SCE 2019 Rate Update Association of Energy Engineers SoCal meeting January 24, 2019
Estimated 2019 System A Estimated 2019 System Average Rate erage Rate - Bundled Ser undled Servic ice (cent e (cents/kWh) /kWh) | | Rat Rate Le Levels include vels include EITE & Climate Dividend ITE & Climate Dividend Preliminary rate level is estimated based on SCE’s latest forecast and is subject to change based on future CPUC decisions in various proceedings & market Rates expected to increase by ~1% * SCE’s alternate implementation proposal to address a possible delay in its 2019 ERRA implementation due to unsettled issues related to the Power Charge Indifference Adjustment (PCIA) Recent SA Re nt SAR Hi R Histor story January 2015 – 16.2 cents/kWh January 2016 – 15.0 cents/kWh 1 January 2017 – 15.8 cents/kWh
Estimated 2019 rates reflect SCE’s Estimated 2019 Class A Estimated 2019 Class Average Rates erage Rates newly adopted 2018 GRC Phase 2 revenue allocations. - Bundled Ser undled Servic ice (cent e (cents/kWh) /kWh) | | Rat Rate Le Levels exclude vels exclude EITE & Climate Dividend ITE & Climate Dividend Preliminary rate level is estimated based on SCE’s latest forecast and is subject to change based on future CPUC decisions in various proceedings & market 1s 1st Ha Half - - 1s 1st H Half - Jan 201 2018 Jan 201 2018 % Cha % Change 2019 20 19 2019 019 % of SAR % o % o % of S SAR Total R l Residential Resid idential 19.5 19.8 1.6% 116% 118% Small C&I (< 20 kW) TOU-GS-1 17.8 17.6 -0.9% 106% 105% Traffic Control TC-1 19.1 18.9 -0.9% 114% 113% Medium C&I (20 kW - 200 kW) TOU-GS-2 18.1 18.0 -0.9% 108% 107% Medium C&I (200 kW - 500 kW) TOU-GS-3 16.0 15.9 -0.9% 96% 95% Tota tal L Lighti ting/Small/Medium C C&I Total L LSMP 17.5 17.3 -0.9% 105% 103% Large C&I (Sec) TOU-8-SEC 14.2 14.2 -0.3% 85% 84% Large C&I (Pri) TOU-8-PRI 12.9 12.8 -0.3% 77% 76% Large C&I (Sub) TOU-8-SUB 9.0 9.0 -0.3% 54% 53% Total L Larg rge C C&I Total al L Larg rge P Power 12.3 12.3 -0.3% 74% 73% Small Ag & Pump (<200 kW) TOU-PA-2 14.8 14.7 -0.9% 89% 87% Large Ag & Pump ( ≥ 200 kW) TOU-PA-3 12.0 12.2 1.4% 72% 73% Tota tal Ag Ag & & P Pumping Total Ag Ag & & P Pumping 13.6 13.6 0.0% 81% 81% Tota tal S Street & & Ar Area Lighti ting Street Lighti ting 18.5 18.8 1.6% 111% 112% Standby (Sec) TOU-8-SEC-S 14.5 14.4 -0.9% 87% 86% Standby (Pri) TOU-8-PRI-S 13.8 13.7 -0.9% 83% 82% Standby (Sub) TOU-8-SUB-S 9.0 9.0 0.0% 54% 54% Total S Standby dby Total S Standby dby 10.4 10.4 -0.3% 62% 62% TOTAL BU BUND NDLED TOTAL AL BU BUND NDLED 16.7 16.8 0.3% 100% 100% 2
Mar March 1, 2019 “P h 1, 2019 “Pot o ot of Stew Stew” (Not a comprehensive list of all rate change components) 3
New Time-Of New Time-Of-Use (T -Use (TOU) P OU) Periods riods Shif Shifts daily “peak” period to ts daily “peak” period to 4- 4- • 9 9 p.m. (curr p.m. (currently noo ly noon to to 6 6 p.m.) p.m.) Intr Introduc oduces “ es “supe uper o off-peak ak” ” • period fr period from om 8 8 a. a.m. m.-4 p.m. on p.m. on all Winter days all Winter days Intr Introd oduces T es TOU to U to weekend weekend • char charges (curr ges (currently all weekend ly all weekend hour hours ar s are “o e “off ff-peak”) -peak”) Maintains e intains existing s isting seasonal asonal • definitio definitions (Summ (Summer: June- June- Sept; Winter Sept; Winter: Oct Oct-Ma May) y) The Time-of-Use (TOU) peak period applies to “standard” TOU rates defined as follows: TOU-8, TOU-GS-3, TOU-GS-2, TOU-GS-1, TOU-PA-3, & TOU-PA-2. CPP events occur on weekdays and will take place 12 times per year. 27
Part of March 2019 Consolidated Rate 2018 GRC Phase 2 2018 GRC Phase 2 + Other K + Other Key Changes y Changes Change Crit Critical Peak Pric Peak Pricing Economic Development onomic Development Rate te New Rate Options New Rate Options Real Time Prici Real Time Pricing (RT (RTP) (EDR (EDR) (CPP) (CPP) •Option D Option D (replace (replacement ment for for •Overview Overview •Reduce from 5 to 3 summer •Offers a standard 12% Op Option tion B B Base Base Rate) Rate) weekday pricing categories discount – 5 year contract •CPP offers a discount on •Includes the addition of a summer electricity rates in winter mid ‐ peak distribution exchange for higher prices •Introduces year-round Time •200 MW cap TRD (non ‐ holiday weekdays during 12 CPP event days per Related Demand (TRD) only) year between 4 p.m. and 9 charges •Eligible accounts must be ≥ p.m., usually occurring on the •Maintains existing eligibility 150kW non-residential, non- hottest