IOU & CCA Demand Response Workshop - California Efficiency + ...
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IOU & CCA Demand Response Workshop
Agenda
Time Topic Presenter
9:00 – 9:15 Introduction & Opening Remarks from President Batjer
9:15 – 9:25 IOU Interval Data SDG&E
9:25 – 9:45 CPP – IOU Overview Joint Presentation
9:45 – 10:15 Other IOU DR Programs 1 – SCE (10)
2 - PG&E (10)
3 – SDG&E (10)
10:15 – 10:25 Break
10:25 – 11:10 CCA – Demand Response Programs Overview 1 - Clean Power Alliance (15)
2 – East Bay Community
Energy (15)
3 – MCE (15)
11:10 – 11:25 Roundtable Discussion
11:25 – 11:30 Closing
Introductions & Safety
Roll Call
• CPUC Energy Division https://covid19.ca.gov/vaccines/
• IOUs – PG&E, SCE, SDG&E
• CCAs from all IOU Service
Territories
3
Opening Remarks – President Batjer
IOU Interval Data
Current State Potential Future State
Master Data Validation, Edit & Push to billing Third party data Architecture Smart Meter Future
System Estimation systems exports Changes Update State
5
CPP IOU Program Overview
Critical Peak Pricing Overview
Compensation
Eligibility Structure Event Trigger Notifications Bill Protection
for Load
• Bundled • Limited • Temperature • Pre-season • Credit on • First 12
customers number of • CAISO alerts • Day ahead summer months or
• Default for events (varies • Market prices • Channels electric use de-enrollment
for small, by IOU) • High Load vary by IOU outside of date if prior
medium, and • Year-round demand event hours
large C&I, program • Grid status • Capacity
and large (holiday • Emergencies Reservation
Agricultural. activity varies) Option
• NEM (limited, • Opt-out any
PG&E) time
• No (new) dual • Technology
participation incentive
with other (varies)
incentivized
DR programs
7
PG&E 2021 Demand Response
• PG&E's Critical Peak Pricing Program (SmartRateTM • Especially for the greater Bay
and Peak Day Pricing (PDP) comprises ~ 4% of Area, focusing on customers with higher
the load management portfolio load drop potential is extremely
Load Impacts (MW) of DR Resources [1] Aug-21 important
Residential
SmartAC™ 18
SmartRate™ 4
CBP-DA 2
Total, Residential 24
Non-Residential
BIP 183
CBP-DA 40
DRAM 83
Ex-ante load evaluation
Peak Day Pricing (PDP) 10
Total, Non-Residential 316
Totals 340
SmartRate™ and PDP 14
[1] Average of Portfolio-Adjusted hourly ex ante load impacts (MW) under 1-in-2 weather conditions from 4 to 9 PM on monthly
system
Source:peak
Tableload
B.1,days.
Applied Energy Group. 2020 Statewide Load Impact Evaluation of California Non-Residential Critical Peak Pricing
Programs, Ex-Post and Ex-Ante Load Impacts (CALMAC ID SDG0334). April 1, 2021
8
Program Year 2020 Ex-Post Load Impact: Typical Event Day
Source: Ta ble ES-5, Applied Energy Group. 2020 Sta tewide Load Impact Evaluation of Ca lifornia Non-Residential Cri tical Peak Pri cing Programs, Ex-Post and Ex-Ante Load Impacts (CALMAC ID SDG0334).
Apri l 1, 2021
• Program Year 2020 statewide total likely overestimates what might be achievable across the state should a statewide event be
needed
• Across all three IOUs, the weather was more extreme in PY2020
• COVID-19 conditions may also have affected how customers responded to CPP events. Given the depressed economic
conditions across the country, it is possible that participants had additional incentive to save energy (and money) over the
summer of 2020. Also, reduced capacities at many retail and restaurant locations may have facilitated additional response.
