Active Demand Reduction Demonstration & Initiative Update - March 20, 2019 - ma-eeac
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Active Demand Reduction Demonstration & Initiative Update March 20, 2019
Agenda
▪ A transition from demonstrations to offerings
▪ Residential Demonstrations - 2018 Activity &
Findings
▪ Residential 2019-2021 Program Design
▪ C&I – Demonstrations - 2018 Activity & Findings
▪ C&I – 2019-2021 Program Design
▪ 2019-2021 Plan & Order
▪ SW Plan Summary Table - what we said we would do
▪ Order Results - what DPU said we could do
▪ Evaluation Plans
2
A Transition
3
Demonstrations Transition to a Full
Offerings
▪ 2016-2018
▪ PAs explored and implemented demonstration offerings
▪ PAs collaborated with DOER, AG, and LEAN through Demand
Savings Group (outlined in the 2016-2018 Term Sheet) and the
EEAC Demand Reduction Subcommittee (expired in March
2017) to research and develop demonstration projects to inform
2019-2021 Three-Year Plan program designs
▪ 2019-2021
▪ PAs completing demonstration offerings and will implement
statewide offerings at scale under programs approved by DPU
▪ PAs have established the Demand Coordinating Committee
under the MC structure, like MTAC, SW Marketing, or others
▪ Future coordination will occur through the RMC/C&IMC (similar
process for all programs and initiatives)
4
General Important Findings
Key Findings – Broadly Applicable
▪ Integration with EE is imperative
▪ Uses EE Delivery Channels for technology seeding – Tstats, HVAC
Controls, BMS/EMS, Lighting Controls, etc.
▪ Uses EE Delivery Channels for marketing/outreach
▪ The most effective Tstat recruitment tool was through-OEM outreach
▪ The most effective C&I customer recruitment path was through sales representatives
▪ Uses Commercial Sales teams to add ADR to suite of solutions and
offerings to discuss with customers
▪ Cost-Effectiveness
▪ Targeted Dispatch vs. Daily Dispatch yields 3x difference in total AESC
Value – at a cost in terms of type of strategy available
▪ Customer Cost-Effectiveness ≠ Program Cost-Effectiveness
▪ Future is unknown – will we see a further decrease in avoided capacity in
future AESC studies?
6
2018 Demonstration Activity & Findings – Residential
Residential Demo Design
Summary
Design/ Customer Segment Dispatch Programmatic Est. Cost range Participant Est.
Demo PA
Approach Targeted Criteria Benefits Targeted Spend ($/kw-yr) Count MW
Connected
Solutions -
DLC
Direct load control Summer, 3-4
Residential and Income Targeting System
of cooling hour events,
National Eligible customers with Peak – avoided ~$1.5 ~$250/kw-
equipment using between 1-6pm, 11,000 6
Grid communicating tstats capacity, Tx, Dx, mil/yr yr
communicating no holidays or
and cooling equipment capacity DRIPE
thermostat weekends
Residential
Direct Load
Control Eight 4-hour DR
Unchanged - A/C
Residential and Income events called, all Targeting System
setpoint
Eligible customers with in July & August Peak – avoided ~$30,000 ~$250-
CLC adjustments 91 0.045
communicating tstats between 2 – 7 capacity, Tx, Dx, /yr 500/kw-yr
targeting ISO
and cooling equipment pm capacity DRIPE
peak hour
Residential
Storage/
Solar PV pairing solar Targeting System
customers and Summer system Peak – avoided
residential customers ~$50,000 >~$2,000/k
Unitil storage to assess peaks, Winter capacity, Tx, Dx, 2-4 0.008
with solar PV /total w-yr
customer dispatch capacity DRIPE +
acceptance Winter Energy
8National Grid & CLC –
Residential DLC
2018
Enrollment in Direct Load Control Enrollments
• Enrolled ~6 MW
• Enrolled ~11,000 devices 2017
• ~100 devices CLC Enrollments
2016
2018 Implementation Updates Enrollments
• NGrid: Reduced costs
through competitively
procured contracts for the
demand response
management system (DRMS)
vendor and device vendors.
