1 Item 3: Authorize the Chief Executive Officer to
Execute Two Power Purchase Agreements with
SunZia Wind South LLC and SunZia Wind North
LLC
SVCE Board Meeting
May 14, 2025
Item 3
PRESENTATION
2 Request
Authorize the Chief Executive Officer to execute two agreements with SunZia Wind South LLC and SunZia Wind North LLC for the procurement of renewable wind energy in substantial form and any necessary ancillary agreements and documents as follows:
1. SunZia Wind South LLC
a. 17.25 MW or approximately 55,000 MWh per year
b. 10-Year term PPA with expected commercial operation dates (COD) and term from June 1, 2026, through May 31, 2036.
c. Total amount not-to-exceed $58,000,000.
2. SunZia Wind North LLC
a. 7.75 MW or approximately 25,000 MWh per year
b. 10-Year term PPA with expected COD and term from June 1, 2026, through May 31, 2036. c. Total amount not-to-exceed $26,000,000.
Item 3
PRESENTATION
3 Executed Long-Term PPAs
• 9 PPAs Online
• 625.3 MW of
nameplate capacity
online
• 1,627.93 MW of
nameplate capacity
executed
• 75% RPS expected in
2030
SVCE has 9 of its 22 PPAs
online Seller Project Name Technology
Generation
MW Storage MW
Storage
MWh
% of Annual
Load in
2030
Term
(years)
SVCE Board
Approval Status
1 MN8 Slate Solar + Storage 93 46.5 186 6.2% 17 Oct-18 Online 2 Ormat Casa Diablo Geothermal 7 1.4% 10 Feb-20 Online
3 Atlantica Coso Geothermal 43.8 6.1% 15 Mar-20 Online
4 Leeward Rabbitbrush Solar + Storage 40 8 20 2.9% 15 Apr-20 Online 5 NextEra Yellow Pine Solar + Storage 50 26 104 3.8% 20 May-20 Online 6 AES Mountain View Wind 33.3 3.1% 20 Apr-21 Online
7 Clearway Victory Pass Solar + Storage 100 25 100 7.6% 15 May-21 Online 8 Terra-Gen Cameron Crest Wind 77.7 4.6% 15 May-21 Online 9 AES Baldy Mesa (RA-only) Storage 0 75 300 10 Sep-22 Online 10 Avantus Aratina Solar + Storage 80 50 200 6.3% 20 Jun-20 Pre-construction 11 174 Power Global Atlas Solar 50 3.6% 10 Jan-21 Pre-construction 12 SB Energy Angela Solar + Storage 20 10 40 1.4% 15 Mar-21 Pre-construction 13 Origis San Luis West Solar + Storage 62.5 15.625 62.5 3.9% 15 Apr-21 Pre-construction 14 Rev Renewables Tumbleed Long Duration Storage 15.9375 127.5 15 Feb-22 Construction 15 Onward Goal Line Long Duration Storage 14.2 113.6 15 Mar-22 Pre-construction 16 Ormat Geothermal Portfolio Geothermal 16.75 4.2% 20 Jun-22 Pre-construction 17 OME Fish Lake Geothermal 1.82 0.4% 20 Jun-22 Pre-construction 18 Middle River Power Hanford Thermal + BESS 99.4 131.4 131.4 12 Apr-23 Construction 19 NextEra Grace Solar 120 8.3% 15 Aug-23 Pre-construction 20 NextEra Yellow Pine III Storage 0 115 460 15 Aug-23 Pre-construction 21 Pattern SunZia Wind 100 7.6% 15 Nov-23 Construction
22 VCI Energy Glossy Garlic Solar + Storage 50 50 200 4.0% 10 Oct-24 Pre-construction Item 3
PRESENTATION
4 Summer 2024 Procurement Efforts
SVCE Procurement Goals:
• Renewable Portfolio Standard
(RPS)
• Integrated Resource Plan
(IRP) GHG Reductions
• Mid-term Reliability (MTR)
Procurement Order
• Portfolio Diversity
• Technology
• Geography
• Resource Adequacy
• Carbon Free Energy &
Standalone Storage Projects
• Term: minimum 10 years
June 2024
• Issued RFO – seeking
diverse RPS & MTR
Resources
Shortlisted
• Incremental SunZia
offering Shortlisted
Item 3
PRESENTATION
5 SunZia Wind
3,515 MW Wind park in New Mexico
• Connects to the Pinal Central
Substation using the SunZia
Transmission line
• From Pinal the resource will connect
with CAISO at Palo Verde
• Several off-takers, including SVCE’s
existing 100 MW contracted share
• SVCE’s proposed incremental share is
