HomeMy WebLinkAbout02/08/2024 - Energy Board - Agenda - Regular Meeting
ENERGY BOARD
REGULAR MEETING
February 8, 2024 – 5:30 pm
222 Laporte Ave – Colorado Room
Zoom – See Link Below
1. [5:30] CALL MEETING TO ORDER
2. [5:30] PUBLIC COMMENT
3. [5:35] APPROVAL OF JANUARY 11, 2023 MINUTES
4. [5:45] STAFF REPORTS (Discussion, 15 Min.)
• Riverside Community Solar Garden Update (Packet Item Only)
5. [6:00] BUILDING PERFORMANCE STANDARDS COUNCIL RECOMMENDATIONS
(Discussion, 45 Min.)
Brian Tholl, Utilities Senior Energy Services Manager
Katherine Bailey, Project Manager, Utilities Customer Connections
6. [6:45] VIRTUAL POWER PLANTS (Discussion, 45 Min.)
Brian Tholl, Utilities Senior Energy Services Manager
7. [7:30] MEMO RE: PLATTE RIVER’S NATURAL GAS TURBINE (Decision, 30 Min.)
8. [8:00] BOARD MEMBER REPORTS (5 min.)
9. [8:05] FUTURE AGENDA REVIEW (5 min.)
10. [8:10] ADJOURNMENT
Participation for this Energy Board Meeting will be in person in the Colorado Room at
222 Laporte Ave.
You may also join online via Zoom, using this link: https://fcgov.zoom.us/j/96707441862
Online Public Participation:
The meeting will be available to join beginning at 5:15 pm, February 8, 2024. Participants
should try to sign in prior to the 5:30 pm meeting start time, if possible. For public comments,
the Chair will ask participants to click the “Raise Hand” button to indicate you would like to
speak at that time. Staff will moderate the Zoom session to ensure all participants have an
opportunity to address the Board or Commission.
To participate:
• Use a laptop, computer, or internet-enabled smartphone. (Using earphones with a
microphone will greatly improve your audio).
• You need to have access to the internet.
• Keep yourself on muted status.
ENERGY BOARD
January 11, 2024 – 5:30 pm
222 Laporte Ave – Colorado Room
ROLL CALL
Board Members Present: Bill Althouse, Marge Moore, Alan Braslau, Stephen Tenbrink (remote), Brian
Smith, Bill Becker (remote), Thomas Loran
Board Members Absent: Jeremy Giovando
OTHERS PRESENT
Staff Members Present: Christie Fredrickson, Phillip Amaya, Cyril Vidergar, Brian Tholl (remote),
Michael Authier, Leland Keller, Lance Smith, Nick Combs
Members of the Public:
MEETING CALLED TO ORDER
Chairperson Tenbrink called the meeting to order at 5:30 pm.
ANNOUNCEMENTS & AGENDA CHANGES
None.
PUBLIC COMMENT
None.
APPROVAL OF MINUTES
In preparation for the meeting, board members submitted amendments via email for the December 14,
2023, minutes. The minutes were approved as amended.
DISCUSS RATE INCREASE COMMUNICATION
Lance Smith, Senior Director, Utilities Finance
Nick Combs, Communications & Marketing Manager
Board members discussed a recent communication pamphlet that went out in Utility Bills that states:
“[Electric rates will have a] 5% average increase due to higher generation costs associated with new,
renewable resources and capital projects like transformer and cable replacements.”
Board members feel the messaging implies the rates are increasing due to renewable generation, which
is not consistent with the messaging they believe they heard from Platte River. Mr. Smith explained there
was a 5% increase in purchased power costs this year, which was attributed to the cost of renewables,
which is why that language was included on the bill insert. Board member Braslau believes that’s a
misrepresentation, the cost stems from the projection of eliminating coal and the associated profits from
that generation.
