Burlington Electric Commission — Burlington, VT
Date: 2025-04-09
Time: 17:00

BURLINGTON
 BOARD OF ELECTRIC COMMISSIONERS
 585 Pine Street
 Burlington, Vermont 05401
 To be held at Burlington Electric Department (and)
 Via Microsoft Teams
 +1 802-489-6254
 Conference ID: 636 059 465#
LARA BONN
MICHELLE HOBBS
SCOTT MOODY, CHAIR
ANDY VOTA
BETHANY WHITAKER, VICE CHAIR
 AGENDA
 Regular Meeting of the Board of Electric Commissioners
 Wednesday, April 9, 2025 – 5:00 PM


1. Agenda

2. Minutes of the March 12, 2025 Meeting

3. Public Forum

4. Commissioners’ Corner (Discussion)

5. GM Update

6. Financial review (Discussion) – Emily Stebbins-Wheelock

7. FY2026 Draft Budget Presentation – General Manager Springer and Emily Stebbins-Wheelock

8. Net Zero Road Map Update – General Manager Springer

9. Commissioners’ Check-In

10. Executive Session – McNeil Commercial Items

11. Executive Session – Personnel Matters


 Attest:

 _________________________________________
 Elena Alexander, Board Clerk



If anyone from the public wishes to speak during the public forum portion of the Commission Meeting and/or wishes to
be present for the Meeting of the Board of Electric Commission via Microsoft Teams, please email
ealexander@burlingtonelectric.com to receive a link to the meeting.




Note: Members of the public may speak during the Public Forum, or when recognized by the Chair during consideration of a specific
 agenda item.

BURLINGTON
 BOARD OF ELECTRIC COMMISSIONERS
 585 Pine Street
 Burlington, Vermont 05401
 To be held at Burlington Electric Department (and)
 Via Microsoft Teams
 +1 802-489-6254
 Conference ID: 636 059 465#
LARA BONN
MICHELLE HOBBS
SCOTT MOODY, CHAIR
ANDY VOTA
BETHANY WHITAKER, VICE CHAIR
 AGENDA
 Regular Meeting of the Board of Electric Commissioners
 Wednesday, April 9, 2025 – 5:00 PM


1. Agenda

2. Minutes of the March 12, 2025 Meeting

3. Public Forum

4. Commissioners’ Corner (Discussion)

5. GM Update

6. Financial review (Discussion) – Emily Stebbins-Wheelock

7. FY2026 Draft Budget Presentation – General Manager Springer and Emily Stebbins-Wheelock

8. Net Zero Road Map Update – General Manager Springer

9. Commissioners’ Check-In

10. Executive Session – McNeil Commercial Items

11. Executive Session – Personnel Matters


 Attest:

 _________________________________________
 Elena Alexander, Board Clerk



If anyone from the public wishes to speak during the public forum portion of the Commission Meeting and/or wishes to
be present for the Meeting of the Board of Electric Commission via Microsoft Teams, please email
ealexander@burlingtonelectric.com to receive a link to the meeting.




Note: Members of the public may speak during the Public Forum, or when recognized by the Chair during consideration of a specific
 agenda item.
 DRAFT MINUTES OF REGULAR MEETING
 BURLINGTON ELECTRIC COMMISSION

 Wednesday, March 12, 2025

The regular meeting of the Burlington Electric Commission was convened at 5:05 pm on
Wednesday, March 12, 2025, at Burlington Electric Department, 585 Pine Street, Burlington,
Vermont, and on Microsoft Teams.

Attendance
  Channel 17 was present to record this meeting.
  Commissioners Lara Bonn, Michelle Hobbs, Scott Moody and Andy Vota were present.
  Staff members Elena Alexander, Paul Alexander, Mike Kanarick, Paul Nadeau, Darren
 Springer, and Emily Stebbins-Wheelock were present at 585 Pine St.
  Staff members Yvon Edades, James Gibbons, Munir Kasti, Betsy Lesnikoski, and Amber
 Widmayer were present via Microsoft Teams.
  One anonymous member of the public was present via Microsoft Teams.

Agenda
  There were no changes to the Agenda.

Meeting Minutes
   Commissioner Bonn made a motion to approve the minutes of the February 12, 2025,
 Commission Meeting; Commissioner Hobbs seconded the motion. Vote: 3 ayes 0 nays.
 Commissioner Vota abstained from voting as he was not present at the February meeting.

Public Forum
  No members of the public were present at this time.

Commissioners Corner
  No items stated.

General Manager’s Update
  General Manager Springer shared an update on the proposed 10% energy tariff (separate
 from the broader potential 25% tariff that may apply to other goods) and how it may affect
 Hydro Quebec Power's energy supplies to New England, especially Vermont. There is
 ambiguity about whether the 10% energy tariff would apply to Vermont's contracts. Ontario
 has proposed a 25% surcharge on its energy exports to states like Minnesota, New York, and
 Michigan. Vermont and BED do not obtain any energy from Ontario, but media reports have
 suggested that Hydro Quebec may cancel projects in Massachusetts and New York City
 1
 and/or not sell energy in the spot market, which could exert price pressures and negatively
 impact New England's emissions pro ile, an outcome that stakeholders want to prevent.
 Vermont's situation is somewhat distinct due to its long-term power supply contracts.
 Currently, there is an active proceeding at FERC concerning the implementation of any
 tariffs by ISO New England, with entities like GMP, VPPSA, and others iling as intervenors.
 BED has joined VPPSA’s intervention as a strategic partner and joined other VT utilities on a
 letter supporting GMP’s iling. Although there are concerns about potential bill impacts
 stemming from these tariffs, BED's power portfolio relies moderately on Hydro Quebec
 (16%), and any repercussions on bills would be analyzed in conjunction with a rate case for
 iscal year 2026, meaning there would be no immediate changes for customers. General
 Manager Springer is hopeful of gaining more knowledge by April and will provide updates
 as they arise.
  Commission Chair Moody asked about the impact of changing federal policy on BED’s
 electri ication projects and incentives. General Manager Springer stated that the BED’s
 initiatives are not directly affected by federal policy; however, if federal incentives were to
 roll back, BED may be able to temporarily enhance EV incentives. The absence of certain
 federal components could affect adoption rates in Vermont, but most of BED’s grant funding
 relationships with the federal government have not been impacted so far, including with
 FEMA for the Winooski dam replacement, $5 million in congressionally directed spending to
 support District Energy, as well as the Building GIANTS GRIP grant through Department of
 Energy which we have received reimbursement for already. The grant impacted the most
 by the federal funding freeze is the CFI EV Charging Grant for $4.85 million. BED continues
 to be in contact with their counterparts in FHWA, but this agreement has not yet been
 signed. There has been some indication that the funds should be unfrozen for awards,
 whether or not obligated, if the appropriations were made by Congress; this is a broader
 litigation question that many entities are awaiting clarity on. BED’s revenue bond that was
 approved in November has been unaffected by federal matters, leaving its capital program
 positioned favorably for the next few years.
  The main energy bill in the State legislature this year (S.65), aimed at increasing lexibility in
 energy ef iciency funds, is currently under discussion in the Senate and could be voted on by
 the Natural Resources and Energy Committee this week.
  The contract for the McNeil ef iciency study that was approved in February will be going to
 the Council Transportation, Energy & Utilities Committee and the full City Council later this
 month as well as the contract for the forestry study being presented tonight, should it pass.
  BED is currently working with Synapse on the annual update of the Net Zero Energy
 Roadmap data, which we anticipate presenting by April. We are closing in on 1,000 lifetime
 EV/plug-in hybrid rebates and about 3,000 heat pump rebates. We will re lect on the
 progress in the new Net Zero Roadmap and see where we land with thermal and ground
 transportation. Commissioner Hobbs asked how extensively the Roadmap annual data will
 be shared publicly. General Manager Springer stated that historically, BED has presented the
 data to the Commission, City Council, and the public, and it aims to release this year’s
 updates in a timely manner by April, although past reports have faced delays.

FY25 January Financials
Ms. Stebbins-Wheelock presented the January results:
 2
  January had an actual net income of $355,000 compared to a budgeted net loss of $97,000,
 resulting in a favorable variance of $453,000.
  Year-to-date, actual net income exceeds $3 million, just $132,000 short of the budgeted
 expectation of $3.147 million.
  Sales to customers revenue in January was $200,000 higher than budgeted.
  Net power supply expenses were approximately $300,000 better than expected. This
 improvement is the net effect of wind production exceeding budget, high energy prices for
 sales of excess energy, modestly lower fuel costs, and transmission costs lower than budget
 by $118,000.
  Other operating & maintenance expenses was close to budget with a minor negative
 variance of $40,000.
  Non-operating income showed a positive variance of $36,000, due to the timing of grant
 proceeds and external billings.
  In capital spending, the year-to-date expenditure stands at 46% of the full-year budget; the
 distribution and general plant categories have experienced delays but projects are
 progressing in both areas.
  As of January 31st, operating cash is at $11.4 million, slightly above the budget of $11.2
 million. The debt service coverage ratio for the last 12 months is 4.95, the adjusted debt
 service coverage ratio is 1.29, and days cash on hand is 153 (including the line of credit).