9
IOU Critical Peak Pricing
Marketing, Education, & Outreach
PG&E SCE SDG&E
CPP is a pricing plan option that customers can
Phased outreach increasing in urgency/specificity of
What is the optimal Summer readiness campaign to remind customers how CPP choose to participate in. For customers who
rate impact leading up to transition. Communications
customer journey and works, that events are coming, and what they can do to decide that CPP is right for them, our goal is to
detail what’s happening, what it means for the
experience? prepare. educate them on how to best optimize their plan
customer, and how to take action.
and participate if called upon.
What channels of
engagement are most All three utilities agree that the best engagement is through a multi-channel and multi-touch approach, but each utility has a unique tactical strategy that varies slightly.
effective?
In-season support consisted of email and text
outreach, including pre-Event and day-of reminders,
How do we engage our along with tips and customizable energy conservation When events are triggered, customers are notified a day Events are communicated through notifications
customers in a likely action plans. A post-Event email was sent with ahead of a scheduled event by: email, phone, SMS, mobile including email, SMS, IVR day ahead and day of
event approaching? feedback on the customer’s energy curtailment. In app, IVR messaging, sce.com banners and webpages. recordings. SDGE.com is also updated.
addition to the text/email alerts, alerts were added
to pge.com and PG&E’s social media.
How do we partner with
our top 10 to 20 critical Account managers at each utility work directly with these large business customers.
accounts.
10IOU Critical Peak Pricing
Marketing, Education, & Outreach
Lessons Learned:
• Focus on customers with a higher potential/ability to provide load.
• Offer opt-out option if mandatory transition.
• Use a variety of channels to notify customers about the upcoming Demand
Response season and Event Days.
• Allow for multiple recipients to assist in reaching the decision maker.
• Reach customers via their preferred channels of communication.
• Continue to re-educate customers about the program, how it works, how it
can benefit them, and actions to take during an event.
11IOU Critical Peak Pricing
Marketing, Education, & Outreach
2021-2022 PG&E Vision:
Education and Awareness
• Audience: All Non-Residential CPP participants
• Message: Program parameters are changing; update your notification preferences; you
have rate options
• Channels: Pre-season support direct outreach and pge.com ongoing
• Call to action: Prepare and plan; adjust CRL for larger customers
Research and Analysis
• Analyze load and bill impacts by segment in year 1
• Customer profiling to determine likelihood of program engagement and success
Event Season Support
• Audience: Engaged customers; larger businesses; hotter geographies
• Message: Varies, but centers around helping customers prepare for and succeed on
Event Days
• Channels: Email and SMS with pre-event and day-of notifications, and post-event
performance analysis
• Call to action: Plan; act; optimize
12IOU Demand Response Programs
SCE Demand Response Programs - Overview
SCE DR tariffed programs:
• Base Interruptible Program (BIP)
• Agricultural and Pumping Interruptible (AP-I) Program
• Capacity Bidding Program (CBP)
• Summer Discount Plan (SDP) Program
• Smart Energy Program (SEP)
• Critical Peak Pricing (CPP) Program
• Real-Time Pricing (RTP) Program
SCE DR contracts or pilots:
• Demand Response Auction Mechanism (DRAM) Contracts
• DR Power Purchase Agreements (such as Local Capacity Resource (LCR), Preferred Resources Pilot (PRP), and
Aliso Canyon Energy Storage (ACES))
• Distribution Investment Deferral Framework (DIDF)
• Emergency Load Reduction Program (ELRP) Pilot
Other SCE incentive program:
• DR Enabling Technology/Control Incentive Program (includes Automated Demand Response
Technology Incentive Program (Auto-DR) and smart thermostat incentive)SCE’s DR Portfolio
Customer Customer CAISO Retail
Resource Design
Sector Type Integration Compensation
Large C&I, All (bundled & Emergency interruptible load (customer/aggregator
BIP Yes (RDRR) Capacity
Aggregator unbundled) control).
Ag & Water All (bundled & Emergency interruptible load (utility direct load
AP-I Yes (RDRR) Capacity
Pumping unbundled) control).
Residential Capacity Economic, day-ahead (DA) energy (TOU rate
CPP Bundled Only No (*Energy for dual
and C&I participation purposes) structure).
RTP C&I Bundled Only No Energy Economic, day-ahead energy (RTP rate structure).