Mr. Smith said he recognizes that the Board does not agree with Platte River’s plans to add natural gas
generation, but that is the position Platte River has taken, and they are doing so with the intent to stabilize
their renewable resources. He also said he understands that the Board would have deemed other
language (such as “…associated with new renewable and natural gas resources) to be more holistic, and
ENERGY BOARD
REGULAR MEETING
it is something staff can consider in future rate communications, but staff maintains the phrasing is
accurate as it was printed.
Board member Loran said he does not currently agree with some of the other Board members’ stance on
the natural gas turbine, but he pointed out that this is a discussion of capital costs (in renewables) versus
a fully depreciated coal plant. There will obviously be a lot of capital costs, but when it comes to variable
costs, the marginal cost of producing renewable energy approaches zero, whereas there is a moderate
variable cost when producing coal. He believes this is a cost allocation question that he does not have the
answer to. Mr. Smith said most of the renewable energy Platte River is acquiring is through PPAs (power
purchase agreements), so it is a fixed cost, and it will not approach zero through the life of the contract.
Board member Braslau said this is a complex economic situation where Platte River is transitioning from
running a coal plant that is already paid for and profitable (even with operating costs). It doesn’t matter
how the power is being generated, the reality is Platte River is projecting price increases because they
are going from an unsustainable but profitable situation that has to be shut down by law, and that has a
cost.
Mr. Smith asked the Board how they would have preferred the communication to be worded. Board
member Braslau said the increase language should have been prefaced with, “in transitioning away from
coal generation…” Mr. Smith said staff wanted to communicate that the community is moving toward
renewable generation. If that part had been left out, and only outlined that we were moving away from
coal, the public may be left wondering what we were moving toward. Board member Moore said there are
two pieces to the message, that we are moving away from coal generation and moving toward renewable
energy. Board member Loran pointed out that there is a capacity requirement for Platte River to join a
regional market, so the question is in shutting down the coal plant, is Platte River replacing that
generation with renewables or natural gas.
Chairperson Tenbrink explained that he did not have a specific goal for this conversation, but he thought
it was important for Board member Giovando’s comments to be heard and give staff a chance to provide
perspective. He added that it may be beneficial for the pamphlet to be updated in future iterations to
mention the retirement of coal resources without getting too bogged down in the details.
DISCUSS MEMO TO CITY COUNCIL RE: PLATTE RIVER’S PLANS FOR
A NATURAL GAS TURBINE
Board member Tenbrink explained that the Board had discussed potentially writing a memo to City
Council about Platte River’s plans to build a natural gas turbine. He also noted that he was disappointed
that the City’s representatives on Platte River’s Board of directors did not reach out to the Energy Board
for their opinion.
Board member Loran said he does not necessarily agree with the Board’s objection to the natural gas
plants. He does agree with many of their points, but he does not feel comfortable saying there is no need
for any gas-powered plant. His question is, operationally, what is the planned frequency of use for the
turbine? He believes the plant should be reserved for a “break-the-glass,” 100-hour dark calm (when
there are no renewables generating power) type of emergency. He does not want to see it run to send
power to the market and would also like to see Platte River add more storage. Board member Braslau
said economically, the turbine will run whenever the market, or the conditions call for it.
ENERGY BOARD
REGULAR MEETING
Mr. Authier clarified that though Platte River does have a capacity requirement to join the market, they set
the prices for their resources.
Board member Althouse said with the technology on the horizon, the last thing that should have been
chosen was a gas plant and he believes Platte River knows that gas plants are on their way to obsoletion,
but it was identified as a time-critical need, which is why it was written outside of their Integrated
Resource Plan.
Chairperson Tenbrink explained it was not his goal for the memo to sound like the Board is completely
opposed to the gas plant, but more wondering why this process wasn’t communicated better (from a
public perspective, and why an Open RFP wasn’t considered.
Board members discussed the need for increased transparency from Platte River. They agreed that the
memo needs additional work. Board member Loran said he would like to see the memo updated to say
the Board has some concerns about the gas plant, including how often it will run, how it will work within
the regional market, and how it is in conflict with the City’s climate messaging.