• NGrid: Streamlined the
enrollment flow for
customers. Cut the time to National Grid example of enrollment builds and holds
validate customers and pay
incentives.
9Unitil – Residential Battery Storage/Solar
PV Demonstration
Objective: Couple Battery Storage with existing Solar PV to flatten the duck
curve, creating a consistent demand resource.
Demonstration Status
Batteries:
▪ Tesla battery arrival had been delayed pushing us out a year.
▪ These systems will only follow a house’s load – we continue to research this
issue.
▪ LG Chem batteries may be similar – we continue to research this issue.
Installation:
▪ Both battery systems are in stock.
▪ There are four customers lined up (2 less than originally filed) as prices. have
gone up and the budget is fixed.
▪ Installations should be completed by April 30th.
10Residential Findings
▪ National Grid Demonstration
▪ Through-OEM marketing positively impacts enrollments makes for the most effective channel,
50% growth in enrollment over 2017
▪ Tstat Connectivity issues improved, in 2018
▪ Full Participation rate increased to 66%, in 2018, partially attributable to lower rate of
connectivity issues.
▪ Opt-out rate averaged 18% for 2018 and was higher compared to 2017
▪ Per device savings ranged from 0.69kW to 0.91kW
▪ CLC Demonstration
▪ Mini-split control devices experienced the most communication and customer setup issues
▪ Combined w/ low peak-demand savings means not cost-effective to deploy at scale at this time. Will
continue to monitor market for cost-effective mini-split integration solutions.
▪ Most participants unaware of any change in temp./comfort during events
▪ Most customers were satisfied with the demonstration and would participate again
▪ Generally Applicable
▪ No real reason for mass customer adoption – no TOU or direct bill savings
▪ Participation incentives were strongest motivator
▪ Customers largely remain year after year allowing enrollments to build year after year
11
▪ Program delivery cost control is important for offering cost-effectiveness2019-2021 Program Design – Residential
3 Options to Participate -
Residential
Program Parameters Devices
Thermostat • 13 to 17 events per summer
• 3 hours per event
• $20 for signing up
• $25 per year for staying in the
program
Battery • 30 - 60 events per summer,
Per Order: Daily Dispatch • 2 - 3 hours per event
Demonstration for 2019 –
expect to reach full offering • $225/kW-summer
for 2020
• $50/kW-winter
Electric • 2 to 8 events per summer
Vehicle • 3 hours per event
• Eversource – Charger Control –
R&D
• National Grid – Vehicle Control –
Claiming Savings
132018 Demonstration Activity & Findings – C&I
C&I Demo Design Summary
(1 of 2)
Customer Segment Programattic Cost range Participant
Demo PA Design/Approach Dispatch Criteria Est. Spend Est. MW
Targeted Benefits Targeted ($/kw-yr) Count
Connected National Technology agnostic Large Commercial & Summer, 3-4 hour Targeting System
Solutions - Grid manual or automatic Industrial customers events, between 1- Peak – avoided
C&I curtailment demand with interval meters 6pm, no holidays capacity, Tx, Dx,
reduction. Delivered or weekends capacity DRIPE
through Curtailment ~$3-4
$50/kw-yr 276 60
Service Providers mil/yr
(CSPs)
Batteries Eversource Summer: long duration Large Commercial Summer daily: 5 Targeting System
daily dispatch and short Customer hour dispatch Peak – avoided
duration targeted during summer capacity, Tx, Dx,
dispatch peak hours capacity DRIPE
Winter: Price dispatch Summer targeted:
Lithium Ion batteries 1 – 3 hour
dispatch when $598 to
system peak hours $2.5 mil/yr $943/kw-yr 2 0.25
predicted
Winter: Price >
$500/MWh
Thermal Eversource Uses thermal storage to Cold Storage & Daily dispatch Targeting System
Storage (ice reduce load from HVAC load daily during Peak – avoided
storage and existing AC or summer peak capacity, Tx, Dx,
$1.95 mil/yr $224/kw-yr
phase refrigeration equipment hours capacity DRIPE 2 0.03