25 MW across two contracts
Item 3
PRESENTATION
6 SunZia Wind South LLC and SunZia Wind North LLC
• Together would meet 2%
of SVCE’s retail sales
• IRP GHG reduction target
• 75% RPS by 2030
• SB100 Clean Energy target
of 100% by 2045
• Meets long-term RPS
requirements
• Supports GreenStart and
GreenPrime
• Provides 8.75 MW of MTR
capacity
• Provides Resource
Adequacy
• Pattern Energy, Inc. Developer /
Parent Company
• 25 MW New Wind
• 80 GWh, PCC1 Renewable Energy
•MTR and RA countable
Product &
Attributes
• SunZia Wind PowerCo LLC
•Torrance, Lincoln and San Miguel Counties in New Mexico Project Name &
Location
• 10-year, Mid 2026 Expected Delivery
Term Start
• Fixed price ($/MWh) for Metered Energy. No Escalator. Contract Price Structure
Item 3
PRESENTATION
7 Annual RPS Progress
Incremental SunZia Wind
will help SVCE meet
ongoing SB100 RPS
requirements as well as
SVCE’s Agency RPS
target that climbs to 75%
in 2030
SB100 Carbon Neutral
targets per SB 1020
60% by 2030
90% by 2035
95% by 2040
100% by 2045
Item 3
PRESENTATION
SVCE Clean and RPS Positionwith IncrementalSunZia Volumes RPS % mill RPS % with incr.Sunzia ^^■Clean% State RPS target “■■““Agency RPS target 8 Compliance with Long-Term RPS
Procurement Mandate
• SB350 requires 65% of
RPS to come from long-term (>=10 years)
contracts
• Incremental SunZia
Wind adds to
Compliance Periods 5
and 6 obligations
CP #5
2025-2027
CP #6
2028-2030
1. State Mandated RPS per Compliance Period - % of Retail Sales 50% 57%
2. State Mandated % of Mandated RPS (Row #1) to be
Contracted Under RPS Long-term Contracts 65% 65%
3. State Mandated % of Retail Sales with RPS Long-Term
Contracts (Row 2 * Row 1) 33% 37%
4. SVCE: Current Compliance with Row #3: Existing RPS
Achieved with Long-term Contracts 58.05% 71.81%
5. SVCE: RPS Achieved with incremental SunZia agreements 59.04% 73.68% Open Position relative to State Mandate (Row #3)
+Above / (-) Short 26.04% 36.68%
Item 3
PRESENTATION
9 Energy and Reliability Portfolio
SunZia Wind increases
Clean Energy from
Wind by 2%
SunZia Wind increases
Clean RA Capacity by
2%
Sunzia Wind provides
8.75 MW of MTR
eligible capacity in
2026
SunZia Wind will
increase clean energy
and capacity
Item 3
PRESENTATION
Estimated for 2028 AnnualEnergy
(GWh)
Energy Source as a
Percent of TataI
RetailSales
Capacity Source asa
Percent of Total RA
Requirement
Biomass 0 0% 0%
GeothermaL 378 9% 22%
Solar lh835 44% 11%
Wind with SunZia 713 17% 10%
Large Hydroelectric 1,130 27% 0%
Battery Storage 0 0% 9%
NaturalGas RA-only 0 0% 33%
Hanford - Natural Gas 70 2% 15%
Total 4,126 100% 100%
10 Summary
SunZia Wind South LLC and SunZia Wind North LLC diversify SVCE’s portfolio while meeting clean objectives
• Contribute an additional 2% of RPS-eligible energy on an annual basis
• Help meet clean energy goals, SB 100, SB 350 and SB 1020 • Reduce GHG emissions
• Can provide Resource Adequacy capacity
• Can provide MTR attributes for 2026 and beyond
• Provides geographic and technology-based diversity to SVCE’s Portfolio
• Provides net positive portfolio value
Item 3
PRESENTATION
11 Request
Authorize the Chief Executive Officer to execute two agreements with SunZia Wind South LLC and SunZia Wind North LLC for the procurement of renewable wind energy in substantial form and any necessary ancillary agreements and documents as follows:
1. SunZia Wind South LLC
a. 17.25 MW or approximately 55,000 MWh per year
b. 10-Year term PPA with expected commercial operation dates (COD) and term from June 1, 2026, through May 31, 2036.
c. Total amount not-to-exceed $58,000,000.