REVIEW 2024 PLANNING CALENDAR
Board members expressed interest in targeting a few select items to promote and draw attention to for
City Council. Chairperson Tenbrink said he would like to spend more time discussing and learning about
Virtual Power Plants (VPPs), possibly at a work session.
Mr. Vidergar encouraged the Board to figure out how we communicate the current concerns and
emerging concerns to the City’s Platte River representatives as well as to City Council. He advised that
the Board is often reactive, due to the timing of information delivery, so this could be an avenue that could
lead to better results. The Energy Board and City Staff don’t have the power to make Platte River do
anything, but their Board of Directors can.
Board member Braslau noted that discussions centering around how the City can get away from Platte
River are not constructive or useful, he believes there is a lot more to gain by looking at how the City can
transform their relationship with Platte River in a way that helps the community reach its goals. Mr. Amaya
agreed, Platte River has to change and is currently changing with their imminent entry into the market.
Board member Althouse said VPPs are a viable path forward toward the City’s climate goals. He
explained it supports rapid electrification, paying participating end-users (also known as prosumers) for
balancing demand on the grid locally through distributed energy resources and supporting systems.
Board members and staff discussed the implementation of VPPs and how it could potentially be done in a
financially and socially equitable way. Board members agreed the topic of VPPs could be on the calendar
for a future work session.
Board members also discussed utilizing a work session to invite City Council members and Platte River
Board of Director members to discuss alignment, as Mr. Vidergar suggested.
APPROVE 2023 ANNUAL REPORT
Board members reviewed the new comments and edits in their Annual Report. They agreed the report
accurately captured the work from the previous year and are prepared to submit it for publication.
ENERGY BOARD
REGULAR MEETING
VICE CHAIRPERSON ELECTION
Board member Loran Nominated himself for the position of Energy Board Vice Chairperson.
Board member Moore nominated Board member Althouse for Energy Board Vice Chairperson.
Board member Becker moved to appoint Board member Loran as Vice Chairperson until the next
Energy Board Officer election.
Board member Braslau seconded the motion.
Discussion:
None.
Vote on the motion: It passed, unanimously 7-0, with one absent.
BOARD MEMBER REPORTS
Board member Loran’s ductless mini splits are failing, they are putting out too much heat and becoming
difficult to control. He said he will report back in February how the cold snap goes with his heat pump.
Board member Braslau went to speak in front of Council in December during public comment, urging City
Council to leverage the City’s building code and land use code to enforce the urgency of the climate
emergency, and not to contradict the community’s climate goals.
Mr. Amaya notified the Board that Mr. Minor will be moving on from the organization and Fort Collins
Utilities, his last day with the City of Fort Collins will be January 23.
ADJOURNMENT
The Energy Board adjourned at 7:55 pm.
Utilities
electric · stormwater · wastewater · water
222 Laporte Ave.
PO Box 580
Fort Collins, CO 80522-0580
970.212.2900
V/TDD: 711
utilities@fcgov.com
fcgov.com/utilities
M E M O R A N D U M
DATE: February 5, 2024
TO: Fort Collins Energy Board
FROM: Brian Tholl, Energy Services Manager
Leland Keller, Sr. Energy Services Engineer
THROUGH: Philip Amaya, Energy Board Staff Laison
RE: Riverside Community Solar Project outage
This memo provides an update on the status of operations at the Riverside Community Solar
Project (Riverside), restoration actions underway, and participant engagement.
BOTTOM LINE
Utilities staff are working to restore solar generation at Riverside, which stopped generating
electricity on August 20, 2023. Utilities staff have notified Riverside customer-owners of the
outage and have provided relevant updates related to re-energizing the system. We are working
diligently to solicit bids for replacing the inverter system to return Riverside to normal operation
in a financially responsible manner.
BACKGROUND
The Riverside Community Solar Project was established in 2015 under agreement with Clean
Energy Collective to develop, own and operate Riverside. Community Solar provides Utilities
electric customers the opportunity to own solar generation assets without installing solar at their
home. Utilities acquired the Project, including all responsibilities and assets owned or controlled
by Clean Energy Collective in 2020 and adopted Program Rules as approved by Council
(Ordinance No. 141-2020). The Program Rules and Customer Agreement have been consistent
since Riverside inception and are posted on the program web page.