change)
15C&I Demo Design Summary
(2 of 2)
Customer Segment Programmatic Cost range Participant
Demo PA Design/Approach Dispatch Criteria Est. Spend Est. MW
Targeted Benefits Targeted ($/kw-yr) Count
Software Eversource Customized plans to Large Commercial & System triggered Targeting System
signaling of reduce facility load Industrial customers when customer Peak – avoided
Building through software, e.g., with interval meters nears 5% of their capacity, Tx, Dx,
Management pre-cooling and monthly peak, or capacity DRIPE
System reducing maximum when system peak
$2 mil/yr
(BMS) speed HVAC variable hours are N/A 0 N/A
speed air handlers predicted
Manual Load Eversource Technology agnostic Large Commercial & Summer: 1-4 hour Targeting System
Curtailment manual curtailment Industrial customers events, between 2- Peak – avoided
demand reduction. with interval meters 7pm, no holidays capacity, Tx, Dx,
Delivered through or weekends capacity DRIPE
Curtailment Service Winter: Price >
$81 /kw-yr
Providers (CSPs) $500/MWh $1 mil/yr 59 8.4
Wi-fi Eversource Direct load control of Samll Commercial Summer, 3-4 hour Targeting System
thermostats cooling equipment using customers with events, between 1- Peak – avoided
communicating communicating tstats 6pm, no holidays capacity, Tx, Dx,
thermostat and cooling or weekends capacity DRIPE $0.2
equipment N/A 1 N/A
mil/year
16National Grid – C&I Targeted
Dispatch
Preliminary Results
• Enrolled 276 Customers
• Performed 59.3 MW
Performance
• Called 6 Events Summer 2018
Results & Evaluation
• Waiting for draft of results
• Interval data challenges are a
finding and concern
Improvements for 2019
• Enrolling more customers & MW
• Adding Daily Dispatch for
appropriate loads, like batteries
• Adding Winter Dispatch
• More Training for Sales
Representatives
17Eversource – C&I Demonstration
Projects
▪ Eversource is testing five different demand response technologies for C&I
customers (batteries, thermal storage, software signaling of Building
Management System (BMS), manual curtailment, and wi-fi thermostats)
▪ Demonstration projects test three different demand response strategies
(daily dispatch, targeted dispatch, and customized dispatch)
▪ Projects benefit customers and the grid by reducing loads during the system
peak hour, as well as reducing customer monthly peak loads
▪ The demonstration projects are designed to answer a number of research
questions, such as:
▪ How much demand reduction does each technology provide, and what are the net energy
implications for each technology?
▪ How did the recruitment process go compared to expectations?
▪ Are customers satisfied with the demand reduction technology?
▪ The demonstration projects are intended to offer a range of demand
response options suitable for different types of customers, and to inform full
scale program development
18Eversource – Demonstration
Project Status
Technology Number of Installations (Accounts) Evaluated MW Expected MW Cost
Demand Demand $/kW-year**
Summer Current Expected Reduction Reduction
2018 Installed Summer Summer 2018 Capacity
2019* (System Peak Summer 2019
Hour)
Batteries 2 3 9 0.25 2.52 $598 to $943
Thermal 2 3 22 0.03 1.68 $224
Storage (ice
storage and
phase change)
Software 0 3 10 Not Evaluated 3.00 Not Evaluated
signaling of
Building
Management
System (BMS)
Manual Load 59 59 69 8.40 11.6 $81
Curtailment
Wi-fi 1 1 TBD Not Evaluated TBD Not Evaluated
thermostats
*Based on number of customers currently signed up but not yet installed, and customers that are close to finalizing
sign up. **Cost per kW-year is based on an upfront incentive spread over the life of the equipment . Full scale
19
program will be based on a different incentive model (pay-for-performance).Eversource – Impact Evaluation
Findings
▪ Batteries and manual load curtailment performed as expected
▪ Manual load curtailment relies on a portfolio of sites; performance at any given