SCADA Update
  Paul Nadeau and Yvon Edades explained the signi icant upgrade to the SCADA (Supervisory
 Control and Data Acquisition) system. The existing Schneider SCADA system, which had
 reached its end of life, necessitated improvements in reliability and security due to
 increasing software vulnerabilities. The new system includes an Advanced Distribution
 Management System (ADMS), improving load management, outage management, and
 contingency handling capabilities, and was chosen through the RFP process that concluded
 with the selection of Survalent for their suitable and cost-effective solution.
  The old system was limited to a simple one-line diagram, mainly designed for dispatchers to
 access necessary operational information. In contrast, the new SCADA system is
 customizable and integrates seamlessly with the existing Geographic Information System
 (GIS), providing enhanced operational ef iciency. This integration allows dispatchers to
 streamline their communication with ield teams and access real-time data directly to
 expedite operational responses to outages.
  The new system features an Outage Management System (OMS) that improves customer
 communication regarding restoration timelines and enhances the overall customer
 experience. It also boasts an advanced architecture with real-time backup capabilities,
 allowing for rapid recovery in case of system failure, signi icantly reducing downtime
 compared to the manual switch-over required by the old system.
  The project highlighted extensive collaboration across multiple departments, including
 engineering, IT, and dispatch, with management oversight ensuring smooth execution.
 Phases one and two of the SCADA and GIS implementation were completed in early 2025
 alongside the opening of a new dispatch center. Future plans include the rollout of the
 Distribution Management System (DMS) in August 2025, followed by the OMS in February
 2026, all aimed at ensuring improved ef iciency and reliability in operations.
 3
McNeil Forestry Study RFP
   General Manager Springer shared that the Department made three attempts to secure
 competitive bids for forestry consulting services that were within the budget and aligned
 with the City Council's objectives. The latest bid, submitted by K2QC Consulting, has been
 reviewed and found to be acceptable. K2QC is willing to undertake the project for a
 maximum cost of $22,850, within the $25,000 budget.
   Despite initial unfamiliarity with K2QC, both General Manager Springer and Chief Forester
 Betsy Lesnikoski reached out to industry experts, who provided positive endorsements for
 the irm. They possess the expertise to conduct a thorough review of forestry practices,
 validate public communications, and propose recommendations to enhance public
 engagement during hearings. Commission Chair Moody expressed some concerns regarding
 minor typographical errors in the proposal and asked General Manager Springer’s opinion
 on that. It was determined that the proposal's overall advantages were worth pursuing. The
 Council resolution mandates that this process be conducted in a speci ic manner and
 subsequently reviewed by the Council Transportation, Energy & Utilities Committee as well
 as the full City Council. Rejecting the proposal would hinder progress towards the
 established objectives.
   Chief Forester Lesnikoski corroborated General Manager Springer’s thoughts, noting that
 the typos were concerning but outweighed by the strong recommendations for K2QC. She
 mentioned her connection with John Bryant from K2QC, a well-regarded professional with
 extensive experience in both industry and private consulting. Their prior acquaintance from
 college and shared involvement in forestry organizations added to her con idence in the
 proposal's value.
   Commissioner Hobbs inquired about the challenges faced in inding local candidates for the
 project. General Manager Springer explained that previous bids were well above budget,
 with some proposals being excessively comprehensive, leading to increased costs. Feedback
 from industry sources validated that the budget was reasonable for the requested work, and
 it was only on the third attempt that K2QC submitted a responsive bid.
   Commissioner Vota asked for clari ication on the budgeted amount. General Manager
 Springer con irmed that the proposal outlines six speci ic deliverables at a irm cost not to
 exceed the budgeted amount of $22,850.
   Commissioner Bonn made the motion to approve and recommend the Transportation,
 Energy and Utilities Committee and the City Council approve the proposed contract with
 K2QC Consulting to provide forestry assessment and analysis services for the McNeil
 Generating Station. Commissioner Hobbs seconded the motion. Vote: 4 ayes 0 nays.

Commissioners’ Check-In
  Commissioner Hobbs inquired about the upward trend of residential delinquencies shown
 in the monthly report. Mike Kanarick, Manager of Customer Care, Communications and
 Energy Services, explained to the Commission that this uptick was a result of Vermont
 Public Utility Commission rules that prohibit disconnections in cold weather. As the
 4
 weather starts to get nicer and there is an ability to disconnect customers, the delinquencies
 tend to decrease.
  Commissioner Vota requested that, going forward, the Commission packets are more
 contextualized per project status and have a similar format to the General Manager’s update.
 General Manager Springer acknowledged Commissioner Vota’s request.

Executive Session- McNeil Commercial Items
Commissioner Vota made the motion that premature general public knowledge regarding McNeil
commercial items would clearly place the Burlington Electric Department at a substantial
disadvantage per Title 1, Section 313 (a)(1) of the Vermont Statutes; Commissioner Bonn seconded
motion. Commission vote; 4 ayes 0 nays.

Commissioner Vota made a motion to enter into Executive Session at 5:54pm to discuss the McNeil
commercial items under the provisions of Title 1, Section 313(a) (1)(A) of the Vermont Statutes;
Commissioner Bonn seconded the motion. Commission vote; 4 ayes 0 nays.

Commissioner Hobbs made a motion to exit Executive Session at 6:27pm; Commission Vota
seconded the motion. Commission vote; 4 ayes 0 nays

Adjourn
Commissioner Vota made a motion to adjourn; the motion was seconded by Commissioner Hobbs,
Commission vote; 4 ayes 0 nays.

The meeting of the Burlington Electric Commission adjourned at 6:05p.m.

Minutes drafted by Elena Alexander, Board Clerk, edited by Emily Stebbins-Wheelock, CFO & Manager
of Strategy and Innovation
 Attest: _______________________________________________
 Elena Alexander, Board Clerk




 5
To: Burlington Board of Electric Commissioners

From: Darren Springer, General Manager

Date: April 4, 2025

Subject: March 2025 Highlights of Department Activities



General Manager – Darren Springer
For Sharing with Council –
• McNeil RFPs – The Electric Commission has approved both an emissions reduction and forestry RFP,
 and TEUC approved them as well on 3/25. The RFPs will now go to Council for approval 4/14, after
 which we can begin work with the vendors on the analyses.
• Federal Grants – The federal Administration issued a memo directing the Department of
 Transportation to review grants for certain terms or projects including EV and charging, and to
 update work plans based on new Administration priorities. This puts our EV charging grant in further
 limbo while we await the results of this review.
• Net Zero Roadmap – Our annual Net Zero Energy Roadmap update for 2024 will be on Commission
 agenda 4/9 and we’ll make a public presentation on it that day as well, and we are planning to
 present the latest data to the Council on 4/14.
• 2025 Jim Reardon Public Service Award – We’ll have the announcement on 4/9 of the 2025 Jim
 Reardon BED Public Service Award and can share with the Commission at our meeting on 4/9.
• Mobile Battery Storage Pilot – BED is working with Virindi to test a mobile battery storage unit in
 April, with the possibility of pursuing a larger mobile storage battery to deploy against summer
 peaks while we work longer-term on permanent battery storage options from our recent RFP.
• New Fast Charger – BED’s third public network DC fast charger is now in service at the Pease lot at
 the Waterfront, joining our Marketplace Garage charger downtown and our charger at 585 Pine St.
 We invite Burlington EV drivers and visitors to charge up at these locations, with more coming soon.

Center for Innovation – Emily Stebbins-Wheelock
• Monitoring changes in federal and state funding following change in Presidential
 administration; continuing to work with FEMA and VT Dept of Public Safety on grants for July
 2023 and July 2024 flood damage at Winooski One.
• Continued sponsorship of IT Forward implementations.
• Coordinating Policy & Planning and Finance team analysis to support McNeil joint owner
 negotiations.
• Coordinating REC process review for owned generation assets.

Finance & Billing
• Continued work on FY26 budget development.
• Continued work on RFP development for new financial information
 March 2025 – Department Highlights



• Continued work on research for new work order management systems.
• Continued work on updating credit card policy and an RFP for procurement card program.
• Completed PUC workshop for energy efficiency charge investigation and worked on follow-up
 filing with PUC.
• Continued efforts supporting SpryPoint CIS implementations with financial system and General
 Ledger.
• Attended grant implementation bootcamp coaching sessions.
• Worked with City to resolve sick shift premium pay discrepancy and backpay totals.
• Developed Schedule of Expenditures of Federal Awards (SEFA) for impending Uniform
 Guidance Single Audit for FY25.
• Beginning work on 2025 rate case cost of service supporting calculation.
• Exploring implementation of Water Resources assistance program via electric bills.
• Began work on updating financial policies and procedures.
• FY24 program audit of on-bill finance/revolving loan fund program funded by Economic
 Development Administration issued with clean opinion and submitted to EDA.

Information Services
• Phase 3 of Survalent SCADA/ADMS project underway.
• Work to replace production and development database servers.
• Customer Information System: BED and SpryPoint teams continue to work through discovery
 phase. IT working closely with Sprypoint data team.
• Financial Information System RFP: work continues to document and develop requirements.
• Distributed Energy Resource Management System: RFP has been formally issued. Working on
 scoring matrices and demo scenarios.
• Work & Asset Management System: BED held two pre-RFP demonstrations of WAMS to get
 high-level overview of the systems and capabilities. Team is now working on BED-specific
 scenarios for more in-depth demonstrations centered on BED's operations.
• Continued participation on the State of Vermont’s Cybersecurity Advisory Board.
• Ongoing phishing and security testing of our users.

Policy & Planning
• McNeil efficiency study contract review and negotiation.
• Five-year power supply forecasting and budgeting.
• Feb 2025 ISO-NE forward reserve market change – implemented automated bidding.
• Legislative season continues – in-person monitoring and reporting on bills/proceedings.
• McNeil negotiations and analysis.
• DeltaClimeVT 2025 meetings and mentoring.
• Solar Test Center and Village Hydroponics license extension work.
• DERMS project.
• EEC rate proceedings.
• Final 2024 REC positioning.
• Seeking energy replacement options.



 Page 2
 March 2025 – Department Highlights



• Winooski One – FERC-ordered fish studies commencing and Public Safety Plan update
 underway.
• Winooski Bridge Replacement – managing FERC licensing implications.
• Building GIANTS GRIP grant – drafting outreach to residential customers; Sensibo contracting.
• Drafted potential modifications to EAP program.

Sustainability & Workforce Development
• Orchestrated bi-monthly DOE-funded GIANTS meeting on customer outreach and
 communication. Drafted FAQ sheet and communication to HP owners.
• Joined REIB’s second round of Empowerment Grants Selection Committee.
• Planned for Spring Move Out, an annual collaboration between the City, UVM, CSWD, and
 Champlain College. BED participates, reminding tenants to close or schedule account stops.
• Continued Thursday, 3:00-5:00 pm Office Hours at the Fletcher Free Library to connect with
 BED customers on rebates, technical support and to answer questions related to electric bills
 and other issues.
• Staffed a Spanish-language drop in night at the ONE Community Center.
• Assisted in Family Room’s Computer Class and tabled at King Street Laundromat.
• Prepped social media posts for Communications team and worked with Communications team
 on updated 2025 Customer Satisfaction Survey.
• Following January Mayor’s climate meeting, completed draft inventory of city-wide climate-
 related mitigation and adaptation work. Presented at DH meeting. Co-facilitated first Climate
 Advisors Meeting at the request of the Mayor.
• Planned for April Fletcher Free Library-hosted book group conversation, featuring What if We
 Get it Right by Ayana Elizabeth Johnson.
• In conjunction with Communications team, scheduled new podcast recordings including with
 BED staff on the mutual aid program and the State’s Climate Office.
• Coordinated with DPI, BED, Building Electrification Institute, CX Associates, and Burlington
 2030 District on benchmarking ordinance including relevant Energy Star Portfolio Manager
 (ESPM) fields.
• Joined Burlington 2030 District Executive Committee and subsequent Steering Committee
 meeting. Coordinated efforts to support the City’s benchmarking ordinance including 2030
 District-sponsored ESPM training.
• Met with South Burlington’s new Climate Manager to discuss City of Burlington initiatives and
 possibilities for collaboration.
• Joined Vermont Energy Education Project (VEEP) board meeting.
• Accepted invitation to join CarShareVT board; participated in onboarding meeting.
• Participated in Drive Electric Stakeholder meeting and presented the latest information on
 BED’s CFI grant.
• Met with NEEP and ClearlyEnergy team to discuss new DOE grant, technical support for
 benchmarking, and the prospective use of BEAM tool to track benchmarking progress, including
 enforcement.
• Orchestrated Pine Street tour for new and interested staff.