Since the site’s inverter failure in August, Utilities staff have been working closely with partners
to troubleshoot and fix the problem. Utilities staff will soon release a request for proposals (RFP)
soliciting bids from qualified solar contractors to replace the failed inverter equipment. This will
include a redesign option for solar contractors which is intended to maximize the useful life of
the site, minimize the life cycle cost, and complete the repowering project as soon as possible.
Utilities staff have communicated three updates to participants and established a web page with
resources including a history of communications and latest updates. Utilities staff are evaluating
several options for funding repair and will ultimately depend on the total proposed cost for
replacement as identified through the upcoming RFP.
DocuSign Envelope ID: F12EEB5A-B2C6-400F-BAE3-C6F285898525
Several community solar owners have expressed frustration about the long duration of the
current outage and resulting absence of generation credits. Riverside participants receive
credits on their bill based on the solar generation at the site. The average community solar
participant owns 10 panels at Riverside. Monthly credits average approximately $10 per month
in the winter, up to approximately $30 per month in the summer, for a total annual benefit of
approximately $275 for the average participant.
NEXT STEPS
Utilities staff continue to work to find solutions to re-energizing the array, including the following
next steps:
• Launch a public bidding process in February 2024
• Evaluate the cost of repairs and equipment replacement options;
• Communicate updates to participants about advancements in re-energizing Riverside;
• Provide another memo update to City Leadership when solution and timeframe for repair
is available.
CC: Mayor Jeni Arndt, City Council Liaison, Fort Collins Energy Board
Gretchen Stanford, Utilities Deputy Director, Customer Connections
Christie Fredrickson, Utilities Administrative Assistant, Light & Power
DocuSign Envelope ID: F12EEB5A-B2C6-400F-BAE3-C6F285898525
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Program Manager
Katherine Bailey
Building
Performance
Standards
2.8.2024
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2
OCF: The Role of Buildings
Emissions Avoided vs
2005 Pathway Group
2030
Electricity 27.1%
Buildings
•Performance
•Construction
•Electrification
16.7%
•16.1%
•0.3%
•0.3%
Transportation 4.4%
Industry 4.1%
Waste 1.6%
Land Use 0.1%
Buildings in Fort Collins contribute to more than 2/3 of our community carbon emissions
Emissions Avoided vs
2005 Pathway Group
2030
Electricity 27.1%
Buildings
•Direct
•(BEWS, BPS)
•Incentive
16.7%
•8.9
•7.8%
Transportation 4.4%
Industry 4.1%
Waste 1.6%
Land Use 0.1%
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3
Building Performance Standards
•BPS is by far the most impactful direct action the
City can take to reduce emissions by 2030
•BPS has a much higher impact on natural gas than
other Utilities programs
•The impact of BPS by 2030 is projected to be just
under that of all other efficiency programs combined
•132.5k MTCO2e for BPS, 184.3k MTCO2e
from all other efficiency programs combined
Live Better
Big Move 6:
Explore Building Performance Standards
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4
BPS Community Impacts
Disproportionately impacted communities benefit from BPS
Local Benefits Health
Safety
Comfort
Resilience
Reduced energy burden
Economic growth
Increased competitiveness
Higher building occupancy and tenant retention
Increased productivity of occupants
Mitigate utility impacts of rising temperatures
Improved indoor and outdoor air quality
Headline Copy Goes Here 5BPS Development Work
•Timeline