site and on any given day varies, but across the portfolio large demand
reductions are possible for a limited number of hours each season
▪ Batteries provide a reliable, predictable load reduction that can be called every
day
▪ Results for thermal storage were less clear; evaluators will validate results
in Summer 2019
▪ Software signaling of BMS had long sales cycle and limited customer
acceptance
▪ Wi-fi thermostats challenging to deploy through direct install vendors
▪ Most technologies can save energy, but battery solutions require higher
energy use, and battery efficiency varies
▪ There is potential for interaction between Eversource demand response
projects and ISO NE markets, which if not handled carefully could lead to
conflicting obligations and/or reduced claimable savings
20Eversource – Comparison of
Strategies
▪ Daily dispatch batteries provides a predictable reduction of load
every day, while manual curtailment performance varies by event
Average Dispatch Day (Aug 22–Sept 28) Manual Curtailment Demand Reduction by
for Large Battery with Daily Dispatch Event (Adjusted 10 of 10 baseline)
21
21Eversource – Process Evaluation
Findings
▪ Participating customers were very satisfied with their respective projects
▪ Recruiting was challenging for summer 2018 for all but two vendors
▪ Lack of an existing customer base in MA slowed some vendors
▪ Competing priorities for Eversource account executives who could
facilitate customer relationships led to delays with some vendors
▪ Unfamiliar technologies
and a new value
proposition slowed uptake
▪ Training needed re: demand
reduction value and new
approaches (esp. thermal
storage)
22C&I Findings
▪ Manual curtailment is much less expensive than other forms
of active demand reductions
▪ Different technologies are suited to different dispatch
strategies:
▪ Curtailment must be targeted
▪ Batteries and thermal storage can reduce load on a daily basis
without impacting customers comfort or operations
▪ Customers do not accept demand reduction solutions if
▪ The value proposition is not clear
▪ If customers have to cede too much control over their systems
(even in cases where a solution is fully paid for by the PA)
▪ More training needed for sales representatives to explain
value proposition and technologies to customers
232019-2021 C&I Program Design
3 Options to Curtail – C&I
Program Parameters Typical Application
Targeted • 3 - 8 events per summer
Dispatch • 3 hours per event
• $35/kW-summer
• Eversource only: Targeted Storage
$100/kw-summer
Daily Dispatch • 30 - 60 events per summer,
Per Order: • 2 - 3 hours per event
Demonstration for 2019
– expect to reach full
• $200/kW-summer
offering for 2020
Winter • 5 events per winter
Dispatch • 3 hours per event
• $25/kW-winter
25Strategies and Technologies
Typical to Dispatch Scenarios
Targeted Dispatch Daily Dispatch Winter Dispatch
• Usually Manual • Usually Automatic • Usually Manual
• Temperature • Batteries • Snowmaking
setback ~3F • Flywheels • Industrial
• VFD speed • Thermal Storage Processes
limiting • Industrial Freezers • Generators
• Early setback
• Process Changes
• Rarely Lighting
• Generators
• Combined Heat
and Power
26Optimizing Event Windows –
Summer Scenarios
▪ Events are still only 3 hours
long, but now they can happen
between 2pm and 7pm.
Option 1: 3 hours
Option 2: 3 hours
Option 3: 3 hours
2pm 3pm 4pm 5pm 6pm 7pm
272019-2021 Plan & DPU Order
Statewide Active Demand –
Planned Summer
29Statewide Active Demand –
Planned Winter
302019-2021 Plan Proposal for Active
Demand Reduction - Statewide
Sum of Max Net kW Sum of Incentive (Total) Sum of Incentive (Total)
Sector/Season/Dispatch Type 2019 2020 2021 2019 2020 2021
A - Residential
Summer 8,698 15,167 19,354 $560,335 $4,420,511 $5,591,312 $10,572,158
Direct Load Control 8,305 11,515 14,273 $544,598 $712,861 $891,786 $2,149,246
Storage Daily Dispatch, discharge (savings) Summer 0 1,913 2,946 $0 $438,130 $675,686 $1,113,816
