interruptible Program (BIP) 30 Minute Option ,457 Capacity Bidding Program (CBP) Day Ahead ,870 Capacity Bidding Program (CBP) Day Of ,870 Smart Energy Program (SEP) 48, , , , , ,800,000 '(4) Summer Discount Plan Program (SDP) Commercial 9, , , , , ,473 Summer Discount Plan Program (SDP) Residential 233, , , , , ,169,565 Sub Total 293, , , , , Critical Peak Pricing (CPP) 3, , , , , ,921,656 Optional Binding Mandatory Curtailment (OBMC) N/A Real Time Pricing (RTP) ,196 Scheduled Load Reduction Program (SLRP) ,008 (5) Sub Total 3, , , , , Total All Programs 297, , , , , (1) Readers should exercise caution in interpreting or using the estimated values found in this report in either the ex post or ex ante columns. Ex post estimates reflects historic event(s) that have taken place during specific time periods and actual weather conditions by a mix of customers that participated on event day(s). Ex ante forecasts account for variables not included in the ex post estimate such as normalized weather conditions, expected customer mix during events, expected time of day which events occur, expected days of the week which events occur, and other lesser effects etc. An ex ante forecast reflects forecast impact estimates that would occur between 1 pm and 6pm during a specific DR program s operating season, based on 1 in 2 (normal) weather conditions. The ex ante and ex post load impacts presented in this report are based on the IOUs' annual April 1st Compliance Filings pursuant to Decision D SCE provides reports to various other agencies (CAISO, FERC, NERC, etc.) which may differ from the load impact estimates in this report but are still based on the June 1st Compliance Filing. The differences are attributed to the use of average values over specific load impact hours and other factors. (2) = The monthly ex ante average load impact per customer; (reported in the annual April 1 DR Load Impact Studies filed in compliance with D , Ordering Paragraph 4), multiplied by the number of currently enrolled service accounts for the reporting month. The ex ante average load impact is the average hourly load impact for an event that would occur from 1 6pm on the system peak day of the month, with the exception of CPP where the average hourly load impacts from 2 6pm are used. Monthly ex ante estimates are indicated only for programs which can be called for events that reporting month. For programs that are not available that month or do not have a positive load impact, a value of zero is reported. SDP Residential is available year round, however, due to no events being called during certain months in previous years, no ex ante data is available. (3) = The monthly ex post average load impact per customer; (reported in the annual April 1 DR Load Impact Studies filed in compliance with D , Ordering Paragraph 4), multiplied by the number of currently enrolled service accounts for the reporting month. The annual ex post average load impact is the average hourly load impact per customer for those customers that may have participated in an event(s) between 1 6pm on event days in the preceding year when or if events occurred. OBMC Load Impacts are based on program year (4) On July 2, 2018 SCE received approval Letter granting establishment of the Smart Energy Program. From January 1 May 31, 2018 this program was known as "Save Power Days", "Save Power Day Incentive Plus", or "PTR ET DLC." (5) Load Impacts are not available for the SLRP, therefore are estimated based on the hour of peak scheduled load reduction multiped by the number of currently enrolled accounts for the reporting month. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 1