O N D J F M A M J J A S O N D J F M A M J J
Internal
Stakeholders
Task Force
Technical
Committee
Cost Benefit
Analysis
Target Setting
Target Council
Worksession
Targets
2027, 2030
2022 2023 2024
Headline Copy Goes Here 6Task Force Recommendations
Task Force Recommendations are published at ourcity.fcgov.com/bps
Final Recommendations
•Covered buildings
•5,000ft2+
•Small building cohort
•Targets
•Energy Use Intensity
•Explore alternate pathways/ adjustments
•Resources
•All v under-resourced buildings
Headline Copy Goes Here 7Topics to date
Technical Committee Recommendations
Completed/underway
•Targets
•Small buildings
•Alternate pathways
Upcoming
•Target setting methodology
•Penalties
•Costs
•Council direction
Headline Copy Goes Here 8Alternate Pathways
Renewables in BPS
Renewables in Practice
State
For buildings unable to meet their target, after all feasible efficiency measures have been
met
Denver
Gap filler for aggressive targets, prescriptive option for small buildings
Best Practice
“BPS should be designed and implemented such that there is no option for buildings to use
renewable energy procurement as an alternative for bold action on energy efficiency,
electrification, and demand management” -IMT
Headline Copy Goes Here 9Renewables
Efficiency Enables Renewables
Renewables and Efficiency
•Efficiency reduces energy use
•Reduced energy use increases impact of existing and new solar
•Impact of electrification
Local Renewables Percent of Resource Mix (generation % of operational consumption)
0.1%0.2%0.2%0.2%0.3%0.4%0.6%0.9%1.0%1.2%1.5%
1.9%
2.2%
2.6%
3.2%
0.0%
0.5%
1.0%
1.5%
2.0%
2.5%
3.0%
3.5%
20
0
5
20
0
6
20
0
7
20
0
8
20
0
9
20
1
0
20
1
1
20
1
2
20
1
3
20
1
4
20
1
5
20
1
6
20
1
7
20
1
8
20
1
9
20
2
0
20
2
1
20
2
2
20
2
3
with efficiency impact
0.1%0.2%0.2%0.2%0.3%0.3%0.6%0.8%1.0%1.1%1.3%1.6%1.8%2.1%2.5%
0.3%0.3%
0.4%
0.7%
0.0%
0.5%
1.0%
1.5%
2.0%
2.5%
3.0%
3.5%
20
0
5
20
0
6
20
0
7
20
0
8
20
0
9
20
1
0
20
1
1
20
1
2
20
1
3
20
1
4
20
1
5
20
1
6
20
1
7
20
1
8
20
1
9
20
2
0
20
2
1
20
2
2
20
2
3
Headline Copy Goes Here 10Renewables
Renewables in Fort Collins
•11 programs targeting
renewables in FC
•Average commercial
building with solar in
2022 met ~20% of their
annual load with onsite
solar
•~50 potentially
covered buildings
currently have onsite
solar
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11
Renewables
Considerations regarding offsite
•Onsite vs offsite
•Encouraging owners to purchase
additional RECs won’t change our
community inventory or make any
progress toward our goals
•Variable opportunity with onsite alone (but
that’s true with everything)
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12
Renewables
What should the role of renewables be in FC BPS?
Considerations
•Task Force (focus on flexibility)
•Role of target adjustments
Questions
•Performance v renewables – what is our ‘lane’?
•Efficiency first (State of CO) v. option for all
•Capping solar contribution to BPS targets
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For Questions on BPS:
13
Kbailey@fcgov.com
970-221-6818
Program Manager, Energy Services
Katherine Bailey
Headline Copy Goes Here
Manager of Distributed Energy Resources
Platte River Power Authority
Paul Davis
Energy Services Manager
Fort Collins Utilities
Brian Tholl
2.8.24
Virtual Power Plant
Introduction
Headline Copy Goes HereWhat is a Virtual Power Plant?
2
•A virtual power plant (VPP) is a network of
distributed energy resources (DERs) and
systems that, when grouped together,
can provide a reliable power supply for energy
users.
•This differs from “traditional” centralized, large-
scale power generation and delivery.
•VPPs are regionally unique, and built to handle
several use cases.
•VPPs require programs to support DER adoption.
•VPP best practices continue to emerge.