2. SunZia Wind North LLC
a. 7.75 MW or approximately 25,000 MWh per year
b. 10-Year term PPA with expected COD and term from June 1, 2026, through May 31, 2036. c. Total amount not-to-exceed $26,000,000.
Item 3
PRESENTATION
• Subtitle
New SV Clean Energy
PowerPoint Template
Item 4
PRESENTATION
J VALLEY
ENERGY
Customer Demand Flexibility Services
Main Services Agreement with Lunar
Energy
SVCE Board of Directors Meeting
May 14, 2025
•
•
o
Item 4
PRESENTATION
fr) Improving ‘Demand Flexibility* enables better alignment of demand with supply - and supports SVCE’s mission.
Clean
Affordable Reliable
Purpose of today’s presentation:
Review needs, opportunities, and goals for expanding
Demand Flexibility in SVCE’s service area
In support of SVCE’s Demand Flexibility goals, authorize CEO to negotiate and execute an agreement with Lunar
Energy, for:
Distributed Energy Resource Management (DERMS)
software platform, and related services
•
•
•
•
Item 4
PRESENTATION
Value of Demand Flexibility: "Energy Duck Curve"
Opportunity Statement
Devices in SVCE Service territory can shift usage
to cleaner, lower-cost (sunny) hours within the day.
"Demand Shift" Benefits:
Savings opportunities for participating customers
Savings on energy and capacity costs for SVCE
W n
Grid Energy Costs:
Daily: Prices are lowest during the sunny hours,
and highest in the evening
Seasonal: negative prices common during spring
solar hours, $1000+/MWh is possible during hot
summer heat events
CAISO Wholesale Energy Prices - 4/14/2025
ISO 0 LMP o Open in Chart Builder ->
al Marginal Price - CAISO Q Apr 14, 2025 us/Pacific 4 > ± ~$58/MWh at 7pm
~$10/MWh at 2pm-***^r
Day Ahead Real Time
3 •
•
•
Year
CPUC
Capacity Market
Price Benchmarks
($/kW-month)
2019 $2.77
2020 $5.20
2021 $7.33
2022 $8.11
2023 $14.37
2024 $26.26
2025
(Forecast) $40.31
Item 4
PRESENTATION
MW
Value of Demand Flexibility: Reliability
Capacity Obligations (Example)
Example 24 Hour RA Showing
Grid capacity obligations:
Reliability obligation is highest in evening hours, Jul-Sept Reliability obligation is lower during sunny hours, and overnight Shifting obligations out of the evening peak hours can create savings on Capacity procurement costs 4 •
•
•
•
•
•
•
•
•
•
•
•
•
•
•
Item 4
PRESENTATION
As the clean energy transition progresses, needs and
opportunities for Demand Flexibility are expanding.
Past ... Now and Future ...
>
Q
Q
2 (/)
E
O
D
co
E
Q
Fossil-based
Predictable capacity
Seasonal price volatility
Mixed fuel
Flat/declining load
Dumb on/off appliances
Manual load reduction
during extreme peak
events
Renewable
Variable capacity
Daily price volatility
All-electric
70%+ load growth
Connected/flexible loads
Dynamic rates
Automated control &
optimization
5 Item 4
PRESENTATION
Cost,
cents/kWh
How can customers be encouraged to ‘flex’ their
demand from higher to lower-cost hours?
Time-Variant
Electric Rates
Time of Use (TOU)
Day-Ahead Hourly (RTP)
20 Daily Load Modification
Incentive Programs
10kWh
Event-Based Load Reduction
Incentive Programs
1 2 3 4 5 6 7 8 9 10 1112 13 14 15 16 17 18 19 20 21 22 23 24 Hour 6
•
•
•
•
•
•
Item 4
PRESENTATION
Connecting smart devices with clear market signals
is essential for maximizing demand flexibility.