5 Program Eligibility and Average Load Impacts Table I 1A Average Load Impact kw / Accounts 2018 Average Load Impact kw / Accounts (1) Eligible January February March April May June July August September October November December Accounts as of Jan 1, 2018 Eligibility Criteria All customers > 37kW or connected load of 50 horsepower or greater on a TOU Agricultural & Pumping Interruptible (API) ,636 Ag & Pump rate Base Interruptible Program (BIP) 15 Minute Option 2, , , , , , , , , , , , ,457 All C & I customers > 200kW Base Interruptible Program (BIP) 30 Minute Option ,457 All C & I customers > 200kW Capacity Bidding Program (CBP) Day Ahead (2) All non residential customers with an IDR or Smart Connect Meter (excluding non residential customers under any streetlight, area Lighting, traffic control or ,870 wireless technology rate) All non residential customers with an IDR or Smart Connect Meter (excluding non residential customers under any streetlight, area Lighting, traffic control or Capacity Bidding Program (CBP) Day Of ,870 wireless technology rate) Smart Energy Program (SEP) All bundled service residential customers with Smart Meters excluding those on rates DM, DMS 1, DMS 2, DMS 3, D S, SDP, DRAM, CPP, any type of Medical 1,800,000 Baseline Allocation. (3) Summer Discount Plan Program (SDP) Commercial All commercial customers with central air conditioning, excluding those on CBP, 474,473 and BIP Summer Discount Plan Program (SDP) Residential All residential customers with Smart Meters excluding those on rates DM, DMS 2,169,565 1, DMS 2, DMS 3, D S, and SPD/PTR ET DLC Critical Peak Pricing (CPP) ,921,656 All bundled service customers with an IDR or Smart Connect Meter Optional Binding Mandatory Curtailment (OBMC) 1, , , , , , , , , , , ,517.0 N/A All non res. customers who can reduce circuit load by 15%. (3) Real Time Pricing (RTP) ,196 All non res. bundled service customers Scheduled Load Reduction Program (SLRP) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 22,008 All non res. bundled service customers >100kW (1) Average Load Impact kw / Customer = Average kw / Customer service account over actual event hours during the 1 6pm window for the preceding year if events occurred omitting 0 and negative load values if program was available, but not dispatched. Some programs may experience no events or few events while other programs may operate regularly depending on event triggers. For existing programs, the Average Load Impact per customer service account remains constant across all months. for OBMC Load Impacts are based on reports filed in 2008 and all remaining ex post values are from the DR Load Impact Studies annual compliance filing on April 1, 2017 (PY2016) for Jan Mar, April 1, 2018 (PY2017) for Apr Dec. (2) CBP Day Ahead value is based on a weighted average of Day Ahead 1 4 Hour and Day Ahead 4 8 Hour Load Impact values. (3) Smart Energy Program (SEP) formerly known as Save Power Days; Save Power Day Incentive Plus or PTR ET DLC. Average Load Impact kw / Accounts (4) Eligible Accounts January February March April May June July August September October November December as of Jan 1, 2018 Eligibility Criteria All customers > 37kW or connected load of 50 horsepower or greater on a TOU Agricultural & Pumping Interruptible (API) ,636 Ag & Pump rate Base Interruptible Program (BIP) 15 Minute Option 2, , , , , , , , , , , , ,457 All C & I customers > 200kW Base Interruptible Program (BIP) 30 Minute Option ,457 All C & I customers > 200kW All non residential customers with an IDR or Smart Connect Meter (excluding non residential customers under any streetlight, area Lighting, traffic control or Capacity Bidding Program (CBP) Day Ahead ,870 wireless technology rate) All non residential customers with an IDR or Smart Connect Meter (excluding non residential customers under any streetlight, area Lighting, traffic control or Capacity Bidding Program (CBP) Day Of ,870 wireless technology rate) Smart Energy Program (SEP) All bundled service residential customers with Smart Meters excluding those on rates DM, DMS 1, DMS 2, DMS 3, D S, SDP, DRAM, CPP, any type of Medical 1,800,000 Baseline Allocation. (5) Summer Discount Plan Program (SDP) Commercial All commercial customers with central air conditioning, excluding those on CBP, 474,473 and BIP Summer Discount Plan Program (SDP) Residential All residential customers with Smart Meters excluding those on rates DM, DMS 2,169,565 1, DMS 2, DMS 3, D S, and SPD/PTR ET DLC Critical Peak Pricing (CPP) ,921,656 All bundled service customers with an IDR or Smart Connect Meter Optional Binding Mandatory Curtailment (OBMC) 1, , , , , , , , , , , ,348.1 N/A All non res. customers who can reduce circuit load by 15%. (6) Real Time Pricing (RTP) ,196 All non res. bundled service customers Scheduled Load Reduction Program (SLRP) N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 22,008 All non res. bundled service customers >100kW (4) Average Load Impact kw/customer = Average kw / Customer, under CAISO 1 in 2 weather conditions, of an event that would occur from 1 6pm on the system peak day of the month, as reported in the DR load impact studies annual compliance filing on April 1, 2017 (PY2016) for Jan Mar, April 1, 2018 (PY2017) for Apr Dec. (5) On July 2, 2018 SCE received approval Letter granting establishment of the Smart Energy Program. From January 1 May 31, 2018 this program was known as "Save Power Days", "Save Power Day Incentive Plus", or "PTR ET DLC." (6) The accounts eligible to participate in OBMC are not available because the number of customers who can reduce 15% of their entire circuit load during every rotating outage cannot be reasonably estimated. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 2

6 Detailed Breakdown of To Date in TA/TI Programs Table I 1B SCE TA/TI and Program Subscription Statistics January February March April May June Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total July August September October November Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total December Activity reflects projects initiated in Customer counts reported on this page are not excluded from counts in the Program tab. s reported on this page are not directly related to reported in the Program tab. AutoDR General Program category Represents identified for service accounts from completed TA. Represents verified/tested for service accounts that participated in Auto DR. Represents verified for service accounts that participated in TI (i.e. must be enrolled in DR) and not in AutoDR; reported here not necessarily amount enrolled in DR. *A reduction in standard TI s can occur when a customer upgrades to (subsequently, the ADR s increase). *Also, if a customer leaves a DR program it will reduce the s for that particular DR program. Represents the sum of verified associated with the service accounts in the TI and programs. Represents of participants in the TA stage and may include participants who have completed TI and Auto DR. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 3

7 Detailed Breakdown of To Date in TA/TI Programs Table I 1B SCE TA/TI and Program Subscription Statistics January February March April May June Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total July August September October November Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total December Activity reflects projects initiated in Customer counts reported on this page are not excluded from counts in the Program tab. s reported on this page are not directly related to reported in the Program tab. AutoDR General Program category Represents identified for service accounts from completed TA. Represents verified/tested for service accounts that participated in Auto DR. Represents verified for service accounts that participated in TI (i.e. must be enrolled in DR) and not in AutoDR; reported here not necessarily amount enrolled in DR. *A reduction in standard TI s can occur when a customer upgrades to (subsequently, the ADR s increase). *Also, if a customer leaves a DR program it will reduce the s for that particular DR program. Represents the sum of verified associated with the service accounts in the TI and programs. Represents of participants in the TA stage and may include participants who have completed TI and Auto DR. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 4