Aggregator Programs Residential All (bundled & Capacity & Third-party economic energy and capacity (both
Yes (PDR)
(CBP, LCR, PRP, ACES) and C&I unbundled) Energy traditional DR and storage-backed DR).
Bundled Only Yes (RDRR w/ Thermostat direct load control through 3rd party
SEP Residential Capacity
(*Open to all in 2022) DA energy) thermostat providers.
Residential All (bundled & Yes (RDRR w/ A/C cycling utility direct load control (both
SDP Capacity
and C&I unbundled) DA energy) economic and emergency).
Residential All (bundled &
DRAM Pilot Yes (PDR) Capacity RA-qualifying capacity
and C&I unbundled)
Residential All (bundled & Emergency load reduction (customer/aggregator
ELRP No Energy
and C&I unbundled) control).
RDRR – Reliability Demand Response Resource C&I – Commercial & Industrial RA – Resource Adequacy
PDR – Proxy Demand Resource TOU – Time-of-Use A/C – Air Conditioning
DA – Day-AheadSCE’s DR Portfolio Business Roles
Utility Managed Tariff – Utility Managed –
Load-Modifying Wholesale RA
Supply-Side Supply-Side Wholesale Energy
Tariff Capacity
(In House) (Bilateral Contract)
BIP CBP Tariff
CPP Rule 24
AP-I LCR Contract
Program Examples RTP DRAM Pilot (Direct Participation in the
SDP PRP Contract
ELRP (SCE & aggregator) CAISO Energy Market)
SEP ACES Contract
Customer Recruitment SCE SCE Aggregator Aggregator Aggregator/Customer
Customer Enrollment SCE SCE Aggregator/SCE Aggregator Aggregator/Customer
CAISO Integration Not Integrated SCE SCE Aggregator Aggregator/Customer
SCE-to-Aggregator-
Event Notification SCE SCE Aggregator Aggregator/Customer
to-Customer
Retail Settlement SCE SCE Aggregator N/A N/A
Wholesale Settlement Scheduling Scheduling
Not Integrated SCE SCE
(Scheduling Coordinator) Coordinator Coordinator
Customer Management SCE SCE Aggregator Aggregator Aggregator/CustomerPG&E Demand Response Portfolio Non-Residential Programs • Base Interruptible Program • Capacity Bidding Program • Automated Demand Response • Emergency Load Reduction Program (in development) Residential Programs • SmartAC • Capacity Bidding Program • Automated Demand Response
Emergency Load Reduction Program (ELRP)
Program Program Trigger & Measurement
• Group A: Direct Enrollment of bundled and unbundled • Day-Ahead Dispatch (CAISO AWE)
(CCA and ESP), Non-residential eligibility includes both • Group A
Commercial & Industrial, Agricultural and Small-Medium
Business; BIP Aggregator • Performance method: 10 in 10 baseline with a +/- day of
adjustment factor of +/- 40%
• Group B: Aggregator for CBP and Third-party DRP
enrollment (e.g., DRAM) • Compensation bounded by 50% floor and 200% ceiling
for nomination relative to performance
• Allows export and VPP participation
• Group B: Different prescribed methodology
Parameters & Incentive Notable Provisions
Min load shed of 1kW • Dual participation with Base Interruptible Program (BIP)
Parameters DR emergency program
• Availability = May – October; 7 days a week, 4 – 9 p.m. • Dual participation with CBP and other 3 rd party PDR
(e.g., DRAM) programs
• Event Duration: 1-hr min; 5-hr max
• Allows use of prohibited resources during emergency
• Annual Dispatch: Up to 60 hours events (i.e., fossil fuel back-up generation)
• Consecutive Days: No constraint • Certain program elements can be deferred to May 1,
Performance Incentive: $1.00 per kWh (energy) 2022 (e.g., exports)
No penalty; no capacity paymentBase Interruptible Program 24/7/365 days reliability program Program Summary: BIP Participants are on standby 24/7/365 to provide day-of-load reduction on PG&E’s system when PG&E or CAISO issues a curtailment notice. Eligible for both bundled and unbundled (ESP or CCA) customers. When events are called, participants are given a 30-minute notice to reduce their load down to or below their Firm Service Level (or face a penalty).