Demand Flex Approach Example Application SVCE Experience Rates: Time of Use (TOU) EV charging set to begin when customer’s TOU rate is lowest, e.g., 11 pm
90+% of customers on TOU
E-ELEC pilots
Day-Ahead Hourly (RTP) Irrigation pump controllers receive day-ahead RTP rates, run in hours when electricity is lowest-cost
GridShift EV Charging Pilot
‘Hourly Flex Pricing’ pilots
Daily
Load Modification Programs (LM)
Customers receive payments for automated
discharge of batteries during scheduled peak hours
each day
SunRun solar + storage pilot
offsets SVCE RA obligation
Event-Based
Demand Response Programs (DR)
Residential customers paid for automated 2-3 degree
set point increase during grid emergencies
Purchased RA from DR ‘market
aggregators’
7 Current and Projected Deployed Devices, and Projected Demand Flexibility Potential in SVCE Service Area* Item 4
PRESENTATION
0J There is significant potential to expand demand
flexibility in SVCE’s service area.
2025 2030
Device/Technology
Estimated
Number of
Devices
Low /High Estimate
Deployed Demand
Flex Potential
(demand/ MW)
Projected
Number of
Devices
Low/High Projection
Deployed Demand
Flex Potential
(demand/ MW)
Electric Vehicles
(managed charging)
Battery Storage (residential)
HPWH
(residential)
SCTs/HVAC (residential)
Bldg Mgt Systems
(Non-res Load Mgt)
Totals (rounded)
*2030 device projections are speculative, reflective of current device adoption trends; industrial loads and back-up generation not included in this table. 8 •
•
o
•
o
Item 4
PRESENTATION
California aims to double load-shift by 2030, especially through expanded ‘load modifying’ approaches.
In 2022, the CEC estimated ^3,000 MW of customer load shift capacity on the California grid, or 5-6% of peak
The CEC has set a goal to increase customer load shift capacity to ^7,000 MW by 2030 majority of increased capacity targeted to come from daily load modification, from new demand flexibility programs utilizing dynamic pricing/market signals As context, SVCE’s ‘pro-rata’ load weighted share of the CEC’s 2030 load shift capacity goal would be approximately 70-80 MW
in line with SVCE’s projections for demand flexibility potential 9 •
o
•
o
o
o
o
Item 4
PRESENTATION
SVCE’s Demand Flexibility Goal, and Near-term Plans
Goal:
Enable SVCE to provide all customers with the ability to earn savings by easily, automatically and comfortably flexing their electricity use daily - contributing to a reliable and clean grid, and generating operational value for SVCE 2025/2026 Plans:
Contract for Distributed Energy Resource System (DERMS) software platform to support delivery of new SVCE demand flexibility programs Contract with key providers for capacity in SVCE’s service area, provided from existing battery and thermostat/behavioral demand response installations Implement SVCE Demand Flex ‘On Ramp’ program(s) for equipment funded by current and past SVCE decarb programs
Implement new Demand Flex programs incentivizing participation from energy storage, thermostat, and commercial/industrial customers 10 Item 4
PRESENTATION
What is a ‘DERMS’, and why does SVCE need one?
Distributed Energy Resource Management System
A software platform designed to communicate with and optimize the operation of various distributed energy resources (DERs) located across SVCE’s service area, such as:
- batteries
- commercial building management systems
- heat pump water heaters
- thermostats
- electric vehicles / charging
SVCE will rely on a DERMS to manage DERs enrolled in new SVCE demand flexibility programs, helping customers save money while reducing grid strain and associated GHGs.
11 Item 4
PRESENTATION
How does a DERMS work?
(Individual) battery example . ..
1. Customer enrolls their battery in an SVCE demand flexibility program -and receives financial incentives
2. 3.
The DERMS gets data from the battery/home via internet connection Combining battery data with other data, such as the customer’s rate plan, grid conditions, weather, etc., the DERMS determines how to manage the battery accordingly . . . - charge from solar or from the grid
- discharge into the home, or back onto the grid
4. The DERMS then sends instructions to the battery controller on what to do, and when
5. The DERMS receives data back from the battery confirming that the action has been taken 12 •
o
o
•
•
•
Item 4
PRESENTATION
In late 2024, SVCE issued an RFP to identify partner(s) for SVCE’s Demand Flexibility efforts.