8 Detailed Breakdown of To Date in TA/TI Programs Table I 1B SCE TA/TI and Program Subscription Statistics January February March April May June Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total July August September October November December Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total Activity reflects projects initiated in Customer counts reported on this page are not excluded from counts in the Program tab. s reported on this page are not directly related to reported in the Program tab. AutoDR General Program category Represents identified for service accounts from completed TA. Represents verified/tested for service accounts that participated in Auto DR. Represents verified for service accounts that participated in TI (i.e. must be enrolled in DR) and not in AutoDR; reported here not necessarily amount enrolled in DR. *A reduction in standard TI s can occur when a customer upgrades to (subsequently, the ADR s increase). *Also, if a customer leaves a DR program it will reduce the s for that particular DR program. Represents the sum of verified associated with the service accounts in the TI and programs. Represents of participants in the TA stage and may include participants who have completed TI and Auto DR. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 5

9 Detailed Breakdown of To Date in TA/TI Programs Table I 1B SCE TA/TI and Program Subscription Statistics January February March April May June Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total July August September October November Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total December Activity reflects projects initiated in 2017 Customer counts reported on this page are not excluded from counts in the Program tab. s reported on this page are not directly related to reported in the Program tab. AutoDR General Program category Represents identified for service accounts from completed TA. Represents verified/tested for service accounts that participated in Auto DR. Represents verified for service accounts that participated in TI (i.e. must be enrolled in DR) and not in AutoDR; reported here not necessarily amount enrolled in DR. *A reduction in standard TI s can occur when a customer upgrades to (subsequently, the ADR s increase). *Also, if a customer leaves a DR program it will reduce the s for that particular DR program. Represents the sum of verified associated with the service accounts in the TI and programs. Represents of participants in the TA stage and may include participants who have completed TI and Auto DR. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 6

10 Detailed Breakdown of To Date in TA/TI Programs Table I 1B SCE TA/TI and Program Subscription Statistics January February March April May June Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total July August September October November Agricultural & Pumping Interruptible (API) Base Interruptible Program (BIP) Capacity Bidding Program (CBP) Summer Discount Plan Program (SDP) Sub Total Critical Peak Pricing (CPP) Optional Binding Mandatory Curtailment (OBMC) Real Time Pricing (RTP) Scheduled Load Reduction Program (SLRP) Sub Total General Program funded by TA Program funded by or TI but not enrolled in a Supply Side or Load Modifying DR Program Total December Activity reflects projects initiated in 2018 Customer counts reported on this page are not excluded from counts in the Program tab. s reported on this page are not directly related to reported in the Program tab. AutoDR General Program category Represents identified for service accounts from completed TA. Represents verified/tested for service accounts that participated in Auto DR. Represents verified for service accounts that participated in TI (i.e. must be enrolled in DR) and not in AutoDR; reported here not necessarily amount enrolled in DR. *A reduction in standard TI s can occur when a customer upgrades to (subsequently, the ADR s increase). *Also, if a customer leaves a DR program it will reduce the s for that particular DR program. Represents the sum of verified associated with the service accounts in the TI and programs. Represents of participants in the TA stage and may include participants who have completed TI and Auto DR. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 7