Capacity Bidding Program Aggregator-managed | Season: May 1 to October 31 Program Summary: CBP is an economic program for non- residential and residential Aggregators. Aggregators nominate capacity each month for their enrolled resources. Program options include a set price bid into the market by PG&E, or aggregators can choose the price at which their customers are dispatched for a DR event. Customers on bundled or unbundled service (CCA or DA) can participate.
SmartAC
Direct install program for residential 3rd Party Implementer:
central air conditioners
Program Summary:
• A load control switch is installed when a customer
joins the SmartAC program. Customers receive
$50 after installation.
• During hot summer days the switch is activated to
limit when the AC can provide cool air. A customer
will typically experience 20 hours of cycling per
season. Current 2-way Legacy 1-way
switch switch
• Events are at most one hour and at most 6 hours,
typically 2-4 hours long.
• Customers have the option to opt-out of any event,
no limitations or penalties.
• Participation available to both bundled and
unbundled customers.Automated Demand Response – Non-Res
Incentives for all business sectors to offset the cost of controls to
support DR program participation
Program Summary: 3rd Party Implementer:
ADR is an easy way to increase energy
and cost savings by automating the
energy control. Customers install new Dispatch System:
qualifying technologies and must
commit to participate in a DR program
Standard:
for three years.Automated Demand Response - Residential $50 smart thermostat rebates for residential customers Program Summary: Customers who buy an Energy Star certified smart thermostat and apply for a $50 EE rebate may also qualify for a $50 ADR rebate when we confirm they are on a DR program (SmartRate or DRAM). $70 rebate if on a TOU rate (PG&E or non- PG&E).
SDG&E DR Programs - Overview
Programs:
• Capacity Bidding Program
• Base Interruptible Program
• AC Saver Program
• Technology Incentive Program
• Technology Deployment
Program
• Third Party DR – Rule 32
• Emergency Load Shed Pilot
(ELRP)
Rates with a DR Component:
• Critical Peak Pricing (CPP)
• TOU-PA-P Agricultural
• TOU-A-P Small Commercial
24SDG&E –Capacity Bidding Program (CBP) Is a pay for performance Program. Customers receive monthly capacity payment and energy incentives in return for load reduction. Customers mostly participate through 3rd Party Aggregators. Customers opt into a "product" each month: 11:00am-7:00pm or 1:00pm-9pm day ahead or day of. For 2021 Maximum events per month is nine events of which three are reserved for emergencies. SDG&E –Base Interruptible Program (BIP) Emergency/reliability program. Customers receive monthly capacity payments in return for load reduction when notified. BIP has a 20-minute notification time and is a year- round program. Max. 4 hours duration, max. 10 events per month. Incentives are monthly Capacity Payments with penalties for non- performance. Incentives are -$6.30 kW. Nonperformance Penalty is - $4.50 kWh.
SDG&E – AC Saver Program (ACS) Day Of - Switches
Day Of air conditioner program that receives a signal from a one- way direct control switch and cycles
the customers AC using the customers elected cycling percentage. Payment is an annual bill credit paid
in December based on the customers cycling option and AC unit's tonnage. The Program is Available
April through October, noon to 9:00 p.m. For 2021 annual events are 25 with 5 events reserved for
emergencies.
Incentives, per ton:
• Residential 100% - $27.00
• Residential 50% - $10.35
• Commercial 50% - $7.50
• Commercial 30% - $4.50
SDG&E – AC Saver Program - (ACS) Day Ahead -Thermostats
Supply side program for residential and commercial customers with thermostats. Current eligible
brands are Ecobee, Honeywell and Nest. This program is bid into the CAISO. Customers are
notified by e-mail, text and/or by a message on the thermostat. Events 2 - 4 hours duration, For
2021 a maximum 25 events per season with 5 events reserved for emergencies. Program Season:
April – October. Residential annual incentive of $20 paid annually in DecemberSDG&E – Technology Incentive Program (TI) - Load Modifying The Technology Incentives Program offers incentives to business customers to help with the purchase and installation of Energy Management Systems (EMS) controls and/or equipment, This will help the customer manage and save year- round by monitoring, controlling and optimizing energy use. The program offers eligible business customers up to two-hundred dollars per kilowatt ($200.00/kW) for approved, installed and verified kilowatt (kW) reduction. The total incentive is capped at 75% of the total project cost. The TI program requires customers receiving incentives to enroll in a qualified Demand Response program for three years. Qualifying programs for TI enrollment are the Capacity Bidding Program (CBP), Critical Peak Pricing (CPP) or other eligible pilots such as DRAM.