summer days requirements government accounts (max of 20 customers can participate •Default Default •Option E* Option E* (replaceme (replacement nt for for w/loads less than 150kW) Options Options A A & R Optiona & R Optional Rates) Rates) •Applies to all General Service and Large Ag & Pump •Includes a new generation TRD customers; departing load charge in the summer on ‐ peak customers not eligible and winter mid ‐ peak (non ‐ holiday weekdays only) •Default to begin Mar. 2019 for all eligible accounts; annual •Customers w/ DERs are default will start in October of exempt from Standby if served 2020 for eligible accounts on this rate option thereafter •CPP is an optional rate; there •New Option New Optional Ag Ag & & Pump Pump is a 60-day period to Opt Out Rate Rate of CPP before defaulting •In addition to the 4-9pm standard option, a 5-8pm option will be available * Option E is limited to customers w/ qualifying technologies, including technologies currently eligible for TOU ‐ 8, Options A and R and BTM paired storage (solar+storage) and standalone storage 5
Option E recovers more costs Option D recovers more costs via demand charges via energy charges (tends to benefit higher load factor (tends to benefit lower load factor / DER customers) customers) Energy Demand Option D vs. Option D vs. E (Illu (Illustrative T strative TOU-G U-GS-2 Rate Ex 2 Rate Exam amples) ples) Demand Energy Energy Charge - ¢/kWh Summer On-Peak 10.6 46.4 Summer Mid-Peak 16.0 9.8 Summer Off-Peak 11.0 7.3 Winter Mid-Peak 8.7 14.6 Winter Off-Peak 7.8 8.2 Winter Super-Off-Peak 6.0 7.3 Customer Charge - $/month 125.25 125.25 Facilities Related Demand Charge (FRD) - $/kW 11.41 8.19 Time Related Demand Charge (TRD) - $/kW Summer On-Peak 26.81 3.46 Summer Mid-Peak 0.00 0.00 Winter Mid-Peak 6.98 0.74 Winter Off-Peak 0.00 0.00 40.0 CPP Event Energy Charge - ¢/kWh 40.0 (3.42) (3.42) Summer Non-Event Demand On-Peak Credit - $/kW 6
Rate Plan Comparison T Rate Plan Comparison T ool (RPCT) ool (RPCT) SCE has launched a new tool with • rate analysis results available directly to customers Visit www.sce.com/ratetool and • login with your MyAcount credentials 7
Appendix
Acr Acronyms nyms A = Application F&PP = Fuel and Purchased Power Ag = Agricultural FERC = Federal Energy Regulatory Commission B = Billion GRC = General Rate Case BA = Balancing Account kW = kilowatt BIP = Base Interruptible Program kWh = kilowatt hour BRRBA = Base Revenue Requirement Balancing M = Million Account MPB = Market Price Benchmark (MPB) CARE = California Alternate Rates for Energy MMBtu = Million British Thermal Units CCA = Community Choice Aggregation PCIA = Power Charge Indifference Adjustment C&I = Commercial & Industrial CPP = Critical Peak Pricing RTP = Real Time Pricing CPUC/Commission = California Public Utilities SCE = Southern California Edison Commission SAR = System Average Rate D = Decision SONGS = San Onofre Nuclear Generation Station DA = Direct Access TOU = Time-of-Use DR = Demand Response TRD = Time Related Demand EDR = Economic Development Rate EITE = Emissions Intensive and Trade Exposed ERRA = Energy Resource Recovery Account 9
The “Duck Curve” The “Duck Cur e” Duck‘ Duck‘s N Neck • In the late afternoon / early evening hours, the net load curves quickly ramps up to produce an “arch” similar to the neck of a duck • Ramp (aka flexible generation capacity) is attributed to demand peaks when the sun goes down and solar generation tapers off • As more renewable resources come online, the ramp gets steeper Duck‘ Duck‘s Be Belly • In Spring, the net load curves produce a “belly” appearance in the mid-afternoon • Due to low demand and the influx of renewables, oversupply results which can lead to overgeneration • During oversupply times, wholesale energy prices can be very low and even go negative 23
Part of March 2019 Consolidated Rate Time-o Time-of-Use P -Use Period Change riod Change Change TOU Period eriod Season eason Curr urrent nt New New Weekdays: Weekdays: On-P On-Peak eak Summer 12pm-6pm 4-9pm Weekdays: Weekends: Summer 8am-12pm; 6pm-11pm 4-9pm Mid-Peak Mid-P ak Weekdays: Weekdays and Weekends: Winter 8am-9pm 4-9pm Weekdays: 11pm-8am Weekdays and Weekends: Summer Weekends: All hours All hours except 4-9pm Off-Peak Off ak Weekdays: 9pm-8am Weekdays and Weekends: Winter Weekends: All hours 9pm-8am Weekdays and Weekends: Super Super-Off-Peak Winter N/A 8am-4pm 11
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