Storage System and Performance, discharge (savings) Summer 0 1,250 1,539 $0 $3,250,000 $4,000,000 $7,250,000
EV Load Management (Summer) 393 488 596 $15,736 $19,520 $23,840 $59,096
Winter 1,346 3,651 5,081 $62,834 $134,280 $209,515 $406,629
Storage Targeted Dispatch, discharge (savings) Winter 953 1,913 2,946 $58,900 $129,400 $203,555 $391,855
Storage System and Performance, discharge (savings) Winter 0 1,250 1,539 $0 $0 $0 $0
EV Load Management (Winter) 393 488 596 $3,934 $4,880 $5,960 $14,774
B - Income Eligible
Summer 0 289 385 $0 $750,000 $1,000,000 $1,750,000
Storage System and Performance, discharge (savings) Summer 0 289 385 $0 $750,000 $1,000,000 $1,750,000
Winter 0 289 385 $0 $0 $0 $0
Storage System and Performance, discharge (savings) Winter 0 289 385 $0 $0 $0 $0
C - Commercial & Industrial
Summer 94,817 143,053 192,580 $4,307,085 $9,728,663 $14,283,823 $28,319,571
Interruptible Load 93,317 124,858 159,885 $4,019,585 $5,491,996 $7,172,156 $16,683,737
Storage Daily Dispatch, discharge (savings) 0 10,100 17,100 $0 $2,395,000 $4,095,000 $6,490,000
Storage Targeted Dispatch, discharge (savings) Summer 500 5,000 10,000 $62,500 $625,000 $1,250,000 $1,937,500
Custom 1,000 2,903 5,403 $225,000 $716,667 $1,266,667 $2,208,334
Storage System and Performance, discharge (savings) Summer 0 192 192 $0 $500,000 $500,000 $1,000,000
Winter 15,310 32,202 44,722 $642,600 $1,490,900 $2,129,300 $4,262,800
Winter Interruptible Load 12,790 24,910 33,430 $577,600 $1,110,900 $1,449,300 $3,137,800
Storage Targeted Dispatch, discharge (savings) Winter 2,520 7,100 11,100 $65,000 $380,000 $680,000 $1,125,000
Storage System and Performance, discharge (savings) Winter 0 192 192 $0 $0 $0 $0
Total Summer 103,515 158,508 212,319 $4,867,420 $14,899,174 $20,875,135 $40,641,729
Total Winter 16,656 36,142 50,188 $705,434 $1,625,180 $2,338,815 $4,669,429
312019-2021 DPU Order for Active
Demand Reduction
National
Initiative/Offering CLC Eversource Unitil Notes
Grid
CLC can pursue once agreement with Eversource and
Residential DLC - Tstat X X X X
approval from DPU
Residential DLC - WH - - - - no one is pursuing
demo for 2019, per order, assume full offering in 2020-
Residential - Daily Dispatch X X X X*
2021; summer & winter (targeted); CLC deferred
Residential DLC - EVs X X - Eversource Demo, National Grid DLC claimed savings
CLC can pursue once agreement with Eversource and
C&I Interruptible - Targeted X X X X
approval from DPU; summer & winter (targeted)
demo for 2019, per order, assume full offering in 2020-
C&I - Daily Dispatch X X X X
2021; summer & winter (targeted); CLC deferred
C&I Storage - Targeted Dispatch X summer & winter (targeted)
C&I ADR Custom - TBD - - - - TBD
* Unitil will consider moving forward in 2020-2021 pending evaluation results due in the Spring of 2020 and any other constraints.
Order Highlights:
• Statewide Proposals
• All Approved, except Daily Dispatch Storage
• Full scale deployment not allowed, PA may use a portion of the proposed on daily dispatch
demo offering and seek approval
• Five Year Commitments Approved
• Higher Incentive Levels for Daily Dispatch is Appropriate
• Compact
• DPU recognizes CLC efforts/creativity, but CVEO and enhanced storage offer not approved; may
not offer active demand until an agreement between Eversource and Compact is reached.
• Gas Demand Response
• Gas PAs must continue to review the potential for cost-effective savings from gas demand response
offerings, and as part of the next 3YP include detailed testimony and exhibits addressing such 32
continued study and the feasibility of gas demand response offerings.Evaluations Planned
33From the SEP
▪ From Strategic Evaluation Plan
▪ Near-term
▪ For residential, continuing to develop estimates of demand
savings, including the timing of the savings (i.e., load shapes).
▪ Longer-term
▪ For residential, Characterization of EE/DR Storage Ability.