11 Table I 2 SCE Demand Response Programs and Activities Expenditures and Funding 2018 Southern California Edison Year to Date Program Expenditures 2018 Expenditures (1) Program to Date Year to Date 2018 Total Expenditures 5 Year Funding Fundshift Percent Cost Item January February March April May June July August September October November December Expenditures Year to Date 2018 Incentives (2) Adjustments Funding Category 1 : Agricultural & Pumping Interruptible (API) $25,804 $22,923 $26,360 $22,671 $19,911 $134,266 $80,214 ($35,799) $3,234 $27,790 $22,219 $349,591 $5,617,977 $5,967,568 $35,341,929 17% Base Interruptible Program (BIP) $15,907 $13,407 $13,512 $11,612 $15,704 $15,661 $11,379 $14,749 $6,439 $17,034 $16,213 $151,616 $75,768,438 $75,920,053 $347,473,792 22% Capacity Bidding Program (CBP) $11,398 $11,258 $12,384 $12,649 $13,897 $10,031 $8,632 $10,577 $7,922 $7,920 $6,257 $112,924 $459,577 $572,501 $15,029,045 4% Smart Energy Program (SEP) '(3) $261,853 $199,288 $185,678 $142,072 $326,162 $102,260 $26,062 $246,820 $22,105 $23,524 $22,255 $1,558,080 $1,349,082 $2,907,162 $20,431,092 14% Summer Discount Plan Program (SDP) $85,525 $115,066 $165,709 $216,954 $266,000 $488,981 $460,794 $591,026 $486,595 $351,561 $229,808 $3,458,020 $47,174,933 $50,632,953 $220,058,357 23% Category 1 Total $400,487 $361,942 $403,644 $405,956 $641,674 $751,199 $587,081 $827,373 $526,295 $427,829 $296,752 $0 $5,630,232 $130,370,006 $136,000,237 $638,334,215 21% Category 2 : Optional Binding Mandatory Curtailment (OBMC) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $15,000 0% Rotating Outages $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $400,000 0% Scheduled Load Reduction Program (SLRP) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $15,625 0% Category 2 Total $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $430,625 0% Category 3 : Demand Response Auction Mechanism (DRAM) and Direct Participation Electric Rule 24 Demand Response Auction Mechanism (DRAM) (4) $143,380 $146,620 $230,626 $214,898 $298,373 $474,181 $317,030 $622,313 $368,027 $63,754 ($50,792) $2,828,409 $2,828,409 $6,000,000 47% Category 3 Total $143,380 $146,620 $230,626 $214,898 $298,373 $474,181 $317,030 $622,313 $368,027 $63,754 ($50,792) $0 $2,828,409 $0 $2,828,409 $6,000,000 47% Category 4 : Emerging Markets & Technology Emerging Markets and Technology $39,974 $100,589 $84,824 $74,456 $159,085 $88,297 $150,801 $133,040 $78,067 $218,677 $125,483 $1,253,291 $1,253,291 $14,610,000 9% Technology Incentive Program (AutoDR TI) $71,353 $76,803 $90,274 $91,115 $118,277 $136,034 $265,459 $348,757 $1,093,498 $241,448 $94,552 $2,627,571 $2,627,571 $43,639,325 6% Category 4 Total $111,328 $177,392 $175,098 $165,570 $277,362 $224,332 $416,260 $481,796 $1,171,564 $460,125 $220,035 $0 $3,880,862 $0 $3,880,862 $58,249,325 7% Category 5 : Pilots CBP Residential Pilot $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,005,000 0% Charge Ready Pilot $6,122 $6,246 $7,137 $5,093 $6,066 $14,837 $11,853 $7,074 $10,112 $13,543 $9,965 $98,049 $98,049 $429,953 23% Constrained Local Capacity Planning Areas & Disadvantaged Communities Pilot $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,000,000 0% Category 5 Total $6,122 $6,246 $7,137 $5,093 $6,066 $14,837 $11,853 $7,074 $10,112 $13,543 $9,965 $0 $98,049 $0 $98,049 $2,434,953 4% Category 6 : Marketing, Education, and Outreach (ME&O) (5) Other Local Marketing $4,825 $10,661 $74,652 $71,257 $639,974 $325,256 $226,062 $29,546 $75,710 $7,817 $78,049 $1,543,809 $1,543,809 $14,276,950 11% Statewide ME&O $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $1,798,101 Category 6 Total $4,825 $10,661 $74,652 $71,257 $639,974 $325,256 $226,062 $29,546 $75,710 $7,817 $78,049 $0 $1,543,809 $0 $1,543,809 $16,075,051 10% Category 7 : Portfolio Support (includes EM&V, System Support, and Notifications) DR Potential Study $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $2,000,000 0% DR Systems & Technology Support $166,222 $421,145 $51,219 $431,409 $596,151 $710,754 $215,120 $221,755 $449,786 $136,063 $227,220 $3,626,845 $3,626,845 $29,210,482 12% Evaluation, Measurement & Verification (EM&V) $16,232 $17,143 $20,804 $19,026 $15,546 $27,783 $20,918 $20,535 $18,751 $19,518 $22,617 $218,873 $218,873 $6,090,136 4% Category 7 Total $182,454 $438,288 $72,023 $450,435 $611,697 $738,537 $236,039 $242,290 $468,538 $155,581 $249,837 $0 $3,845,718 $0 $3,845,718 $37,300,618 10% Integrated Programs and Activities (6) IDSM Non Residential $56,413 $136,065 $59,908 $124,913 $23,678 $71,612 $114,215 $52,473 $128,168 $72,199 $64,219 $903,861 $903,861 $42,650,000 2% IDSM Residential $4,133 $4,452 $6,348 $6,414 $5,243 $6,662 $4,610 $5,124 $5,187 $6,446 $4,566 $59,184 $59,184 $5,000,000 1% Integrated Programs and Activities Total $60,546 $140,517 $66,256 $131,326 $28,921 $78,273 $118,824 $57,597 $133,355 $78,645 $68,786 $0 $963,046 $0 $963,046 $47,650,000 2% Total Incremental Cost $909,140 $1,281,665 $1,029,436 $1,444,535 $2,504,067 $2,606,615 $1,913,149 $2,267,989 $2,753,601 $1,207,293 $872,631 $0 $18,790,123 $130,370,006 $149,160,129 $806,474,787 18% Technology Incentives (AutoDR TI) commitments outstanding as of 11/30/2018 $ 54,610 Permanent Load Shift (PLS) Commitments outstanding as of 11/30/2018 $ (1) Funding for DR programs and activities are approved in D and recorded in SCE's Demand Response Program Balancing Account (DRPBA) unless otherwise noted. (2) Incentives are for programs in Category 1 only. (3) On July 2, 2018 SCE received approval Letter granting establishment of the Smart Energy Program. From January 1 May 31, 2018 this program was known as "Save Power Days", "Save Power Day Incentive Plus", or "PTR ET DLC." (4) DRAM activities are approved in D and are settled in BRRBA. Expenditures represent Resource Adequacy (RA) payments to demand response providers (DRP) based on the Demonstrated Capacity for each applicable Showing (Delivery) Month, in the month that the payments were paid. Payments are calculated as the product of the Contract Price of the RA Product and Demonstrated Capacity (kw) as defined in the DRAM Purchase Agreement, Section 1.6. (5) Funding for Statewide ME&O is based on SCE Advice Letter 3677 E and recorded to the SWMEOBA (6) Integrated Programs and Activities section was updated in July 2018 to align with the funding approved SCE's EE Rolling Portfolio Business Plan for in D and resulted in the consolidation of 11 activities to 2. In order to align with the DR program cycle defined in D , only funding through 2022 is included. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 8

12 Table I 2A SCE Demand Response Programs and Activities Carry Over Expenditures and Funding 2018 Southern California Edison Year to Date Program Expenditures 2018 Expenditures (1) (5) Year to Date 2018 Cost Item January (2) February March April May June July August September October November December Expenditures Category 1 : Reliability Programs Agricultural Pumping Interruptible (API) $328 $6,976 $400 ($39) $1,277 ($768) $4 $90 $56 ($62) ($7) $8,255 Base Interruptible Program (BIP) $725 $2,268 $154 $46 $117 ($1,198) ($17) $140 $87 ($97) ($11) $2,214 Optional Binding Mandatory Curtailment (OBMC) ($0) $0 $0 $1 $0 $0 $0 $1 $1 $0 $0 $4 Rotating Outages (RO) $70 $74 $53 ($8) $67 ($151) ($0) $21 $13 ($16) ($2) $120 Scheduled Load Reduction Program (SLRP) ($3) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 ($3) Category 1 Total $1,120 $9,318 $608 $0 $1,462 ($2,117) ($13) $251 $156 ($175) ($20) $0 $10,590 Category 2 : Price Responsive Programs AC Cycling : Summer Discount Plan (SDP) $232,684 $15,294 ($14,518) $4,702 $10,586 ($39,016) ($13,083) $10,492 $4,119 $2,665 $2,275 $216,200 Capacity Bidding Program (CBP) $588 $157 $115 $13 $32 ($331) $2 $39 $24 ($27) ($3) $609 Demand Bidding Program (DBP) $785 $721 $258 $315 $72 ($742) $4 $86 $53 ($60) ($7) $1,485 Save Power Day (SPD/PTR) $844,577 ($5,761) ($766,306) $252,533 ($71,958) $94,117 $12,914 ($110) $3,706 $854,626 ($718,199) $500,140 Category 2 Total $1,078,634 $10,411 ($780,451) $257,564 ($61,268) $54,028 ($163) $10,507 $7,902 $857,205 ($715,934) $0 $718,434 Category 3 : DR Provider/Aggregated Managed Programs (3) AMP Contracts/DR