SDG&E – Technology Deployment Program (TD) - Load
Modifying
The Technology Deployment Program is a bring your own
device program (BYOT). The Program offers a $50 incentive
to Residential Customers for installing and enrolling either a
Nest, ecobee or Honeywell Home Thermostat with
the requirement that the customer must enroll in an eligible
DR program.
Eligible Programs for enrollment are:
• AC Saver Day Ahead
• Rates with Events (e.g., CPP )
• Capacity Bidding Program (CBP)
• Demand Response Auction Mechanism (DRAM – Rule 32)
28SDG&E – Third Party DR – Rule 32
Rule 32 allows third-party Demand Response Providers (DRPs) to solicit SDG&E customers to
participate in their demand response programs and to "bid" the electricity reduction into the
wholesale electricity market administered by the California Independent System Operator (CAISO).
Demand Response Auction Mechanism (DRAM) is a third-party pilot program under Rule 32 from
2016 – 2023. SDG&E solicits offers on an annual basis for DRAM contracts. Majority of Rule 32
enrollments are through DRAM.
Local Capacity Requirements (LCR) contract for 2018 – 2022 also under Rule 32 with 4.5MW
29SDG&E – DR Program Marketing and Outreach
Digital Marketing: CCA's will see our mass media campaign including
tactics such as Digital Ad banners, podcast radio ads and LinkedIn InMail.
Website: Our website contains access to the most up to date information
on each demand response program sdge.com/dr.
30Break – 10 Minutes
CCA Demand Response Programs Overview
Demand Management
Programs
April 6, 2021CPA is currently operating two DR programs
● Peak Management Pricing (PMP) is a demand response program highly
similar in design to IOU CPP programs - open to commercial customers.
● Power Response is a DER focused demand response pilot program - open
to residential and commercial customers
CLEAN POWER ALLIANCEPeak Management Pricing CLEAN POWER ALLIANCE
Peak Management Pricing
CPA’s Peak Management Pricing program, launched in 2019, provides summer bill
credits in exchange for the application of a surcharge on energy consumed during
demand response events to encourage curtailment during peak demand days.
Events are five hours in duration (4-9pm on weekdays). Customers
Events are notified 24 hours in advance. Program is limited to 12 events
per year.
Customers receive a per kW credit on their summer bills (June-
Credit September) that varies by rate schedule.
Customers are charged a flat per kWh surcharge for any usage
Surcharge during the 4-9pm event period.
Customer receive a bill credit at the end of their first calendar year on
Bill Protection PMP if they paid more than they would have otherwise paid on their
regular rate.
CLEAN POWER ALLIANCEMarketing and Enrollment
● CPA has engaged its large load and municipal customers directly
through commercial account liaison outreach to explain the potential
benefits of the program
● Direct mailer campaign
● Marketing through local chambers of commerce, social media, and
CPA newsletter
CLEAN POWER ALLIANCEOpportunities and Challenges Observed
Opportunities
● Cautious optimism regarding load management benefits, but more data
needed
● Customer education opportunities on how to shed discretionary load and
building load management systems
Challenges
● Difficult to scale program enrollment with opt-in program model
● Value proposition varies greatly by customer and circumstances
● Difficult for many customers to curtail usage, especially on hottest days of the
summer
CLEAN POWER ALLIANCEPower Response Program CLEAN POWER ALLIANCE
Power Response Program
CPA’s Power Response pilot program, launched in 2020, is a DER focused demand
response program, comprised of three technology types targeting different customer
segments, and designed to leverage existing customer equipment.