RFP had two parts:
Part 1: implementation of DERMS ‘software as a service’ platform, and enrollment of ~5MW of demand flex capacity from existing resources in SVCE’s service area in 2026 Part 2: programs for enrollment and management of ~25MW of new demand flex capacity by 2030, from batteries, commercial buildings, thermostats and HPWH Teamed with Peninsula Clean Energy; 17 proposals received Currently negotiating a contract with Lunar Energy, for the following four scopes:
1) Gridshare DERMS platform installation and support
2) ‘On-ramp’ support for selected DERs installed via existing SVCE incentive/rebate programs 3) Enabling agreement for ‘Load Modification’ capacity from existing batteries in SVCE’s service area 4) Design and implementation support for a new SVCE battery program Second contract under development with another vendor, for a complementary scope 13 •
•
•
o
o
o
o
Item 4
PRESENTATION
Why Lunar Energy?
Global company, with U.S. Headquarters and R&D facility in Mountain View Lunar Energy’s ‘Gridshare’ DERMS platform is being actively used to manage the largest 3rd-party residential battery fleet in the world
SVCE staff recommends Lunar Energy, because:
Lunar’s approach aligned best with SVCE’s needs as described in the RFP, including robust DERMS platform, battery fleet management and program support services Deeply experienced with behind-the-meter DER management with a wide range of customers, including some of the world’s largest utilities Lunar’s Gridshare platform currently supports SVCE’s battery program with SunRun Recently contracted with Ava; also selected by PCE in our joint RFP 14 Staff recommends the Silicon Valley Clean Energy (SVCE) Board of Directors (Board) adopt Resolution 2025-11 authorizing the Chief Executive Officer (CEO) to negotiate and execute a five-year Main Services Agreement with Lunar Energy for a Distributed Energy Resources Management System (DERMS) and related program operation and load modification services, to support SVCE’s customer demand flexibility goals in an amount not-to-exceed $971,238, including all scopes of work need to implement the agreement.
Item 4
PRESENTATION
Recommendation . . .
15 Item 4
PRESENTATION
Item 4
PRESENTATION
Recommendation .
Smart-Control Thermostats / BDR
EV Charging
Heat Pump Water Heaters / HVAC
Battery Storage
Commercial / Industrial Buildings
Event-Based Load Shift
Demand Response (DR)
Daily Load Shift
Load Modification (LM)
15 MW 70 - 90 MW
17 SVCE DERMS
Platform
Customers
• Communication to devices and providers
• M&V, settlement
• Centralized project tracking
OEMs
Aggregators
Residential
C&I
• Dispatch instruction
• Incentive/Settlement
Enrollment Data
• Dispatch devices
• Data collection and measurement
• Program development
• Customer recruitment
• Dispatch devices
• Dispatch Signals
• Integrations and data
• M&V
Item 4
PRESENTATION
What is a ‘DERMS’, and why does SVCE need one?
Role of a Distributed Energy Resource Management System (DERMS) 18 • Subtitle
New SV Clean Energy
PowerPoint Template
Electrification Rate Pilot
Programs
Peter Mustacich, Technical Manager of Decarb Planning & Strategy Michaela Pippin, Communications Manager
5/14/2025
Item 5
PRESENTATION
SILICON VALLEY
CLEAN ENERGY
Recommended Action
Board approve ending the current E-ELEC 1.0 Rate Pilot
Program and associated rate schedule effective July 1, 2025. End Board adopt the E-ELEC 2.0 Rate Pilot Program and
associated rate schedule with a budget of $3.5M. Adopt
+
Item 5
PRESENTATION
3 Time-of-Use (TOU) plays an important role
in leveraging load shift potential
SVCE Effort Question We’re Answering
RTP Pilot How can SVCE integrate with PG&E’s billing
system?
VPP / DERs How can automated response to dynamic
price signals impact customer bills?
E-ELEC 2.0 How can price signals influence customer
behavior? Can we improve TOU rates?
Item 5
PRESENTATION
4 Background
Grid emissions
are lowest
during daytime
hours, and
higher in the
evening and
overnight.
Current Time-of-Use (TOU)
electricity rates
don’t reflect
this.