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3
Structured Approach to VPP Planning
Assess
•Drivers
•Goals
•Desired outcomes
•Challenges
•Benefits
Identify
•Services
•Functional capabilities
•Target technology roadmap
Determine
•Current state
•Gap analysis
•Roadmap
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4
Goals for VPP development
Goals
Drivers
Enhanced
customer
experience
Reliability Financial
sustainability
Environmental
responsibility
1.Provide DER benefits to all customers and facilitate DER
deployment X X X
2.Embed DERs into planning X X X
3.Facilitate DER enrollment, interconnection, and aggregation X X X
4.Integrate DERs into operations X X X X
5.Institute common standards and processes for DERs
among Platte River and the owner communities X X X X
6.Incorporate safety in planning and operations X X X
7.Comply with cybersecurity and data privacy/
protection policies and standards X X X
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5
17 Functional Capabilities
And 160+ functional use cases (not shown)
Functional use cases define needed technology systems and architecture…
Aggregation-Independent (FERC 2222)
Aggregation-PRPA/OC
Analytics & Reporting
Architecture & Integration
DER Control & Dispatch (operate DERs)
DER Enrollment/Interconnection
DER Program Management
DER Visibility
Distribution Grid Management
Forecasting
Grid Reliability
Optimization
Planning
Safety, Security, and Compliance
Settlement/Billing
Telecom/Telemetry
Virtual Power Plant (VPP)
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6
Functional Use Cases: Examples
Analytics &
Reporting
ANR With the DERMS I want to…Additional Detail or Clarification Time
Frame
People/
Organizations
Systems/
Integrations/
Devices
Actual vs Forecast
Reporting
ANR-01
[PLA-03]
Generate standard and ad hoc reports showing actual
DER performance relative to forecast and disaggregated
from load at various levels/groupings
•Entire grid (All PRPA)
•Individual OC
•Individual substation
•Distribution feeder
•Aggregated DERs
•Individual DERs
•Custom groupings
•Weather effects on performance (actual vs forecast
weather
This reporting is mostly for internal use. Can be used
for human refinement to forecast algorithms and
DER settings
2027-1Q @
Launch
Evolves
DER Ops; IT/OT AMI
Data management
DER/DR
Platforms
Forecasting
Grid Edge
Systems
Individual DER
MDMS
Telecom
M&V Data ANR-02
[SBL-03]
[PLA-04]
Gather, format and package M&V data for generation of
M&V reporting. M&V reports may be generated by the
DERMS or DERMS will provide data to separate reporting
platform(s). Includes gathering M&V data from DER
platforms external to DERMS
Gather, format and package M&V data according to
PRPA and market standards. Send M&V data to
external M&V reporting platform-OR-DERMS
generations M&V reports directly. M&V reports
should be standard reports in a standard format (not
ad hoc).
Assumed M&V date will be inputs to Planning and
Forecast tools.
2027-1Q @
Launch
DER Ops
DIST Planning
GEN Planning
IT/OT
PGM Mgmt
TSM Planning
AMI
Data management
DER/DR
Platforms
DIST Planning
Forecasting
GEN Planning
Grid Edge
Systems
Individual DER
M&V Reporting
MDMS
Telecom
TSM Planning
Weather
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7
Virtual Power Plant (VPP) Ecosystem
Customers
Adopt DERs and
participate in VPP to:
Fort Collins & Owner Community (OC) utilities
Enable DER adoption and Participation
Platte River
Enable DER adoption and VPP Participation
Market
(SPP RTOW 2026)
Enable DER adoption and VPP Participation
•Provide service
Productivity
Comfort
Convenience
Reliability
Resilience
•Decarbonize
•Save money
•Provide customer
service
•Decarbonize
•Improve reliability
and resilience
•Manage costs
•Serve owner
communities
•Decarbonize
•Improve reliability
and resilience
•Manage costs
•Improve reliability
and resilience
•Economically serve
load
Policies Requirements Agreements Systems Programs Integrations Data/Information Value
Headline Copy Goes HereTarget Technology Landscape: Draft
8
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9
Target Technology Landscape: Supporting Acronyms for Draft
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10
Strategies for DER Management
Maximum DER benefits will come from suite of solutions
Control
Request: notification
Rates: time varying price signals
Behavioral: education
Passive: efficiency, building and equipment optimization
Headline Copy Goes HereChallenges: Electric Vehicle Load Management
11
Not connected to vehicle
Not plugged into charger
Not actually charging
The customer opted out
Max Load Available is ~ 7.8 kW per EV.