Contracts (AMP) ($7) $23 $50,749 $47 $21 $5, $19 $200,223 $34 $184,048 $1 $440,961 Demand Response Auction Mechanism (DRAM) $26,244 $200,050 $3,532 $6,482 $0 ($53,045) $0 $0 $0 $0 $0 $183,264 Category 3 Total $26,238 $200,073 $54,281 $6,529 $21 ($47,242) $19 $200,223 $34 $184,048 $1 $0 $624,225 Category 4 : Emerging & Enabling Technologies / Technology Incentives (AutoDR TI) $26,483 $52,134 ($560,307) $35,147 $2,081 ($12,660) ($836) $1,879 $8,091 $43,268 ($196) ($404,917) Emerging Markets & Technologies $5,386 $106,677 $30,599 $252,671 $328,661 $195,685 $205,288 $323,307 $366,262 $128,638 $40,580 $1,983,753 Category 4 Total $31,868 $158,810 ($529,708) $287,818 $330,742 $183,025 $204,452 $325,187 $374,353 $171,906 $40,384 $0 $1,578,836 Category 5 : Pilots Over Generation Pilot Program $0 $0 $0 $0 $0 $0 $0 $142,107 $0 $55,137 $2,232 $199,476 Category 5 Total $0 $0 $0 $0 $0 $0 $0 $142,107 $0 $55,137 $2,232 $0 $199,476 Category 6 : Evaluation, Measurement and Verification DR Research Studies (CPUC) $0 $0 $0 $0 $36,845 $23,210 $0 $2,315 $0 $0 $0 $62,370 Measurement and Evaluation $39,978 $8,279 $4,528 $15,632 $5,552 ($3,279) $38,095 $289 $21,122 $42,536 $339,888 $512,617 Category 6 Total $39,978 $8,279 $4,528 $15,632 $42,396 $19,931 $38,095 $2,604 $21,122 $42,536 $339,888 $0 $574,987 Category 7 : Marketing, Education & Outreach (4) Circuit Savers Program ($0) ($0) $0 $0 $0 $0 $0 $0 $0 $0 $0 ($0) Statewide ME&O $136,537 $62,274 $260,921 $653,462 $128,459 $123,183 ($54,736) $137,248 $136,887 $478,824 $299,273 $2,362,332 Other Local Marketing $41,573 ($50,122) $2,083 $549 ($2,083) $0 ($549) ($7,019) $0 $0 $0 ($15,569) Category 7 Total $178,110 $12,151 $263,005 $654,011 $126,376 $123,183 ($55,285) $130,229 $136,887 $478,824 $299,273 $0 $2,346,763 Category 8 : DR System Support Activities DR Systems & Technology (S&T) $10,464 $7,854 ($6,669) ($21,238) $714 ($9,020) ($105) $928 $1,645 $19,807 $2,662 $7,041 DR Rule 24 $17,377 $35,731 $36,161 $28,567 ($5,004) $66,762 $39,290 $15,290 $18,083 $24,943 $66,751 $343,951 Category 8 Total $27,841 $43,585 $29,492 $7,329 ($4,290) $57,742 $39,184 $16,218 $19,728 $44,749 $69,413 $0 $350,992 Category 9 : Integrated Programs and Activities (Including Technical Assistance) Commercial New Construction ($201) $111 ($50,003) $831 $21 ($278) $1,562 $8 $0 $22,390 $0 ($25,559) DR Energy Leadership Partnership (ELP) $708 $282 $165 ($62) $50 ($656) ($9) $59 $26 ($53) ($7) $504 DR Institutional Partnership ($284) ($54) $165 ($48) ($708) ($510) ($6) $45 $1,032 $1,294 ($493) $434 DR Technology Resource Incubator Program (TRIO) $84 $81 $59 ($17) $14 $10,870 ($2) $16 $7 ($15) ($2) $11,095 Federal Power Reserve Partnership (FedPower) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 IDSM Continuous Energy Improvement $92 $89 $65 ($19) $15 ($200) ($3) $18 $8 ($16) ($2) $47 IDSM Food Processing Pilot ($0) $0 $0 $0 $0 $582 $0 $0 $0 $0 $0 $582 Integrated DSM Marketing $9,169 ($7,130) $772 ($215) $1,109 ($2,223) $407 $202 $89 $180 ($141) $2,220 RCx Initiative $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 Residential New Construction Pilot $50 $49 $35 ($10) $8 ($109) ($1) $10 $4 ($9) ($1) $25 Statewide IDSM ($8,823) ($5,770) $5,328 $5,323 $6,595 $175 $0 ($113,986) $0 $19,894 ($19,894) ($111,159) Technical Assistance (TA) ($142) $700 $323 ($48) $91 ($930) $5 $108 $67 ($75) ($9) $91 Third Party Programs $716 $730 $535 ($79) $150 ($1,537) $8 $180 $111 ($125) ($14) $675 Upstream w/hvac $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 Workforce Education & Training Smart Students (SmartStudents) $349 $356 $261 ($39) $73 ($751) $4 $87 $54 ($61) ($7) $328 Category 9 Total $1,718 ($10,553) ($42,296) $5,618 $7,418 $4,433 $1,964 ($113,253) $1,399 $43,406 ($20,569) $0 ($120,717) Category 10 Special Projects Permanent Load Shift $5,442 $5,603 $706,865 $1,769 $22,422 $606,564 $1,816 $3,745 $2,668 $1,108 $1,853 $1,359,857 Category 10 Total $5,442 $5,603 $706,865 $1,769 $22,422 $606,564 $1,816 $3,745 $2,668 $1,108 $1,853 $0 $1,359,857 Programs Support Costs $17,456 $302 $25,327 ($7,866) ($63,008) $1,269 $98 $572 ($253) $128 $919 ($25,056) Total Incremental Cost $1,408,404 $437,980 ($268,348) $1,228,403 $402,270 $1,000,815 $230,166 $718,388 $563,996 $1,878,873 $17,440 $0 $7,618,386 Technology Incentives (AutoDR TI) commitments outstanding as $ 2,139,459 of 11/30/2018 Permanent Load Shift (PLS) Commitments outstanding as of 11/30/2018 $ 3,016,300 (1) Carryover program costs, for funding cycles prior to 2018, are reported here and are recorded in SCE's Demand Response Program Balancing Account (DRPBA), unless otherwise noted. SCE seeks Commission authorization to carryover program costs in its ERRA proceeding. (2) Negative expenses in January are a result of reversed accrual entries. (3) Category 3 expenses are recorded to BRRBA and/or PAACBA (4) Statewide ME&O expenses are recorded to the SWMEOBA (5) Expenses may include costs recorded to Aliso Canyon Demand Response Program Balancing Account (ACDRPBA) SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 9

13 Annual Total Cost Table I 3 SCE Demand Response Programs Customer Program Incentives 2018 Total Embedded Cost and Revenues (1) Cost Item January February March April May June July August September October November December Year to Date Total Cost Program Incentives Agricultural Pumping Interruptible (API) (2) $46,015 $37,159 $67,264 $54,322 $80,081 $579,261 $1,335,400 $1,456,326 $1,152,303 $707,425 $102,421 $5,617,977 Base Interruptible Program (BIP) (2) $841,787 $752,452 $859,018 $807,437 $828,164 $3,969,315 $18,461,640 $20,873,888 $15,195,492 $12,640,473 $538,772 $75,768,438 Capacity Bidding Program (CBP) (3) $0 $2,601 $2,601 $3,181 $24,187 $44,860 $131,149 $184,047 $62,671 $4,279 Pending $459,577 Demand Bidding Program (DBP) (4) $377,874 $379 $0 $0 $0 $0 $0 $0 $0 $0 $0 $378,253 AMP Contracts/DR Contracts (AMP) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 Smart Energy Program (SEP) (5) $15,749 $12,833 $13,997 $13,961 $13,284 $14,474 $10,360 $541,485 $415,141 $279,909 $17,889 $1,349,082 Summer Discount Plan Program (SDP) Commercial $5,952 ($146) $5,304 $6,274 ($2,266) $1,414,191 $3,060,496 $3,649,992 $3,006,654 $1,858,435 $6,294 $13,011,179 Summer Discount Plan Program (SDP) Residential $255,444 $201,262 $262,247 $252,721 $231,255 $4,124,527 $8,172,188 $8,557,056 $7,182,910 $4,168,603 $169,057 $33,577,268 Summer Discount Plan Program (SDP) Residential O Switch $6,920 $4,901 $4,252 $5,391 $4,717 $69,788 $138,082 $147,211 $126,955 $75,007 $3,262 $586,485 Total Cost of Incentives $1,549,740 $1,011,441 $1,214,682 $1,143,287 $1,179,421 $10,216,417 $31,309,316 $35,410,004 $27,142,126 $19,734,130 $837,695 $0 $130,748,259 Revenues from Excess Energy Charges (6) $0 $0 $0 $0 $0 $0 $0 $0 $69,954 $2,429,310 $9,712 $2,508,976 (1) Amounts reported are for incentives costs that recovered in the Demand Response Program Balancing Account (DRPBA). (2) BIP and API shown here represent the amount of incentives paid to all enrolled service accounts based on the month in which incentives were paid by the utility and not necessarily based on the month in which they were earned. BIP is net of incentives and Excess Energy Charges. (3) CBP incentives represents the net amount of capacity and any applicable energy payments issued to participating aggregators. Amounts are based upon settlement and actual performance. "Pending" indicates settlements for that operating month have either not been completed or are being processed by SCE's DRP Credit. (4) DBP incentives shown here represent the amount of incentives paid to program participants based on the month in which incentives were paid by the utility and not based on the month in which they were earned by participating customers. (5) On July 2, 2018 SCE received approval Letter granting establishment of the Smart Energy Program. From January 1 May 31, 2018 this program was known as "Save Power Days", "Save Power Day Incentive Plus", or "PTR ET DLC." (6) Revenues from Excess Energy Charges, assessed by BIP participants, are for failure to reduce load when requested during curtailment events. SCE ILP and DRP Report for November 2018_Final.xlsx - PUBLIC - A 10