 Page 3
 March 2025 – Department Highlights



• Met with City Comprehensive Planner to discuss plan update and the integration of scenario
 planning.
• Reviewed equity maps, generated by City’s GIS specialist, including how these data sets can
 advance BED’s equity work and ensure all Burlingtonians are empowered to benefit from and
 participate in strategic electrification.
• Hosted Vermont Chapter of New England Women in Energy and Environment meeting in the
 Spark Space.

Center for Safety and Risk Management – Paul Alexander
Safety
• Completed annual hoist inspections per OSHA 1910.179
• Assisting Generation with annual outage tasks.
• Conducted weekly operational safety/ops meeting.
• Completed annual maintenance of fire extinguishers in Operations & Substations.
• Provided operations/generation supervisors weekly safety summary.
• Conducted three full days of safety training for Generation Personnel. Covered:
 ▪ CPR/First Aid/AED Recertifications
 ▪ Train Trestle safety
 ▪ Ash Handling procedures
 ▪ Hot Work Permits
 ▪ Confined Space Entry
 ▪ Lock Out Tag Out Procedures
 ▪ Pre Job Safety Briefs
 ▪ Forklift refresher training
 ▪ Gas Detector & Hazard Communication training
 ▪ Spill Prevention Control & Countermeasures
 ▪ Respiratory Protection Program
 ▪ Annual Respirator Fit Tests
 ▪ Completed weekly OSHA 300 reporting.

Environmental
• Worked with the REC process group on backup path going forward
• Sampled monthly wastewater
• Conducted pre-outage planning
• Conducted boiler inspection with new working crew leader & station engineer
• Assisted with & completed outage training
• Regenerated the demineralizer system
• Completed linearity testing of the CEMS

Risk Management
• New Claims Investigations (1 total: Small Claims Court).
• 2 new employee Workers’ Compensation/Accidents/Loss Control orientations.
• Extensive work on reviewing/revising FY’26 expense and capital budget revisions/edits
• Sponsor VT CPCU at silver level (PR created and check sent)
• Contract ticket process meeting/emails
• Participate in monthly Safety iPi/USOLN forum


 Page 4
 March 2025 – Department Highlights



• Attend generation asset REC process meeting
• OP-16/NX-9 form submitted for ISO-NE
• Attend BEC meeting/ Chair BSC meeting
• Attend Summit Fire FOB software training
• Meet with Mayor and GM on beltline lights
• Reply to HR’s ADA/Market Factor email
• PRIMA’s “Let’s Talk Tuesday” webinar
• Schedule/reschedule Zurich Property tour of McNeil
• Perform Barrel check for Safety/Environment
• Work with City Attorney on ICE/HIS signs and 4/11 webinar
• Sit in on 2nd round interview of Dir of Gen & Maintenance
• M&G with new City councilors
• Revise Vehicle listing spreadsheet
• Attend NZE Planning meeting
• Attend Generation Asset REC meeting/Cyber security monthly meeting
• Create Liability Release for Callahan Park (American LL)
• Kick-off meeting scheduled for NPCC Self-audit (PRC-005, PRC-006) with USI and Engineering
• Attend USI Monthly TO/DP call
• Attend annual McNeil safety training

Purchasing/General Services
• Ordered Replacement truck C-1
• Installed New Key Fob Control System
• Started Outage at McNeil Generating Station
• Worked Fire Department Punch List
• Reposted RFP for GT Roof Replacement Over Budget
• Started Demo Old Dispatch Room
• Sent Out RFP for SCADA ROOM Construction
• DM Fire System inspection

Center for Operations & Reliability – Munir Kasti
Engineering, Grid Services & Operations
• Continued pulling new underground conductors on Battery Street from College Street to Main
 Street and South Champlain Street.
• Continued rebuild work of the underground system on Summit Ridge.
• Issued estimates for service upgrades on Cambrian Way, Shelburne Street and North Street.
• Issued work orders for service upgrades on Shelburne Street, North Street and East Avenue
• Completed service upgrades on Loomis Street, Strong Street and Booth Street.
• Started reconductoring overhead cable on College Street.
• Issued work orders for the replacement of three overloaded transformers.
• Issued work order to install new voltage sensors on 861S switch at Main Street and South
 Prospect Street.
• Issued work order to replace underground systems to UVM Aiken Center, UVM Stafford
 Greenhouse, Centennial Court and UVM Library Annex.
• Completed installation and commissioning of a new Level 3 EV Charger at the Waterfront Pease
 Lot.


 Page 5
 March 2025 – Department Highlights



• Replaced the pad mounted switches at Main Street Reservoir.
• Completed the installation of the second of two pad-mounted transformers for the new
 Burlington High School.
• Removed the underground primary lines and transformers at 20 Pine Street to prepare for
 demolition of the building.
• Participated in meetings and workshops related to Phase 3 of the SCADA/ADMS upgrade.
• Participated in meetings related to the upgrade of the Customer Information System (CIS).
• Participated in meetings related to DPW-led projects on Champlain Parkway and Main Street.
• Upgraded street lighting at the East Avenue jughandle to new LED lighting.
• Darby Crum, BED’s newest metering technician, has completed the first of two metering courses
 through the Northeast Public Power Association (NEPPA).

SAIFI & CAIDI Outage Metrics:

BED’s distribution system experienced 18 outages in March 2025 (4 unscheduled and 14
scheduled). BED’s SAIFI for the Month of March was 0.01 interruptions per customer and CAIDI
was 1.94 hours per interruption. BED's YTD SAIFI is 0.13 interruptions per customer and YTD
CAIDI is 1 hours per interruption. BED experienced a high CAIDI value for the month of March due
to the capital projects to replace pad mounted switches at Main St Reservoir.

The following figure shows BED’s historical YTD SAIFI and CAIDI:




The following figure shows BED’s historical March SAIFI and CAIDI:




 Page 6
 March 2025 – Department Highlights




The following figure shows BED’s historical Unplanned Outages:




Generation
McNeil Generating Station
Month Generation: 10,132 MWh
YTD Generation: 68,526 MWh
Month Capacity Factor: 27.2%
Month Availability: 28.7%
Hours of Operation: 284 hours

Routine maintenance, preventative maintenance, and process improvement projects were
completed at McNeil this month. At the beginning of the month the plant was offline due to a
jammed feeder grate. The initial startup attempt only lasted a couple of hours until the live bottom
froze up. When the plant was back online, clogged augers reduced generation to 42 MW. This issue
was compounded by a failed cooling tower fan that brought the plant to 35 MW for most of March.
The feeder grates jammed again and brought the unit offline, which prompted the annual overhaul
outage to start early. Mike Harron, McNeil’s new Director of Operations, started on March 3, 2025.

Winooski One Hydroelectric Station
Monthly Generation: 2,573.15 MWH (75.5% of average)
YTD Generation: 4,510.11 MWH (56% of average)
Month Capacity Factor: 46.7%
Annual Capacity Factor: 28.2%
Month Availability: 70% (due problems with Generator 1 gates)

Routine maintenance, preventative maintenance, and process improvement projects were
completed at Winooski One this month. The large dam bladder project was completed with all
scaffolding removed. An issue with the gates of Generator 1 is being investigated as it is preventing
the gates from opening more than 30% and limiting generation.




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 March 2025 – Department Highlights



Burlington Gas Turbine
Month Generation: 18.97 MWh
YTD Generation: 43.95 MWh
Month Capacity Factor: 0.11%
Month Availability: 100%
Hours of Operation Unit A: 1.2 hours
Hours of Operation Unit B: 1.2 hours

Training, an operational run, and preventative maintenance checks were performed at the Gas
Turbine this month. We also completed a successful borescope study.

Solar

Solar (Pine Street 107 kW)
Month Generation: 9 MWh (+15% from previous year)
YTD Generation: 13 MWh
Month Capacity Factor: 11.8%
Month Availability: 100%

Solar (Airport 499 kW)
Month Generation: 28 MWh (-32% from previous year)
YTD Generation: 54 MWh
Month Capacity Factor: 7.5%
Month Availability: 100%

Center for Customer Care & Energy Services – Mike Kanarick
Customer Care
• Call Answer Time (75% in 20 seconds): March 2025 90.3%, February 89.6%, January 86.4%,
 December 2024 83.4%, November 84.0%, October 80.6%. March 2024 87.7%, February 87.7%,
 January 86.7%, December 2023 88.6%, November 88%, October 84.8%. Best call answer time in
 many months!
• March 2025 Stats: please see dashboard for additional metrics categories.




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 March 2025 – Department Highlights




 Complaints to DPS about Customer Care Team
 6 5




 # of Complaints
 5
 4
 3
 2 1
 1 0 0 0 0 0 0 0 0 0 0 0 0
 0
 2015 2016 2017 2018 2019 2020 2021 2022 2023 Q1 Q2 Q3 Q4 Q1
 2024 2024 2024 2024 2025
 Calendar Year


Communications and Marketing
• Women’s History Month: in honor of this special month, we featured BED’s own Amanda Hurlbut,
  BED’s Controller, and Erica Ferland, BED’s IT Director. Check it out on Facebook.
• Net Zero Energy Podcast: we invite you to listen to our latest podcast episode, featuring Mona Tolba,
  who is a shining example of community leadership through her work with the Vermont Language
  Justice Project and on the Just Transition Subcommittee of the Vermont Climate Council
  burlingtonelectric.com/podcast.
• Earth Day: on April 20, BED will participate in the Church Street Marketplace Earth Day celebration.
  With our BED tent located across from City Hall and surrounded by our friends from Burlington City
  Arts, Fletcher Free Library, Local Motion, the Intervale, and others, we will engage in meaningful
  conversations with community members about steps each of us can take along the path toward Net
  Zero Energy.

• North Avenue News: our April column advertised BED’s open job positions, as well as promoted NZE
 rebates for 2025.
• Website and Facebook Highlights
 • Overall site-wide pageviews for March = 19,047
 • February = 18,341
 • January = 23,653
 • December = 20,787
 • November = 17,793
 • October = 26,469
 • September = 29,558
 • August = 24,904
 • July = 23,183
 • June = 30,133



 Page 9
 March 2025 – Department Highlights



 • May = 27,971
 • April = 20,221
 • March = 17,841
 • Unique homepage pageviews for March = 4,251
 • February = 3,804
 • January = 4,739
 • December = 6,959
 • November = 6,713
 • October = 5,248
 • September = 5,183
 • August = 5,795
 • July = 5,541
 • June = 11,531
 • May = 6,428
 • April = 4,753
 • March = 4,747
 • Defeat the Peak email notification list = 813 (no change from Jan. or Feb.)