0 1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
$0.00
$0.05
$0.10
$0.15
$0.20
$0.25
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Grid Emissions (MTCO2/hr)
Generation Cost ($/kWh)
Time-of-Use Rates vs CAISO Grid Emissions
EV-2 Rate CAISO Grid Emissions
OFF-PEAK PART-PEAK PEAK PART-PEAK
1 AM 12 AM
Item 5
PRESENTATION
Title of the
Page
E-ELEC 1.0
LEARNINGS
Item 5
PRESENTATION
6 What is the SVCE E-ELEC 1.0 Rate Pilot?
SVCE launched the rate pilot in Jan 2023 with two goals: 1.) lowering bills from home electrification, and 2.) testing rate-driven load-shifting. $0.00
$0.05
$0.10
$0.15
$0.20
$0.25
$0.30
$0.35
OFF PEAK PARTIAL PEAK PEAK PARTIAL PEAK
SVCE Summer Generation Rates ($/kWh)
1 AM Default E-ELEC E-ELEC 1.0 12 AM
30% Off-Peak
discount
10% Peak cost
increase
• 5,300 Enrolled Customers
• Avg savings of $15/mo
• $8.0M of $9.5M budget
remaining (85%)
Item 5
PRESENTATION
Customer opts to
enroll in E-ELEC
rate through
PG&E account
Proves eligibility
by owning one of
the following:
• EV
• Heat pump
• Standalone
storage
Customer
enrolled in E-ELEC rate
(T&D)
Customer
automatically
enrolled in SVCE
E-ELEC 1.0 Rate
Pilot
(Generation)
7 Currently we don’t control enrollment
Customers are automatically enrolled in our pilot when they opt to enroll in the E-ELEC rate through PG&E
Who controls the process?
PG&E SVCE
Item 5
PRESENTATION
Lessons learned from E-ELEC 1.0 Rate Pilot
LEARNINGS
Customers saved money!
Primary enrollment device is EVs
Improved TOU price signals
Hard to correlate behavior change
Auto-enrollment means awareness
and engagement are lower
GOALS
Reduce customer bill impacts for home
electrification
Incentivize load shifting
Item 5
PRESENTATION
Title of the
Page
THE FUTURE:
E-ELEC 2.0
Item 5
PRESENTATION
We are adapting and changing course
E-ELEC 2.0 DESIGN CHANGES
Require heat pump space and water heating to qualify
Introduce a new Time-of-Use (TOU) period that better aligns with grid emissions, helping reduce system-wide costs for all customers SVCE to control rate enrollment, creating a dialogue with customers from day one
Include ongoing M&V to capture learnings and steer towards a scalable version of this rate
Item 5
PRESENTATION
11 Guaranteed savings which can be increased
$0.00
$0.05
$0.10
$0.15
$0.20
$0.25
$0.30
OFF PEAK SUPER OFF PEAK PARTIAL PEAK PEAK PARTIAL PEAK OFF PEAK Summer SVCE Generation Rates ($/kWh)
Default E-ELEC E-ELEC 2.0
1 AM 12 AM
Reduces cost of
heat pump HVAC
Supports lower
income customers
with less flexible
load
Incentivizes load
shifting to cleanest,
cheapest hours
Item 5
PRESENTATION
Title of the
Page
Item 5
PRESENTATION
Meet Sue
• Sue installs heat pump
space and water heaters
• Signs up for default E-ELEC
• With her busy lifestyle, she
does not change energy
use behaviors
Sue saves
$250/yr
$$$$
Meet Liz
•Liz installs heat pump
space and water heaters
•Signs up for the E-ELEC 2.0
pilot program
•Liz makes minor changes
to her household’s energy
use behaviors
Liz saves
$450/yr
y? y? yC y? CpCpCp CpCpCp
Meet Jo
•Jo installs heat pump
space and water heaters
•Signs up for the E-ELEC 2.0
pilot program
•Jo maximizes savings by
shifting usage to daytime
hours and leveraging smart
tech
Jo saves up to
$650/yr
Incorporating Customer Feedback –
The “Power User” Dinner
We invited 900+ E-ELEC 1.0 Rate Pilot customers to dinner to learn from their experiences Key Takeaways
• Customers were motivated to “do the
right thing.”
• Customers want more
communications and resources.
• Confusion around how much energy
each appliance uses and what savings
would look like if shifted.
• In E-ELEC 2.0 we will focus extensively
on communicating customer
performance, bill savings, and
education.
Item 5
PRESENTATION
Customer opts to
enroll in E-ELEC
rate through PG&E
account
Proves eligibility by
owning one of the
following:
• EV
• Heat pump
• Standalone storage
Customer enrolled
in E-ELEC rate
(T&D)
Customer enrolled
in default E-ELEC
rate (4% discount)
(Generation)
14 We will control rate pilot enrollment
Who controls the process?