Description Target Segment
EV Charging Pays customers to shed EV Commercial & Municipal
charging load during events
Pays customers with onsite Commercial & Residential,
Solar + solar and battery to discharge including Disadvantaged
Storage batteries during events Communities (DACs)
Pays customers who manually Residential, including
Smart
reduce their A/C load during Disadvantaged Communities
Thermostat events or allow CPA to control (DACs)
smart thermostats remotely
CLEAN POWER ALLIANCEMarketing and Enrollment
CPA employed different strategies to reach commercial vs residential
customers
● Commercial
○ Direct engagement by commercial account liaisons
○ Targeted webinars and email campaigns
● Residential
○ Variety of mass marketing techniques including direct mail/email,
social media, in-app notification
○ Partnered with recipients of CPA’s CBO Grant Program to raise
awareness and enroll interested customers
○ Outreach conducted in multiple languages – English, Spanish,
Chinese, Tagalog
CLEAN POWER ALLIANCE2020 Program Highlights
● Tested direct load control
● High event engagement / acceptance rate (~50%)
● High effectiveness per thermostat
● Low customer dissatisfaction / event-related tickets
● Successfully navigated and helped alleviate early heat waves and energy
shortages
CLEAN POWER ALLIANCEOpportunities and Challenges Observed
Opportunities
● Overlap with Residential TOU
○ TOU default approaching in 2022, opportunities to align messaging
● Steady enrollment in the residential smart thermostat and residential
battery storage segment of the program showed promising load
management benefits to CPA and extremely engaged customer base
● Planning to test CAISO integration of DER resource this summer
Challenges Reaching Commercial Customers
● Access to information regarding existing installed customer DER
technology is limited, making targeted outreach challenging
● Customers with previously installed technologies were less likely to
participate in Demand Response as it can modify existing technology
agreements or value propositions
CLEAN POWER ALLIANCENext Steps
Peak Management Pricing
● Working to develop direct, customized, and targeted outreach strategies and
more tools to educate commercial customers of the availability of PMP and
potential benefits
Power Response
● CPA is releasing an RFP this week for an implementation provider to scale
the Power Response Pilot program to full implementation
○ In next phase CPA is seeking to leverage market activity around newly
installed DERs through a trade ally network to acquire customers into the
program and expand direct load control capabilities
CLEAN POWER ALLIANCESummer 21 Demand Response Program Workshop PRESENTED BY: Stefanie Tanenhaus DATE: April 6, 2021
Summary
• Overview of EBCE’s experience with CPP/PDP
• Current and planned approaches to demand-side peak load
management
• Barriers to incremental demand response
46EBCE experience with CPP/PDP
• EBCE offered a Peak Day Pricing program in 2018 and 2019
• Mirrored PG&E’s Peak Day Pricing program
• Performed targeted outreach to customers with the greatest load elasticity
• Analysis of performance indicated limited behavioral changes
• Transition to TOU rates further limits incremental benefits of PDP
• Pursuing alternative approaches to providing peak load management
47EBCE Approaches to Peak Load
Management
• Partnering with OhmConnect to provide 25 megawatts of load reduction
for summer 21
– Structured as energy hedge during peak load hours (HE 17-21 daily)
• Resilient Home initiative
– Onsite solar and storage systems for residential customers
– Targets 5 MW load reduction by end of 2022
• Sunrun Oakland Clean Energy Initiative
– Behind-the-meter solar (500 kW) and storage (500 kW/2 MWh) by 1/2022
• Exploring additional potential opportunities to increase demand
response in summer 21 timeframe
48Actions to Increase Load Reduction
Potential
• Support range of demand-side solutions
• Equitably value demand-side resources under RA framework
– Account for net export value of BTM hybrid and storage systems
– Eliminate- not further reduce- cap on DR for RA
• Revise contract length requirements for new DR under IRP procurement
requirements
– Limiting eligibility to 10-year DR contracts inhibits ability to bring on new DR
– Commission should allow 3-year contracts to satisfy existing and future IRP
procurement mandates