• Full site visits for March 2025




 Page 10
 March 2025 – Department Highlights



 • Visitors by website page




 • Top-performing Facebook & Instagram posts (note logo in lower right corner of each photo)
Top Facebook & Instagram posts
Women’s History Month & New Level 3 charger on Waterfront




Energy Services

UVM
• Stafford Hall Chilled Water Upgrade – This lab-hood intensive research building has been
  cooled with four air-to-water DX Air Handler Units since its construction in the mid-1990’s.


 Page 11
 March 2025 – Department Highlights



 A project to connect the cooling system to the central plant chilled water system was
 completed to improve reliability and reduce energy and maintenance costs. A BED site visit
 has verified the completion of the project. This month BED received an updated energy
 savings estimate for the project from a third-party engineering company. A rebate offer has
 been supplied to UVM.
• Health Science Research / Absorption Chiller Replacement – One of two steam absorption
 chillers in this research building is in process to be replaced with a 1000-ton electric chiller.
 DDC trending data was used to calculate the steam / natural gas offset from the old
 absorption chiller. Final NG offset calculations have been completed and BED has developed
 a Tier 3 offer for this project. We are waiting to receive the detailed analysis worksheet used
 to calculate the natural gas savings and preparing to provide the formal incentive offer at that
 time. The new electric chiller is to arrive near the end of this month and the system is to be
 up-and-running in time for the summer cooling season.
• Greenhouse #10 LED Grow Lighting Retrofit – BED received news last month that the new
 (QTY=18) LED grow light fixtures have arrived and were being installed. A savings
 calculation and incentive package had previously been delivered to UVM for the project.
 Some quality issues with the fixtures were then identified, and a new shipment of fixtures
 was received this month. BED completed a site visit this month to view the completed
 installation. The incentive process is now complete with a rebate check to be mailed shortly.

 UVMMC
• Dish Room Renovation Project - BED has been reviewing the documentation for this project,
  which includes a new dish machine and conveyor system, and an updated and more effective
  ventilation system. This dish machine services the kitchen that delivers meals to the in-
  patients of the main hospital. This represents approximately 450 meals, provided three times
  a day. We have worked in tandem with VGS to offer several incentives to modify the project
  to gain higher efficiencies and energy cost reductions. BED has finalized the energy
  modeling for the project and based on the results was able to slightly increase the incentive
  offered.
• Exterior Door Air Curtain Application – The hospital recently contacted BED concerning a
  proposal they’ve received to add two air curtains to existing exterior doors at the main
  entrance of the ACC building. We have been in contact with VGS concerning this measure,
  as there are likely more natural gas savings than electrical savings in the application. VGS
  has suggested a preliminary prescriptive rebate for this energy savings measure.

Other Services
• State Buildings at 32 and 50 Cherry St. / HVAC Re-Commissioning – A kick-off virtual
 meeting was held at the end of this month with an engineering from the State of VT and the
 controls contractor for these buildings. Based on AMI data analysis, BED feels that there is
 likely significant energy savings associated with this work. BED will have log-in access to



 Page 12
 March 2025 – Department Highlights



 the DDCs in these buildings and an investigative meeting is now scheduled for the first part
 of April.
• BETA Technologies / North Hangar Re-commissioning – BED was contacted at the end of
 last month concerning a proposal from a controls company to re-commissioning the North
 Hangar DDC system. Several specific tasks were called out to be completed. The most
 promising item for energy savings is the implementation of HVAC scheduling for the
 building. BETA has indicated that there have been no unoccupied scheduling routines set up
 in the DDC. This month BED supplied an incentive offer to the owner based on a best-
 estimate of savings from analysis of the AMI data.
• Hannaford Grocery / Heat Recovery System Site Visit – EVT, VGS and BED met on-site at
 the North Avenue grocery this month to investigate the status of the heat recovery systems in
 the store. The compressor racks for the refrigeration system create a constant source of waste
 heat that is designed to be fed back into the HVAC system and to support DHW heating. It
 happens that this store shows higher natural gas use than other Hannaford’s in the State and it
 was felt that further investigation was appropriate. The analysis of the data collected during
 the visit is still in progress.
• Village Hydroponics / Shipping Container Vegetable Grow Facility – After some delay, this
 facility is now up and running and in full production. It is a non-profit whose mission reads:
 Village Hydroponics is at the forefront of innovative agriculture in Burlington, Vermont,
 utilizing hydroponic technology inside of a shipping container to grow fresh, nutrient-rich
 produce even in the coldest and darkest winter months. Our mission is to nourish our
 community when other farms cannot, champion food justice, and promote environmental
 sustainability. By utilizing controlled environment agriculture and mutual aid methods to
 grow and distribute vegetables through the entire off season, we can take a pivotal step in
 our community's self-sufficiency. Now that stable operation has been established, BED has
 received updated grow data from the facility.
• Burlington Airport Runway Light Conversion to LED - Information was received this month
 from the Airport Airfield Manager of a plan to replace existing high intensity quartz runway
 lighting with LED technology. BED has requested more details about the lighting products
 being replaced and the new LED fixtures to be installed.
• Burlington High School / New Construction Project – A preliminary energy modeling report
 is now available which estimates Tier 3 and EEU savings for this building. BED has
 determined that the energy modeling has been completed to BED specifications and this
 month we delivered a rebate offer to the Project Manager including both EEU and Tier 3
 incentives. The energy model indicates a highly energy efficient building that will be 100%
 heated/cooled with a geothermal heat pump system.
• Cambrian Rise / Building BG New Construction – This is 100+ unit market-rate multifamily
 building. BED is working with the owner and the energy modeler to have a calibration
 proposal developed. An update of the energy model was completed during February,




 Page 13
 March 2025 – Department Highlights



 incorporating some changes in the design. Work on the calibration continued during March,
 with the job to be finished once the appropriate weather files for the model are available.
• 266 College St. Multifamily / Old YMCA NC Project – BED has been contacted by the
 owners of this property, and the design team, to begin to develop an incentive offer for this
 new construction project. It is comprised of QTY=89 rental units within a 100,000 SF
 structure, part of which is a renovation of the existing building and part which is new
 construction. A preliminary energy model was delivered to BED for analysis earlier in the
 year. There are new construction drawings available, and we will continue our evaluation of
 the design once the new drawings have been made available to us. We intend to schedule a
 meeting with the owner and design team sometime next month.
• Mater Christi School / Early Education Center New Construction – Preliminary energy
 modeling by a third-party engineering company has been completed for this renovation of an
 existing nunnery and an added new addition. The total building area is 7750 SF. A
 geothermal system is being proposed for the building with possible Tier 3 funds available, in
 addition to electrical efficiency rebates. More investigation of the model is needed before a
 rebate offer can be generated.
• VHES/ASHRAE Education Session – Bob Bolin provided input on utilizing thermal storage
 (ice) in a large-scale commercial application. Follow-on discussion with UVMMC facility
 operations manager on analysis requirements for feasibility, potential benefits, initial and
 operational cost savings, greenhouse gas emissions reductions, and mechanical systems
 performance improvement.
• BHA Decker Towers – Direct Outside Air System (DOAS) RTU replacement – Scope
 clarification and usage data provided to CX associates to estimate potential fuel offset and
 electrical savings.
• Ride Your Bike LLC – Proposed new multi-family building complex on Lakeside Ave
 (~1,200 units) - Attended discussion where a third party owned and operated ground source
 mechanical system was proposed. This model has been used in other areas of the country to
 reduce first costs to the developer of all mechanical systems. There are numerous benefits,
 risks, and liabilities associated with this model that the developer will consider carefully.

Electric Vehicles
• The EVSE (ChargePoint, Flo & AmpUp) dispensed a total of 36.4MWh and supported 1,893
 sessions.
• The EVSE (ChargePoint, Flo & AmpUp) dispensed a total of 38.5MWh and supported 2,168
 sessions.
• The ChargePoint EVSE served 852 unique drivers.
• The top 3 sales on the ChargePoint network (all L2) were 92kWh, 93kWh, and 142kWh and
 occurred at the College St. Garage, Oakledge Park and the Cherry St. Garage.
• Approximately 26% (or 10.0MWh) of the energy sold from the entire network is attributed to
 the Pine St. and Marketplace Garage DCFC’s.
• The Pease Lot DCFC was commissioned on March 18-19. The station began dispensing
 energy on March 19.


 Page 14
 March 2025 – Department Highlights



• Station BE15 (122 Main St.) stopped dispensing energy on Mar. 28. It is out of service due to
 construction on Main St.
• The Pine St. DCFC front power module failed on Feb. 21 and was replaced on March 3.
• The Maple St. drop down station charger failed on Mar. 25. The station is under warranty
 and was returned to the manufacturer on 3/31. The manufacturer indicated that there is a 5-
 day turnaround on warranty repairs.
• The Time of Use pricing functionality offered through AmpUp has been programmed from
 12AM-12PM. There are a number of issues that their software team is resolving.
• BPRW will send invoice for Oakledge station reimbursement and it was paid.
• Session Count plot, Dispensed Energy plot, and Location Table from the public charging
 network below.




 Page 15
 March 2025 – Department Highlights




• Number of EV and PHEV rebates to date – 1,038 (of this 228 LMI rebates to date as shown
 below)
 - New All Electric Vehicle – 456
 - New All Electric Vehicle (High-Mileage Driver) – 1
 - New All Electric Vehicle (LMI) – 123
 - New PHEV – 204
 - New PHEV (LMI) – 54
 - Used All Electric Vehicle – 81
 - Used All Electric Vehicle (LMI) – 36
 - Used PHEV- 38
 - Used PHEV (LMI) – 15


 Page 16
 March 2025 – Department Highlights



 - New All Electric Vehicle ($60K plus) – 26
 - New PHEV ($60K plus) – 4

• Number of customers currently participating in the new EV Charging Rate- 364
• Number of E-Motorcycle rebates to date – 2

Electric Vehicle Charging Stations
• Number of home EV charging stations rebates to date – 301
• Number of Multi-family EV charging stations rebates to date – 1
• Number of Multi-family Non-EVmatch-LMI charging stations rebates to date (LMI) – 3
• Number of Multi-family EVmatch Public charging stations rebates to date – 6
• Number of Multifamily EVmatch Non-Public – 9
• Number of Multi-family Non-EVmatch charging stations rebates to date – 3
• Number of Multifamily EVmatch Non-Public – LMI – 1
• Number of Multifamily Non-EVmatch Non-Public – LMI – 8
• Number of Level 2 Workplace charging stations rebates to date – 35

Electric Lawn Equipment to Date
• Number of e-mower rebates to date – 801 (11 commercial & 790 residential)
• Number of e-leaf blowers to date – 108
• Number of Residential e-Trimmers – 114
• Number of Residential e-chainsaws – 26

Heat Pump Installations to Date
Total Heat Pump Installations including Multi-Family New Construction Projects & Installations
in existing buildings since the September 2019 NZEC announcement –
 - 2,960 installations