Assess the electricity-equivalent capacity of various “thermal
batteries” using smart controls to load shift using smart
thermostats and smart water heaters
▪ For special and cross cutting: Conduct research supporting new
active demand programs and policy frameworks.
▪ For C&I: Although active demand currently resides in SCC,
demand studies may become more important in the future and
require C&I research area effort.
34Thank you
For Reference Only
2019-2021 Plan Proposal for
Active Demand Reduction - CLC
Sum of Incentive
Sum of Max Net kW Sum of Incentive (Total) (Total)
PA/Sector/Season/Dispatch Type 2019 2020 2021 2019 2020 2021
CLC
A - Residential
Summer 1,055 2,869 3,400 $86,310 $3,347,851 $4,099,320 $7,533,481
Direct Load Control 1,055 1,618 1,861 $86,310 $97,851 $99,320 $283,481
Storage System and Performance, discharge (savings) Summer 0 1,250 1,539 $0 $3,250,000 $4,000,000 $7,250,000
Winter 0 1,250 1,539 $0 $0 $0 $0
Storage System and Performance, discharge (savings) Winter 0 1,250 1,539 $0 $0 $0 $0
B - Income Eligible
Summer 0 289 385 $0 $750,000 $1,000,000 $1,750,000
Storage System and Performance, discharge (savings) Summer 0 289 385 $0 $750,000 $1,000,000 $1,750,000
Winter 0 289 385 $0 $0 $0 $0
Storage System and Performance, discharge (savings) Winter 0 289 385 $0 $0 $0 $0
C - Commercial & Industrial
Summer 117 6,053 6,080 $9,585 $888,663 $888,823 $1,787,071
Interruptible Load 117 5,458 5,485 $9,585 $221,996 $222,156 $453,737
Custom 0 403 403 $0 $166,667 $166,667 $333,334
Storage System and Performance, discharge (savings) Summer 0 192 192 $0 $500,000 $500,000 $1,000,000
Winter 0 192 192 $0 $0 $0 $0
Storage System and Performance, discharge (savings) Winter 0 192 192 $0 $0 $0 $0
Note: CLC Storage System & Performance offering builds cumulatively, also subject to DPU and Eversource agreements 372019-2021 Plan Proposal for Active
Demand Reduction - Eversource
Sum of Incentive
Sum of Max Net kW Sum of Incentive (Total) (Total)
PA/Sector/Season/Dispatch Type 2019 2020 2021 2019 2020 2021
Eversource
A - Residential
Summer 2,000 3,150 4,250 $160,000 $281,250 $388,750 $830,000
Direct Load Control 2,000 3,000 4,000 $160,000 $240,000 $320,000 $720,000
Storage Daily Dispatch, discharge (savings) Summer 0 150 250 $0 $41,250 $68,750 $110,000
Winter 50 150 250 $13,750 $41,250 $68,750 $123,750
Storage Targeted Dispatch, discharge (savings) Winter 50 150 250 $13,750 $41,250 $68,750 $123,750
B - Income Eligible
Summer 0 0 0 $0 $0 $0 $0
Winter 0 0 0 $0 $0 $0 $0
C - Commercial & Industrial
Summer 27,500 57,500 96,000 $1,412,500 $4,325,000 $7,700,000 $13,437,500
Interruptible Load 27,000 47,000 75,000 $1,350,000 $2,350,000 $3,750,000 $7,450,000
Storage Targeted Dispatch, discharge (savings) Summer 500 5,000 10,000 $62,500 $625,000 $1,250,000 $1,937,500
Storage Daily Dispatch, discharge (savings) 0 5,000 10,000 $0 $1,250,000 $2,500,000 $3,750,000
Custom 0 500 1,000 $0 $100,000 $200,000 $300,000
Winter 6,770 13,750 22,750 $340,000 $837,500 $1,437,500 $2,615,000
Winter Interruptible Load 6,750 11,750 18,750 $337,500 $587,500 $937,500 $1,862,500
Storage Targeted Dispatch, discharge (savings) Winter 20 2,000 4,000 $2,500 $250,000 $500,000 $752,500