49Peak Load Programs
April 6, 2021
50Overview
• Billing Data Barrier
• Program Participation Barrier
• Demand Flexibility Market
• MCEv Smart EV Charging Pilot
• Battery Storage Program
• Peak Feed-in-Tariff*
• Time-of-Use + Demand Management Outreach
Priorities
51Billing Data Barrier
• CCAs receive billing data from utilities
• PG&E – generalizes hourly usage into blocks (i.e. 4pm-10pm)
• Hourly data is needed for load shedding incentives
(e.g. CPP programs)
• ShareMyData is an inadequate workaround
• Separate system with hourly and 15-minute data
• Not scalable & undermines impact of incentives
• Data quality challenges
• Short-term need: billing data; long-term: real-time data
52Program Participation Barrier
• Need data to verify customer participation in load shedding
programs
• To avoid double-dipping on incentives or double counting
achievements
• To mitigate the risk of conflicting signals between multiple programs
• Eligibility determinations
• Need data to understand market saturation and remaining
potential for program design
• Need information about existing third party and utility programs
• Can avoid overcommitment of resources and support incremental
progress
53Demand Flexibility Market
• Under development – aiming for Summer 2021
• Offers payments for load shifting to off-peak hours and
day-ahead event-based response to support grid
reliability and resiliency
• Focus on reducing summer evening peak demand
• Maximizes reach via the Flexibility Market model
• Nearly any provider can participate
• Technology agnostic
• Integrates efficiency, load shifting, and event-driven DR
54Demand Flexibility Market
• Reshaping the duck requires a daily resource value
• Building off experience with energy efficiency (EE)
• Leading NMEC measurement (CalTRACK 2.0) with control
group analytics – accurate, open source counterfactual
• Attractive to vendors for it’s simplicity - MCE’s Commercial
Efficiency Market subscribed budget within 3 months
• EE implementers can produce optimized load shapes
• Many DR providers can do more than event-driven DR
• The Flex Market model aims to demonstrate that value
55MCEv Smart Charging Pilot
Goal: Reduce Peak Load + Shift EV Charging to Peak Solar
•DESCRIPTION: Launching in summer 2021, this pilot uses
vehicle telematics to shift and balance EV charging load
based on grid conditions and power procurement
•SCOPE: ~200 vehicles enrolled with a subset of those having
home battery storage
•BUDGET: TBD
•OBJECTIVE: Help residential customers, especially low-
income and those already on NEM tariff, minimize the
carbon intensity and cost of energy used for EV charging
Source: Fachrizal (2020)MCEv Smart Charging Pilot
Barriers to Implementation
• Learning from ratepayer-funded pilots
• PG&E’s primary role in administering pilots – should be all LSEs
• Existing pilot coordination is limited – encourage richer
dialogue and information sharing
• Early coordination on pilot designBattery Storage Program
• Active program with a goal of 15 MWh of
dispatchable storage paired with solar by 2022
• Technical assistance, financing, performance
payment, and rebates available
• Outside of emergency outages and Public
Safety Power Shutoffs, batteries will be
dispatched daily between 4pm-9pm
58
• Addresses up-front cost barrier for storagePeak-Feed-in-Tariff*
*supply-side activity
• Redesigning MCE’s Feed-in-Tariff (FIT) program to focus
on deliveries during peak
• Revised program in 2019 to require all new solar
projects include battery storage
• Considering additional changes to reduce daytime
generation
• Challenge - Grid upgrade delays preventing resources
from getting Resource Adequacy credit
59Time-of-Use + Demand Management
Outreach Priorities
• Focused Customer Engagement
• NEM customers: options for load shedding and shifting
• Large commercial customers : webinars and 1:1 outreach on TOU
and Energy Management
• Residential customers: partner with PG&E on campaign in advance
of Spring 2022 default TOU transition
• General Education and Awareness
• Digital messaging– Flex Alerts, resiliency, targeted banner ads
• Website content – TOU, Flex Alerts, resiliency and energy
management tips
• Content toolkits for community partners
60
• Blog posts, social mediaMichael Callahan, Senior Policy Counsel
Thank You mcallahan@mcecleanenergy.org
61Roundtable Discussion
62Closing
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