Installations since the September 2019 NZEC announcement
Number of Heat Pump Technology rebates to date- 1,470 (of this 184 LMI rebates to date as
shown below)

 o Number of ductless heat pumps to date – 854
 o Number of LMI eligible ductless heat pumps to date – 153
 o Number of centrally ducted heat pumps to date – 315
 o Number of LMI eligible centrally ducted heat pumps to date – 18
 o Number of air-to-water heat pumps to date – 3
 o Number of commercial VRF heat pump systems to date – 2
 o Number of geo-thermal heat pump systems to date – 1
 o Number of heat pump hot water heaters to date – 111
 o Number of LMI eligible heat pump hot water heaters participants to date – 13




 Page 17
 March 2025 – Department Highlights



Electric E-Bikes to Date
• Number of e-bike rebates to date – 786

Electric Induction Stovetops to Date (new offering in Jan 2021)
• Number of induction Stovetops rebates to date – 97

Electric Snow Blowers to Date (new offering in Jan 2022)
• Number of snow blower rebates to date – 35




 Page 18
 BED 2024-2025
 Strategic Direction Dashboard


 March 2025 February January 2025 2024 Yearly 2022 Yearly 2021 Yearly 2020 Yearly 2019 Yearly 2018 Yearly
 Target Actuals  2025 Actuals Actuals Actual 2023 Yearly Actual Actual Actual Actual Actual Actual
Engage Customers and Community
Call answer time 75% within 20 seconds 75% 90% 90% 86% avg 81% avg 82% avg 82% avg 82% avg 81%
Delinquent accounts >$500 0 323 287 251 avg 223 avg 168 avg 188 avg 529 avg 201
Disconnects for non-payment 0 10 1 1 308 224 12 0 45
Energy Assistance Program Customers (program lifetime) NA 862 858 852 843 234
Energy Assistance Program Customers (currently enrolled) 300 776 776 774 770 219
# of residential weatherization completions 10 0 0 0 7 11 5 5 3 11 11
Weatherization completions in rental properties 0 0 0 3 8 6 0 0 TBD TBD
# or % of homes or SF weatherized TBD TBD TBD 0 TBD TBD TBD TBD 0 0
# of commercial building with improved thermal envelopes 0 0 0 5 6 4 5 5 0 0
Total annual mWh saved via the EE programs (annual goal) 4,032 877 84 61 1116 2,940 4053 3057 4843
Total residential annual mWh saved via the EE programs (cumulative for year) 724 51 35 28 333 494 862 917 2256
Total commercial sector annual mWh saved via the EE programs (cumulative for year) 3,308 828 49 33 783 2,447 3191 2140 2587
% of EEU charge from LMI customers spent on EE services for LMI customers
 $ 297,026 $ 186,013 $ 178,052 $ 167,552 $ 155,814 $ 504,942 $ 335,234 TBD TBD TBD TBD
(cumulative for 2024- 2026 3-year EEU performance period)
Strengthen Reliability
SAIFI (AVG interruptions/customer) (annual target) < 2.1 0.01 0.05 0.07 1.63 0.56 1.05 0.17 1.48 1.01 0.43
CAIDI (AVG time in hrs to restore service) (annual target) < 1.2 1.94 1.72 0.44 0.94 0.67 1.49 0.55 0.75 0.93
Distribution System Unplanned Outages (annual target) 82 4 5 3 69 39 61 44 90 98 78
McNeil Forced Outages 0 2 1 0 10 5 14 5 21 TBD TBD
W1H Forced Outages 0 1 1 0 3 2 6 9 2 TBD TBD
GT Forced Outages 0 0 0 1 2 9 6 2 3 TBD TBD
Invest in Our People, Processes, and Technology
Avg. # of days to fill positions under recruitment 120 317 257 232 253 219 100 68 179
# of budgeted positions vacant 0 9 11 11 avg 12 avg 12 avg 9 avg 9 6 NA NA
 BED 2024-2025
 Strategic Direction Dashboard


 March 2025 February January 2025 2024 Yearly 2022 Yearly 2021 Yearly 2020 Yearly 2019 Yearly 2018 Yearly
 Target Actuals  2025 Actuals Actuals Actual 2023 Yearly Actual Actual Actual Actual Actual Actual
Innovate to Reach Net Zero Energy
Tier 3 Program
# of residential heat pump installs 18 11 31 176 186 255 315 203 10 0
# of commercial heat pump installs 0 0 0 5 8 4 4 13 0 0
# of residential hot water heat pump installs 1 2 5 28 31 26 14 6 4 0
# of commercial hot water heat pump installs 0 0 0 0 0 0 0 0 0 0
Heat pump rebates 18 11 31 185 206 271 328 212 0 0
Heat pump hot water heater rebates 1 2 5 28 47 18 15 3 0 0
LMI heat pump rebates 1 0 0 35 21 43 28 6 4 0
Heat pump technology installs in rental properties 0 0 0 3 8 10 14 9 TBD TBD
LMI heat pump hot water heater rebates 0 0 0 2 6 1 2 0 1 0
EV rebates - new 10 6 18 125 103 53 67 14 36 44
EV rebates - pre-owned 2 2 1 23 16 18 7 8 2 0
 See NZE
LMI EV rebates 4 2 5 50 26 9 11 7 7 0
 Roadmap
PHEV rebates - new 4 3 7 44 25 27 41 10 17 14
 Goals below
PHEV rebates - preowned 0 0 5 8 6 12 6 5 3 0
LMI PHEV rebates 0 0 0 11 5 15 13 6 2 1
Public EV chargers in BTV (total) 41 40 ports 40 ports 40 ports 32 ports 30 ports 27 ports 27 ports 14 14
Public EV charger energy dispensed (kWh) 38,500 36,400 40800 355500 244,300 151,360 86,570 35,690 78,000 67,931
Home EV charging station rebates 8 5 18 82 72 70 32 20 12 0
EV charging rate customers (total) 364 354 351 347 246 157 40 40 28 4
Level 2 charger rebates 0 0 1 22 10 11 10 0 1 0
Level 1 charger rebates 0 0 0 0 0 - 0 1 0 0
E-bike rebates 22 1 27 169 147 152 88 36 65 62
E-mower rebates 1 0 2 109 135 159 154 95 142 NA
E-forklift rebates 0 0 0 0 0 1 0 0 0 0
MWE of Tier 3 measures installed 1,711 1,139 1,863 26,120 22,374 22,837 23,763 35,112 3,342
% Tier 3 obligation met with program measures 100% 19% 12% 8% 122% 117% 131% 159% 283% 31% 30%
Net Zero Energy Roadmap Goals
# of solar net metering projects installed 2 1 1 13 32 33 29 24 33 52
No. of homes receiving NZE Home Roadmaps 0 0 0 0 - 7 10 7
Residential heat pumps for space heating (no. of homes) 2023: 8615 NA NA NA NA 1,952, 18% of goal 1,749 1,448 1,112 925 NA
Commercial heat pumps for space heating (1000 SF floor space served) 2023: 5397 NA NA NA NA 431, 7% of goal 411 405 374 374 NA
Residential heat pumps for water heating (no. of homes) 2023: 4365 NA NA NA NA 289, 7% of goal 243 224 208 203 NA
Commercial heat pumps for water heating (1000 SF floor space served) 2023: 1019 NA NA NA NA 0 0 0 0 - NA
EV registrations in BTV (light-duty) 2023: 2294 NA NA NA NA 829, 22% of goal 699 549 361 296 NA
Greenhouse gas emissions (1000 metric tons CO2) 2023: 150 NA NA NA NA 191, 127% of goal 191 188 185 214 NA
Fossil fuel consumption (billion BTU) 2023: 2418 NA NA NA NA 2,983, 136% of goal 3,285 3,171 3,182 3,660 NA
 BED 2024-2025
 Strategic Direction Dashboard


 March 2025 February January 2025 2024 Yearly 2022 Yearly 2021 Yearly 2020 Yearly 2019 Yearly 2018 Yearly
 Target Actuals  2025 Actuals Actuals Actual 2023 Yearly Actual Actual Actual Actual Actual Actual
Demand Response
Manage Budget and Risks Responsibly
Safety & Environmental
No. of workers' compensation/accidents per month 0 0 0 0 7 8 16 4 8
Total Paid losses for workers’ compensation accidents (for the month) annual $3,018 $5,489 $66,100 $272,353 $98,393 $ 145,102 $ 93,612 $ 165,402 $38,288 $ 255,273
Lost Time Incident Rate (days/year) (Dec numbers reflect annual results) <= 3.5 annual N/A N/A N/A 0.99 2.0 1.99 0.0 0.93 0.89 1.89
Lost Time Severity Rate (days/year) (Dec numbers reflect annual results) <= 71 annual N/A N/A N/A 9.90 107.4 112.63 0.0 41.71 78.2 109.75
Lost work days per month 0 0 0 0 avg 10 avg 12 avg 9 0.0 45 116
NOx reporting levels to EPA (Quarterly) (lbs/mmbtu) <0.075 0.068 0.069 0.068 0.06 0.06 0.06 0.07 0.07
# of reported spills, waste water incidents (monthly) 0 0 0 0 4 2 6 4 4
Phosphorus levels to DEC in lbs (monthly/yearly total) <0.8/37 0.174/1.979 0.165/1.986 0.153/1.965 1.87 0.705 0.688 2.028 1.169
# of new power outage claims reported (monthly) 1 0 0 0 6 3 5 7 4
# of new auto/property/other liability claims reported (monthly) 2 1 1 4 24 36 27 18 27
Purchasing & Facilities
# of Purchase Orders for Inventory (Target: avg for winter months) 42 86 72 51 738 541 636 644 593
$ value of Purchase Orders for Inv. (Target: avg dollars spent during winter) $78,000 $973,263 $919,825 $142,579 $ 6,613,883 $2,481,531 $ 4,861,023 $ 3,278,620 975,531
# of stock issued for Inventory (Target: avg during winter months) 320 730 510 631 7,207 6,777 6,187 4,402 4,545
$ value of stock issued for Inventory (Target: avg. during winter) $ 65,000 $ 151,857 $ 122,341 $ 66,331 $ 2,352,360 $ 1,925,781 $ 2,200,233 855,456 1,086,478
# of posters pulled from poles monthly (Target: goal to remove each month) 58 0 0 40 351 592 900 2,728 627
# of Spark Space and Auditorium setup/breakdowns monthly (Target: Covid impact) 3 19 16 15 199 207 132 88 87
Finance
Debt service coverage ratio (avg of previous 12-months) 1.25 5.14 4.95 4.10 FY24 3.81 FY23  4.61 FY22 4.26 FY21 3.77 FY20 3.56 FY19 NA-FY basis
Adjusted debt service coverage ratio (avg of previous 12-months) 1.5 1.34 1.29 1.25 FY24 1.29 FY23  1.22 FY22 1.08 FY21 0.93 FY20 0.90 FY19 NA-FY basis
Days unrestricted cash on hand (incl line of credit) >90 156 153 146 FY24 93 FY23 120 FY22 121 FY21 120 FY20 109 FY19 NA-FY basis
Arrearages >60 days $ 493,414 $ 484,303 $ 480,633 $ 470,940 $ 392,196 $ 408,903 $ 1,087,769 $ 749,054
Power Supply
McNeil generation (MWH) (100%) per budget 10,132 25,714 32,680 197,044 184,798 228,981 273,355 192,696
McNeil availability factor 100% 29% 81% 100% 66% 84% 67% 80%
McNeil capacity factor per budget 27% 77% 88% 45% 42.3% 52.4% 62.4%
Winooski One generation (MWH) per budget 2,573 854 1,083 29,498 36,318 25,350 24,752 21,194
Winooski One availability factor 100% 70% 90% 90% 98% 97.2% 98.3% 97%
Winooski One capacity factor per budget 47% 17% 20% 48% 56% 41.7% 37%
Gas Turbine generation (MWH) NA 19.0 18.1 6.9 484 475 356 373 441
Gas Turbine availability factor 100% 100% 100% 97% 98% 46.7% 54.5% 96%
Gas Turbine capacity factor NA 0.1% 0.1% 0.0% 0.1% 0.2% 0.2% 0.21%
BTV solar PV production (mWh) 410 117 215 5,020 4,681 5,260 5,015 5,182
Cost of power supply - gross ($000) $2,968 $2,629 $34,858 $30,002 $36,755 $30,285 $31,081
Cost of power supply - net ($000) $2,968 $2,629 $27,984 $22,710 $27,487 $22,134 $23,388
Average cost of power supply - gross $/KWH $0.11 $0.09 $0.11 $0.09 $0.11 $0.09 $0.10
Average cost of power supply - net $/KWH $0.11 $0.09 $0.08 $0.07 $0.08 $0.07 $0.08
 FY 2025
Financial Review
 February