382019-2021 Plan Proposal for Active
Demand Reduction – National Grid
Sum of Incentive
Sum of Max Net kW Sum of Incentive (Total) (Total)
PA/Sector/Season/Dispatch Type 2019 2020 2021 2019 2020 2021
National Grid
A - Residential
Summer 5,550 9,036 11,570 $306,375 $786,480 $1,097,326 $2,190,181
Direct Load Control 5,156 6,785 8,278 $290,638 $370,080 $466,550 $1,127,268
Storage Daily Dispatch, discharge (savings) Summer 0 1,763 2,696 $0 $396,880 $606,936 $1,003,816
EV Load Management (Summer) 393 488 596 $15,736 $19,520 $23,840 $59,096
Winter 1,296 2,251 3,292 $49,084 $93,030 $140,765 $282,879
Storage Targeted Dispatch, discharge (savings) Winter 903 1,763 2,696 $45,150 $88,150 $134,805 $268,105
EV Load Management (Winter) 393 488 596 $3,934 $4,880 $5,960 $14,774
B - Income Eligible
Summer 0 0 0 $0 $0 $0 $0
Winter 0 0 0 $0 $0 $0 $0
C - Commercial & Industrial
Summer 67,000 79,000 90,000 $2,865,000 $4,455,000 $5,635,000 $12,955,000
Interruptible Load 66,000 72,000 79,000 $2,640,000 $2,880,000 $3,160,000 $8,680,000
Storage Daily Dispatch, discharge (savings) 0 5,000 7,000 $0 $1,125,000 $1,575,000 $2,700,000
Custom 1,000 2,000 4,000 $225,000 $450,000 $900,000 $1,575,000
Winter 8,440 17,960 21,480 $300,100 $643,400 $681,800 $1,625,300
Winter Interruptible Load 5,940 12,960 14,480 $237,600 $518,400 $506,800 $1,262,800
Storage Targeted Dispatch, discharge (savings) Winter 2,500 5,000 7,000 $62,500 $125,000 $175,000 $362,500
392019-2021 Plan Proposal for Active
Demand Reduction – Unitil
Sum of
Sum of Max Net kW Sum of Incentive (Total) Incentive (Total)
PA/Sector/Season/Dispatch Type 2019 2020 2021 2019 2020 2021
Unitil
A - Residential
Summer 94 112 135 $7,650 $4,930 $5,916 $18,496
Direct Load Control 94 112 135 $7,650 $4,930 $5,916 $18,496
Winter 0 0 0 $0 $0 $0 $0
B - Income Eligible
Summer 0 0 0 $0 $0 $0 $0
Winter 0 0 0 $0 $0 $0 $0
C - Commercial & Industrial
Summer 200 500 500 $20,000 $60,000 $60,000 $140,000
Interruptible Load 200 400 400 $20,000 $40,000 $40,000 $100,000
Storage Daily Dispatch, discharge (savings) 0 100 100 $0 $20,000 $20,000 $40,000
Winter 100 300 300 $2,500 $10,000 $10,000 $22,500
Winter Interruptible Load 100 200 200 $2,500 $5,000 $5,000 $12,500
Storage Targeted Dispatch, discharge (savings) Winter 0 100 100 $0 $5,000 $5,000 $10,000
40Basics of Targeted Dispatch
• Typically 3 – 6 events per summer
• 3 hours per event
• Between 2 – 7pm
• Customers/Vendors are notified the
day before.
• Weekdays
• Not Holidays
• Paid by performance: $35/kW-
summer
41Basics of Daily Dispatch
Demonstration for 2019
• Typically 30–60 events per summer
• 2 - 3 hours per event
• Between 2 – 7pm
• Customers/Vendors are notified the day before.
• Weekdays
• Not Holidays
• Events called in June, July, August, and September, but mostly
in July and August
• Paid by performance: $200/kW-summer
• Performance incentive locked for first 5 years
42Basics of Winter Dispatch
• 5 events per winter
• 3 hours per event
• Time of day - TBD
• Customers/Vendors are notified the day before.
• Weekdays
• Not Holidays
• December, January, February, March
• Paid by performance $25/kW-winter
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