But then one or more of the following challenges
arise:
This will result in average load shed by controlled
device to be 0.4-1.0 kW
Headline Copy Goes HereChallenges: Thermostat Load Management
12
Max Load Available is 3 kW per enrolled thermostat.
But then one or more of the following challenges
arise:
Thermostat not connected
Thermostat is in cooling mode
Customer opts out
Customer overrides
This will result in average load shed by controlled
device to be 0.6-1.0 kW
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13
Capacity Reduction Findings: DER Potential Study
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14
Key Takeaways: DER Potential Study
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15
Customer Perspective: FC Solar + Storage Program Survey
What other concerns do you have about connecting to a system that allowed
Fort Collins Utilities to manage a battery storage system at your home?
“I would not be interested in
having the city control my
battery at all. You should
incentivize us to act in the
way you’d like.”
“(I) Do not want
anyone to
manage my
system but me.”
“Battery technology, at this time,
has a short lifespan...on the
order of ~1500-2000 cycles
depending on how it is used. I'd
want to restrict that cycle use
to only peak-power times,
otherwise the cost benefit
greatly reduces.”
“I am not worried about
outages, we’ve had just 4
of any significant length in
30 years, all under 6 hours
max… I like the peak
shaving aspect for the
utility and us overall.”
“Don’t want it won’t use it if
mandated I will shut the system
down. It is mine not yours.”
“Security -
what if Fort
Collins Utilities
was hacked?
What could
happen to my
home and
system?”
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16
VPP (Topic Area 2): GRIP Concept Paper Overview
•Platte River Power AuthorityLead applicant
•Estes Park Power and Communications
•Fort Collins Utilities
•Longmont Power and Communications
•Loveland Water and Power
Utility Partners
•Front Range Community College
•Boulder County Workforce Development Offices
•Larimer County Workforce Development Offices
•Weld County Workforce Development Offices
•Energy Outreach Colorado
Other Partners
Total Project
Budget: $76M
•Federal
funds
30.4M
(40%)
•Applicant
Share:
Total Project Budget $76M
Federal Funds $30.4M Applicant Share $45.6M
60% - exceeded the 50%
minimum to make the
application more competitive
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17
VPP (Topic Area 2): GRIP Concept Paper Overview Cont’d
Scoring
Technical Portion (80%)Communities Benefit Plan (20%)
Community Benefits Plan include focus on:
Community and Labor Engagement
Workforce Development
DEIA
Disadvantaged Communities
Proposed Outcomes
(2025-2029)
Enroll 21,000 EVs in the VPP
Enroll 6,900 residential and 50 commercial customers in the VPP
Achieve 26MW of dispatchable capacity for the VPP
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Ongoing Optimization Required
•PRPA / FC impacts
•Carbon benefits,
•Customer benefits,
•Community benefits
•Market requirements
•Market readiness,
•Benefit / cost,
•Incentive sizing
•Dispatchability,
•Market impacts
•DER control integration,
•Utility use cases,
•Consumer use cases
•DERs deployed,
•Monitoring system,
•Communications,
•Controls
Technical Operational
PolicyProgrammatic
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Gaps & Next Steps
Support for infrastructure upgrades: from substation (PRPA/Utility) to customer electrical panels
Enabling Utilities Administrative Policies
System Integration (internal and external resources): ADMS enhancement and DERSM expansion
Customer programs and DER deployment
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Final Comments
Fort Collins and Platte River Power Authority
continue collaboration on DER Strategic Planning
Technology Roadmap in progress to building virtual
power plant capabilities
We are executing a 5–10 year plan enhancing
DER management in Fort Collins and beyond
Fort Collins continues to share lessons learned on 10+
years of history of local DER management
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