 March 27, 2025
 Burlington Electric Department
 Financial Review

 FY 2025



Table of Contents:

● Financial Highlights 1-2


● Revenues and Expenses

 o KWH Sales – Total 3
 o Cooling/Heating Degree Days 4
 o KWH Sales – Residential & Commercial 5
 o Net Power Supply Costs 6-11
 o Operating & Maintenance Expense 12
 o Labor Overhead 13
 o Net Income 14


● Capital Spending 15 - 18


● Cash 19
 FINANCIAL HIGHLIGHTS – BUDGET VS ACTUAL as of FebruaryFY25

 Full Yr CURRENT MONTH YEAR TO DATE
  ($000) Budget Budget Actual Variance Budget Actual Variance
 Sales to Customers 56,090 4,562  4,776 214 38,337 39,108 771
 Other Revenues 3,881 301 189 (111) 2,513 2,148 (365)
 Power Supply Revenues 7,631 1,502 0  (1,502) 5,330 3,742 (1,587)
  Total Operating Revenues 67,602 6,365  4,966  (1,399) 46,181 44,999 (1,182)
 Power Supply Expense (Net) 35,540 3,005  2,967 38 23,918 23,359 559
 Operating Expense 22,912 1,747  1,526 221 14,513 14,191 322
 Depreciation & Amortization 5,832 486 500 (14) 3,888 3,946 (58)
 Taxes 3,615 305 287 18 2,420 2,296 124
  Sub-Total Expenses 67,899 5,542  5,279 263 44,739 43,791 948
  Operating Income (298) 823 (314) (1,137) 1,441 1,207 (234)
  Other Income & Deductions 6,855 285 576 290 4,704 3,920 (784)
  Interest Expense 3,204 263 264 (2) 2,153 2,114 38
  Net Income (Loss) 3,354 846 (2) (848) 3,992 3,013 (980)



Year-to-Date Results:
  Sales to Customers up $771,000 (2%). Residential Sales up $365,500 and Non-Residential Sales up
 $401,100.

  Other Revenues down $365,000 (14.5%)
 a. DSM billable (customer driven).

  Power Supply Revenues down $1,587,000 (29.8%)
 a. McNeil REC revenue of $1,726,000 compared to a budget of $2,380,000.
 b. Wind REC revenue of $1,432,000 compared to a budget of $2,222,000.
 c. Hydro REC revenue of $524,000 compared to a budget of $727,000.
 d. Other REC revenue of $60,000 compared to a budget of $0.

  Power Supply Expenses (Net) down $560,000 (2%)
 a. Fuel down $788,000.
 b. Purchased Power up $342,000.
 c. Transmission down $114,000.

  Operating Expenses down $322,000 (2.2%)

  Taxes down $124,000 (5%)
 a. Actual Winooski One Property Tax is $228,300 lower than budget assumption for the year.
 b. Actual Payment in Lieu of Tax (PILOT) is $63,500 higher than budget assumption for the year.

  Other Income & Deductions down $784,000 (16.7%)
 a. Timing of customer contribution/grant proceeds unfavorable ($1,165,000).
 b. Timing of jobbing unfavorable ($157,700).
 c. Offset by unrealized gain on investment $132,000 and interest income $82,900.




 p.1
 FINANCIAL HIGHLIGHTS – BUDGET VS ACTUAL as of FebruaryFY25




 Capital Spending – February YTD
 ($000s)
 Plant Type Full Yr. Budget Budget Actual % Spent
 Production $2,446 $1,568 $1,970 81%
 Other 369 328 162 44%
 Transmission 577 577 577 100%
 Distribution 5,797 4,562 2,891 50%
 General 2,478 1,714 271 11%

 Total $11,667 $8,749 $5,871 50%

(1) Production – Timing; YTD budget includes replacement rail cars ($50,000) and catalyst
 replacement for NOx system ($225,000) at the McNeil Plant. Offset by timing of planned
 FEMA contribution for large inflatable dam replacement at Winooski One hydro.

(2) Distribution – Timing of Transformers ($1,219,600).

(3) General – Timing; budget includes IT Forward CIS implementation $1,068,000 vs $73,000,
 key fob system replacement, $68,200 and new SCADA room, $64,800.




 As of February 28, 2025
 Operating Cash and Investments
 Operating Funds $10,194,000
 Operating Fund – CDs $979,000
 Total Operating Cash $11,173,000




 Credit Rating Factors – February 2025
 3 Year
 "A" "Baa" Current Average
 Debt Service Coverage Ratio 1.25 1.25  5.14 4.19
 Adjusted Debt Service Coverage Ratio 1.50 1.10  1.34 1.24
 Cash Coverage - Days Cash on Hand 90 30
 - With $10M Line of Credit 156 129
 - Without Line of Credit 92



 p.2
 Burlington Electric Department
 Fiscal Year Ending June 30, 2025


 Total Sales to Customers - KWH
 Monthly


 35,000




 30,000




  KWH (000)
 25,000




 20,000
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget 31,875 30,916 26,348 24,728 24,527 26,775 27,534 25,154 25,632 23,380 24,109 26,888
 Actual 32,858 30,322 26,906 25,257 24,535 27,234 28,719 26,360




 KWH Sales to Customers (YTD)
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
Budget 31,875 62,791 89,139 113,867 138,394 165,169 192,703 217,857 243,489 266,869 290,978 317,865
 Actual 32,858 63,180 90,086 115,343 139,878 167,112 195,831 222,192



 p.3
 FY 2025
 Cooling Degree Days (CDD)
 400
 350
 300
 250
 200
 150
 100
 50
 0
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget CDD 269 220 85 9 1 0 0 0 0 2 52 132
 Actual CDD 340 195 78 10 0 0 0 0



 Heating Degree Days (HDD)
 1,600
 1,400
 1,200
 1,000
 800
 600
 400
 200
 0
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget HDD 2 6 109 388 787 1,081 1,316 1,154 1,013 577 211 44
 Actual HDD 0 17 53 365 682 1,118 1,342 1,221

 Average Monthly Temperature
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
Budget 73 72 64 53 39 30 22 24 32 46 60 68
Actual 76 70 66 53 42 29 22 21

CDD/HDD definition per National Weather Service : Degree days are based on the
assumption that when the outside temperature is 65°F, we don't need heating or cooling to be
comfortable. Degree days are the difference between the daily temperature mean (high
temperature plus low temperature divided by two) and 65°F. If the temperature mean is above
65°F, we subtract 65 from the mean and the result is Cooling Degree Days. If the temperature
mean is below 65°F, we subtract the mean from 65 and the result is Heating Degree Days.


 p.4
 Burlington Electric Department
 Fiscal Year Ending June 30, 2025
 KWH Sales


 Residential Customers


 10,000


 9,000




 KWH (000)
 8,000


 7,000


 6,000


 5,000
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget 8,781 8,358 6,618 6,333 6,882 8,264 9,026 8,027 7,724 6,132 5,808 6,992
 Actual 9,514 8,313 6,733 6,475 6,932 8,616 9,293 8,355




 Commercial & Industrial Customers


 25,000


 22,500


 20,000


 KWH (000) 17,500


 15,000


 12,500
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget 23,095 22,558 19,730 18,395 17,645 18,511 18,508 17,127 17,908 17,248 18,300 19,895
 Actual 23,344 22,009 20,173 18,782 17,603 18,618 19,426 18,005




Street Lighting is included with Commercial & Industrial Customers.




 p.5
 Net Power Supply Costs
 February - FY 2025
 ($000)
 Current Month Year-to-Date
 Budget Actual Variance Budget Actual Variance
Expenses:
 Fuel (p. 7) $1,048 $933 $115 (1) $6,762 $5,974 $788 (1)
 Purchased Power (p.11) 951 1,081 (130) (2) 9,919 10,262 (342) (2)
 Purchased Power Adjustment (p 11) 43 43 (0) 347 347 (0)
 Transmission Fees - ISO 731 701 30 (3) 5,202 5,345 (143) (3)
 Transmission Fees - Velco 140 120 19 (4) 1,069 895 174 (4)
 Transmission Fees - Other 92 88 4 (5) 619 536 83 (5)
Total Expenses 3,005 2,968 38 23,918 23,359 560

Revenues:
 Renewable Energy Certificates - McNeil 864 0 (864) 2,380 1,726 (655)
 Renewable Energy Certificates - Wind 512 0 (512) 2,222 1,432 (790)
 Renewable Energy Certificates - Hydro 127 0 (127) 727 524 (203)
 Renewable Energy Certificates - Other 0 0 0 0 60 60
Total Revenues 1,502 0 (1,502) (6) 5,330 3,742 (1,587) (6)

Net Power Supply Costs $1,503 $2,968 ($1,465) $18,589 $19,616 ($1,028)

Load (MWh) 25,801 26,881 1,079 223,657 227,764 4,107
$/MWh $58.26 $110.40 $52.14 $83.11 $86.13 $3.01

Current Month:
(1) See detail on page 7.
(2) See detail on page 11.
(3) ISO-NE Peak Load under Budget.
(4) BED share of VELCO Common charges under Budget.
(5) NYPA NYISO Transmission charges booked as estimate. Actuals will be trued up in March.
(6) Timing of REC deliveries.