PG&E SVCE
Customer enrolls in
E-ELEC rate
through PG&E,
auto enrolled into
default E-ELEC rate
(4% discount)
Customer applies
to SVCE to
participate in E-ELEC 2.0 Rate Pilot
Program
Proves eligibility by
owning both of the
following:
• HPWH
• Heat Pump HVAC
Customer enrolled
in E-ELEC 2.0 Rate
Pilot Program
E-ELEC Rate
Enrollment
E-ELEC 2.0 Rate
Pilot Enrollment
Item 5
PRESENTATION
E-ELEC 2.0 pilot program budget: $3.5M
Budget will provide:
• Customer Discounts
• Administration
• Billing Setup & Support
• Contingency
• Measurement & Verification
• Marketing, Communication & Education
Release remaining $4.5M to support
other decarb efforts
Benefits:
• Enroll up to 5,000 customers
over 5 years (through 2031)
• $2.5M in direct customer bill
savings
• Integrate into existing SVCE
electrification programs
• Inform future SVCE rate design
Item 5
PRESENTATION
Timeline
May 2025 Seek Board approval to end E-ELEC 1.0 and adopt E-ELEC 2.0 Inform enrolled customers that E-ELEC 1.0 pilot is ending and they will automatically be switched to default E-ELEC gen rate Jun – Jul
2025
E-ELEC 2.0 setup: billing system, data management, performance tracking, enrollment process, marketing and communications Jun – Dec
2025
Jan 2026 Open E-ELEC 2.0 Pilot Rate Program for enrollment Item 5
PRESENTATION
Recommended Action
Adopt Resolution 2025-12 Approving ending the
current E-ELEC 1.0 Rate Pilot Program and
associated rate schedule effective July 1, 2025, and
establish the E-ELEC 2.0 Rate Pilot Program with a
budget of $3.5M.
Item 5
PRESENTATION
18 APPENDIX
Item 5
PRESENTATION
Proposal: replace current E-ELEC rate pilot
with a default rate and updated pilot design
E-ELEC 1.0
(Current)
E-ELEC
(default)
E-ELEC 2.0
Rate Pilot
Winter
Super-Off-Peak 9a-3p -30% -4% -60%
Off-Peak 12-9a -30% -4% -30%
Partial-Peak 3-4p & 9p-12a 0% -4% -10%
Peak 4-9p +10% -4% -10%
Summer
Super-Off-Peak 9a-3p -30% -4% -60%
Off-Peak 12-9a -30% -4% -30%
Partial-Peak 3-4p & 9p-12a 0% -4% -10%
Peak 4-9p +10% -4% -10%
Note: Negative means “cheaper than PG&E”, positive means “more expensive”.
Item 5
PRESENTATION
Comparison of generation rates (including
PCIA & FFS)
E-ELEC 1.0
(Current)
E-ELEC
(default)
E-ELEC 2.0
Rate Pilot
Winter
Super-Off-Peak 9a-3p $0.06851 $0.09396 $0.03915
Off-Peak 12-9a $0.06851 $0.09396 $0.06851
Partial-Peak 3-4p & 9p-12a $0.11122 $0.10677 $0.10010
Peak 4-9p $0.14431 $0.12594 $0.11807
Summer
Super-Off-Peak 9a-3p $0.10438 $0.14315 $0.05964
Off-Peak 12-9a $0.10438 $0.14315 $0.10438
Partial-Peak 3-4p & 9p-12a $0.19421 $0.18644 $0.17479
Peak 4-9p $0.32265 $0.28159 $0.26399
Item 5
PRESENTATION
Comparing total bundled rates ($/kWh) puts
these designs into perspective
E-ELEC 1.0
(Current)
E-ELEC
(default)
E-ELEC 2.0
Rate Pilot
Winter
Super-Off-Peak 9a-3p $0.31 $0.34 $0.28
Off-Peak 12-9a $0.31 $0.34 $0.31
Partial-Peak 3-4p & 9p-12a $0.35 $0.35 $0.34
Peak 4-9p $0.39 $0.37 $0.36
Summer
Super-Off-Peak 9a-3p $0.34 $0.38 $0.30
Off-Peak 12-9a $0.34 $0.38 $0.34
Partial-Peak 3-4p & 9p-12a $0.45 $0.44 $0.43
Peak 4-9p $0.64 $0.60 $0.58
Item 5
PRESENTATION