YTD:
(1) See detail on page 7.
(2) See detail on page 11.
(3) ISO-NE Peak Load over Budget.
(4) VELCO Common charges under Budget
(5) NYPA NYISO Transmission charges under Budget.
(6) REC Sales under Budget due to lower McNeil and Wind production in Calendar Year 2024.

 p.6
 Net Power Supply Costs
 February - FY 2025

 ($000)
 Current Month Year-to-Date
 Budget Actual Variance Budget Actual Variance
FUEL:

McNeil:
McNeil 1,034 927 107 (1) 6,644 5,891 752 (1)

Gas Turbine 14 6 8 (2) 118 83 35 (2)

Total Fuel 1,048 933 115 6,762 5,974 788




Current Month:
(1) McNeil production 19% under Budget. Wood Price per Ton 4% over Budget. (p. 8)
(2) GT production (18 MWh) 39% under Budget.

YTD:
(1) McNeil production 9% under Budget. Wood Price per Ton 3% under Budget. (p. 8)
(2) GT production (201 MWh) 17% under Budget.




 p.7
 Burlington Electric Department
 McNeil Plant - MWH Production (50%)
 FY 2025
25,000




20,000




15,000




10,000




  5,000




 0
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
Budget 11,656 11,656 3,760 4,324 7,520 17,484 17,484 15,792 13,968 3,300 3,150 6,317
Actual 5,016 8,822 14,029 0 8,548 15,831 16,340 12,857
Maximum 18,600 18,600 18,000 18,600 18,000 18,600 18,600 16,800 18,600 18,000 18,600 18,000




 p.8
 Burlington Electric Department
 Winooski One - MWH Production
 FY 2025
  8,000


  7,000


  6,000


  5,000


  4,000


  3,000


  2,000


  1,000


 0
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
Budget 2,650 1,246 832 1,541 1,942 3,216 2,531 1,587 2,032 4,503 3,575 3,643
Actual 2,803 2,784 1,054 1,032 1,316 1,355 1,082 853
Maximum 5,506 5,506 5,328 5,506 5,328 5,506 5,506 4,973 5,506 5,328 5,506 5,328




 p.9
 Burlington Electric Depatment
 Fiscal Year 2025


 Woodchips Price Per Ton
 Monthly Variance


 30%
 25%
 20%
 15%
 10%
 5%
 $/Ton
 0%
 -5%
 -10%
 -15%
 -20%
 -25%
 -30%
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Actual -2% -3% -2% -3% -4% -4% 1% 4%




 Woodchips Price Per Ton
 Year-to-Date Variance


 30%
 25%
 20%
 15%
 10%
 5%
 $/Ton
 0%
 -5%
 -10%
 -15%
 -20%
 -25%
 -30%
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Actual -2% -2% -2% -3% -3% -3% -3% -3%




* Wood only. Does not include other costs.




 p.10
 Net Power Supply Costs
 February - FY 2025
 ($000)
 Current Month Year-to-Date
 Budget Actual Variance Budget Actual Variance

PURCHASED POWER:

Non-Energy (capacity) 62 27 34 549 394 155

Energy:
 Georgia Mountain Wind 293 330 (37) (1) 2,220 2,329 (108) (1)
 Hancock Wind 315 349 (35) (2) 2,030 2,042 (12) (2)
 VT Wind 225 193 31 (3) 1,590 1,746 (156) (3)
 Hydro Quebec 272 271 1 2,402 2,397 5
 Great River Hydro 0 0 0 1,064 1,135 (71) (4)
 In City Solar Generators 42 21 22 (4) 487 496 (9) (5)
 NYPA 5 8 (3) 49 59 (10)
 ISO Exchange (373) (321) (52) (5) (1,231) (1,663) 431 (6)
 ISO Exchange Adjustment 43 43 (0) (**) 347 347 (0) (**)
 FirstLight 0 120 (120) (6) 0 741 (741) (7)
 Velco Exchange 0 (1) 1 0 (6) 6
Total Energy 822 1,015 (193) 8,957 9,622 (665)

Ancillary Charges 1 16 (15) (95) (58) (36)

VT RES Tier 1 Compliance Expense 54 0 54 (7) 433 172 262 (8)
Miscellaneous-Other 56 67 (11) 421 479 (58)

Total Purchased Power Expense 994 1,125 (130) 10,266 10,609 (342)

Special Note (**)
Adjustment to reduce expense and create regulatory asset by amount of ISO Exchange excess winter energy revenue shortfall ($4,162,233) and
record one-eighth ($520,279) as amortization in FY24.

Current Month:
(1) Production 13% over Budget.
(2) Production 11% over Budget.
(3) Production 14% under Budget.
(4) Production under budget.
(5) McNeil (19%) and Winooski One (46% due to bladder work) production under Budget.
(6) FirstLight contract not in Budget.
(7) VT RES Tier 1 Compliance budgeted monthly, expensed quarterly.

YTD:
(1) Production 5% over Budget.
(2) Production 1% over Budget.
(3) Includes additional congestion relief charge not in Budget.
(4) Associated RECs not Budgeted under Energy.
(5) Production over budget.
(6) Energy Prices over Budget. Wind Production 2% over budget.
(7) FirstLight contract not in Budget.
(8) VT RES Tier 1 Compliance budgeted monthly, expensed quarterly.




 p.11
Burlington Electric Department
Operating and Maintenance Expense by Spending Category
FY 2025 - February YTD
 %
 Budget Actual Variance Variance *
Labor-Regular 5,843,070 6,040,003 (196,933) 3% a
Labor-Overtime 286,715 339,628 (52,913) 18% b
Labor-Temporary 200 1,791 (1,591) 796%
Labor-Overhead 2,519,324 2,732,540 (213,216) 8% c
Outside Services 1,609,731 1,324,338 285,393 18% d
DSM (rebates & outside services) 1,380,772 1,231,643 149,129 11% e
Materials & Supplies 644,887 517,884 127,003 20% f
Insurance 520,811 427,677 93,134 18%
A & G Clearing (738,637) (519,251) (219,386) 30% g
Other - RES Tier 3 Compliance 641,487 529,046 112,441 18%
Other 1,804,285 1,565,825 238,460 13% h

  Operating & Maintenance Expense 19,307,432 16,747,105 2,560,327 13%



(a) Labor is impacted by the amount of capital (vs. expense) work.


(b) Areas higher than planned include Distribution, $9,100 and McNeil Plant, $54,000; offset by areas lower than
planned include System Operations, ($16,000).

(c) See page 13.

(d) Timing of various areas.

(e) Projects are driven almost entirely by customer decisions. The budget is based on information on specific
projects or seasonal variations; otherwise the amount is spread evenly across the year.

(f) Timing of various areas.

(g) The credit for A&G ("Admin and General Expenses") charged to Capital projects was less than planned.

(h) Timing; various areas are less than budget including, Maintenance Contracts ($53,400), Education & Training
($59,500), Transportation Clearing ($145,900), Building Clearing ($15,800) and Utilities ($37,000).




 p.12
 Burlington Electric Department
 Budget vs Actual Spending Analysis
 FY 2025 - February YTD

 (000's)
Labor - Overhead Budget Actual Variance %

 Pension $1,287 $1,236 $51 4% (a)
 Medical Insurance 1,387 1,558 (171) -12% (b)
 Social Security Taxes 704 656 48 7% (c)
 Workers Compensation Ins. 278 278 (0) 0% (b)
 Dental Insurance 63 59 4 6% (b)
 Life Insurance 13 13 0 3% (b)
 Childcare Contribution Tax 41 36 4 10% (d)
 $3,773 $3,837 ($64) -2%



Rates Table: Budget

Pension (a) 14.13%

Social Security (c) 7.65%

Childcare Payroll Tax 0.44%


(a) Function of labor cost.

Includes pension per Actuarially Determined Employer Contribution (ADEC), $1,843,800
and amortization of IBEW Pension back payment, $87,041.

(b) Budget provided by the City during budget development. Actual YTD reflects an error
that will be corrected throughout the remainder of the year.


(d) New tax as of July 1, 2024 is 0.44% of wages. Budget had assumed .33% of wages.



 p.13
 Net Income
 FY 2025 - February ($000)

 Current Month Year - To - Date
 Ref Budget Actual Variance Budget Actual Variance
Operating Revenues
 Sales to Customers p.3 4,562 4,776 214 38,337 39,108 771
 Other Revenues 301 189 (111) (a) 2,513 2,148 (365) (a)
 Power Supply Revenues p.6 1,502 0 (1,502) 5,330 3,742 (1,588)
 Total Operating Revenues 6,365 4,966 (1,399) 46,181 44,999 (1,182)

Operating Expenses
 Fuel p.6 1,048 933 115 6,762 5,974 788
 Purchased Power p.6 994 1,124 (130) 10,266 10,609 (343)
 Transmission p.6 963 910 53 6,890 6,776 114
 Operating and Maintenance p.12 1,747 1,526 221 14,513 14,191 322
 Depreciation & Amortization 486 500 (14) 3,888 3,946 (58)
 Revenue Taxes 56 53 4 434 433 1
 Property Taxes Winooski One 45 26 19 (b) 358 206 152 (b)
 Payment In Lieu of Taxes 203 208 (5) (c) 1,628 1,657 (29) (c)
 Total Operating Expenses 5,542 5,279 263 44,739 43,791 948

Other Income and Deductions
 Interest/Investment Income 36 35 (1) 334 417 83
 Dividends 373 374 1 2,982 3,005 23
 Customer Contributions/Grant Proceeds 34 186 153 (d) 1,694 529 (1,165) (d)
 Gain/(Loss) on Disp of Plant (157) 0 157 (336) (26) 310
 Other (0) (20) (20) (e) 30 (5) (35) (e)
 Total Other Income & Deductions 285 576 290 4,704 3,920 (784)

Interest Expense 263 264 (2) 2,153 2,114 38

Net Income 846 (2) (848) 3,992 3,013 (980)

Current Month:
(a) Energy Efficiency Program cost reimbursement was lower than planned, $107,000.
(b) Actual Winooski One tax bill is lower than budget assumption by $228,300 for the year.
(c) Actual Payment in Lieu of Tax (PILOT) is higher than budget assumption by $63,500 for the year.
(d) Budget includes customer contributions for other overhead billable ($10,000). Also, grant income for "Building Giants"
 (Federal 50% share) ($24,100). Actual includes customer contributions for overhead billable, $95,000 and various grant
(e) Timing of jobbing unfavorable ($33,500); offset by unrealized gain on investment, $14,700.

Year - To - Date:
(a) Energy Efficiency Program cost reimbursement was lower than planned, $413,400.
(b) See current month.
(c) See current month.
(d) Budget includes Winooski One FEMA reimbursement (75%) for inflatable dam ($1,057,500), and other customer contributions
 for Champlain Parkway ($191,000), Winooski bridge rebuild ($34,800) and other overhead and underground billable. Also,
 grant income for FEMA reimbursement for July '23 flooding at Winooski One ($101,800) and "Building Giants" (Federal 50%
 share) ($192,400). Actual includes overhead & underground billable and various grant income.
(e) Timing of jobbing unfavorable ($157,700); offset by unrealized gain on investment, $132,000.




 p.14
 Burlington Electric Department
 Capital Projects - FY25

 $000
 Full Year February
 Budget Budget Actual Variance

McNeil (BED 50% Share)
Ash Silo Pug Mill/Auger Upgrade (312) 25 0
Catalyst Replacement for Nox System (312) 450 450 226 225
Condensate Motor (314) 10 0
Condensate Pump (314) 15 0
Cooling Tower Make-Up Pumps Replaced (314) 8 0
ESP Mechanical Field Rebuild 284 0
Farmhouse Improvements (311) 10 5 (5)
McNeil - IT Forward FIS 38 13 13
Reclaimer Rebuild (312) 30 0 (0)
Replace Water & Sewer Lines at the Farmhouse (311) 28 0
Replacement Rail Cars (312) 50 50 50
Routine Station Improvements 1 188 113 38 75
Safety Valve Replacements (312) 13 6 6
Station Tools & Tool Boxes (312) 8 5 3 2
Turbine Control System Upgrade/Insurance (314) 0 21 (21)
Woodchip Dryer (1 of 2) (312) 38 38 1 37
Loader repair 0 (25) 25
Other 16 13 0 13 (a)
 Total McNeil Plant 1,209 687 269 419

(a) Budget includes perimeter fence upgrade, rigging equipment, portable radios upgrade, energy efficiency
improvements and furniture.

Hydro Production 980 699 1,692 (994)

(a) Full year budget assumes inflatable dam project at a cost of $1.3M with 75% reimbursement from FEMA of $1.1M.

Gas Turbine 257 183 9 174 (a)

(a) Timing; budget assumed roof replacement in August, $97,600, delayed until spring.

 Total Production Plant 2,446 1,568 1,970 (401)

Other
Direct Current Fast Chargers (Level 3) 171 154 117 37
Distributed Energy Resources 33 26 26
EV Charger Installations (Level 2) 127 114 42 73
EV Chargers Public (Level 2) 3 (3)
EV Chargers/Staging Plan 13 13 13
P&P R&D 26 21 21
 Total Other 369 328 162 166




 p.15
 Burlington Electric Department
 Capital Projects - FY25

 $000
 Full Year February
 Budget Budget Actual Variance

Transmission Plant
VT Transco Investment 577 577 577 0
 Total Transmission Plant 577 577 577 0

Distribution Plant-General

Aerial
Archibald St Rebuild 66 66 55 11
Barrett Street Rebuild 10 (10)
Dunder Road Rebuild 58 58 1 56
Killarney Drive Rebuild 0 (3) 3
North St Rebuild P1577-1486 0 105 (105)
Replace 2L5 Circuit from P2349-913S 0 21 (21)
Replace Condemned Poles 110 110 82 28
South Cove Road East Rebuild 145 145 18 127
South Cove Road West Rebuild 184 184 4 180
 Total Aerial 563 563 293 270

Underground
Battery St Phase I Replace UG Cable 50 (50)
Battery St Phase II Replace UG Cable 517 517 517
Cathedral Square Rebuild 41 41 43 (2)
College St (Pine - St Paul St) Replace UG Cable 148 74 62 12
Fern Hill UG Rebuild 0 4 (4)
Replace 2L5 Cable 913s to UH248 0 35 (35)
Summit Ridge Rebuild 63 63 168 (105)
Switch 305S/325S/326S (Main St Reservoir) 258 258 165 93
Switch 322/323/324S (Main St and Univ Hts) 242 242 185 57
Switch 817S/912S/913S (Main St Reservoir) 151 151 98 54
 Total Underground 1,421 1,346 809 538

Customer Driven/City Projects
Champlain Parkway-Billable 345 224 11 214
Champlain Parkway (CAFC) (294) (191) (327) 136
City Place Streetlighting 306 0
City Place Streetlighting (CAFC) (197) 0
Great Street Initiative 0 0 (0)
Great Street-Main Street 23 15 5 11
Great Street-Main Street (CAFC) (23) (15) (15)
Winooski Bridge Rebuild 35 35 35
Winooski Bridge Rebuild (CAFC) (35) (35) (35)
 Total Underground 161 33 (312) 345




 p.16
 Burlington Electric Department
 Capital Projects - FY25

 $000
 Full Year February
 Budget Budget Actual Variance

Other
College St Breaker Racking Device 25 25 25
Distribution Transformers-Purchase 1,590 1,431 211 1,220
Distribution Transformers-Install 6 5 14 (9)
Communication Equipment Emergency Repair 15 10 10
ADMS SCADA Upgrade (Phase I/11) 617 555 870 (315)
ADMS SCADA Upgrade (Phase III/IV) 542 0
SCADA Servers PC's and Monitors 0 41 (41)
SCADA Video Display 0 0 (0)
SCADA Equipment 128 128 17 111
Other 3 (3)
 Total Other 2,922 2,154 1,157 997

 Total Distribution Plant-General 5,066 4,097 1,947 2,150

Distribution Plant - Blanket
Aerial 146 91 81 10
Aerial (CAFC) (64) (35) (49) 14
Underground 321 168 371 (203) (a)
Underground (CAFC) (132) (66) 160 (226) (a)
Meters 178 138 159 (21)
Lighting 223 124 193 (69)
Tools & Equipment - Distribution/Technicians 30 24 24 (0)
Replaces Failed SCADA Field Equipment 11 8 2 6
Substation Maintenance 18 13 2 11
 Total Distribution Plant - Blanket 731 465 944 (479)

(a) Actual includes prior year progress billing that was reversed, $277,368 in September (wf 36863 - City Place).

 Total Distribution Plant 5,797 4,562 2,891 1,671




 p.17
 Burlington Electric Department
 Capital Projects - FY25

 $000
 Full Year February
 Budget Budget Actual Variance



General Plant
Computer Equipment/Software 2,127 1,363 223 1,140 (a)
Vehicle Replacement 191 191 191
Buildings & Grounds 155 155 48 107 (b)
Gas Detectors 5 5 5
 Total General Plant 2,478 1,714 271 1,443



(a) Budget includes IT Forward, $1,068,000 vs actual of $73,000. Other various projects include AMI Network
Infrastructure replacement, desktop/laptop replacements, iPads replacements for line crew and engineering plotter.
(b) Budget includes Key Fob Replacement, New SCADA Room, Storage racks for red warehouse and Ice Machine
(breezeway). Actual includes fence for solar array and security cameras.

 Sub-Total Plant $11,667 $8,749 $5,871 $2,878

 Add: CAFC* reclass to "Other Income" 1,803 1,400 216 1,184



Total Plant $13,470 $10,149 $6,087 $4,062

* Customer Advances (Contributions) for Construction.




 p.18
 Operating Cash - FY 2025
 Monthly Ending Balance
 14,000

 12,000

 10,000

 8,000
$000
 6,000

 4,000

 2,000

 0
 Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
 Budget 7,664 8,809 11,355 11,436 10,765 10,299 11,208 11,973 10,795 9,939 11,027 9,803
 Actual 7,569 9,413 9,254 13,174 11,163 10,956 11,417 11,173




 p.19

DRAFT MINUTES OF REGULAR MEETING
 BURLINGTON ELECTRIC COMMISSION

 Wednesday, April 9, 2025

The regular meeting of the Burlington Electric Commission was convened at 5:03 pm on
Wednesday, April 9, 2025, at Burlington Electric Department, 585 Pine Street, Burlington, Vermont,
and on Microsoft Teams.

Attendance
  Channel 17 was present to record this meeting.
  Commissioners Lara Bonn, Scott Moody, Andy Vota and Bethany Whitaker were present.
  Staff members Elena Alexander, Paul Alexander, Mike Kanarick, Munir Kasti, Darren
 Springer, and Emily Stebbins-Wheelock were present at 585 Pine St.
  Staff members James Gibbons and Amber Widmayer were present via Microsoft Teams.

Agenda
  There were no changes to the Agenda.

Meeting Minutes
   Commissioner Vota made a motion to approve the minutes of the March 12, 2025,
 Commission Meeting; Commissioner Whitaker seconded the motion. Vote: 4 ayes 0 nays.

Public Forum
  No members of the public were present.

Commissioners Corner
  No items stated.

General Manager’s Update
 General Manager Springer shared that staff along with Commission Chair Moody presented the
 2025 Jim Reardon Public Service Award to Ita Meno, BED’s Project and Equity Analyst. We
 appreciate all the amazing outreach work Ita is doing in our community, making people aware
 of our programs, taking good feedback that we can learn from as we design new programs, and
 ensuring all of our customers have access to everything that we offer, as well as all the
 community service that Ita does on boards and other ventures outside of BED.

 The McNeil RFPs have been approved by the TEUC and will go to City Council on Monday along
 with the 2024 Net Zero Roadmap update.


 1
The federal DoT EV charging grant is a dynamic situation; we’ll continue to advocate and are not
giving up on it. In the meantime, we'll continue to invest and are pleased to announce that there
is a new fast charger located at the waterfront. This now makes three fast chargers in our
network: Pease lot, 585 Pine, and Marketplace Garage.

We're doing a battery storage pilot with a company called Viridi that is based in Buffalo, New
York. I was able to talk with their team a couple weeks ago based on a mutual connection about
the testing of 250kWh mobile batteries at Green Mountain Power and, instead of bringing them
back to Buffalo, they offered to bring them here. BED connected them on Tuesday and they are
now up and running. Policy & Planning staff will be using the interface and seeing how it works.
The batteries can be used for discharge events against peak. If they work out well, BED is
interested in whether we might be able to bring in a larger mobile storage unit, maybe 1.2 MWh
that we can connect here at 585 for the summertime. As we'll touch on in the budget
presentation, transmission costs continue to be an unacceptably large driver of our cost
increases and one we have almost no control over. The one piece of control we do have is if we
can reduce our peak demand, which will help reduce transmission costs in the next year's
budget. It won't necessarily help with this year's budget, but it will help us for next year and we
know the annual peak will be sometime this summer. We'll run our Defeat the Peak events, but if
we had a mobile battery, too, that could be a real help and a nice interim step between now and
when we ultimately deploy a battery or batteries around the city as a result of our RFP that we
recently issued and are reviewing results from. We'll see how this works out over the next
couple weeks and will then look into whether there's an option economically to have a larger
battery on-site to demo for the summer.

A couple of items that we covered in the press release today, but that aren't really part of the Net
Zero Roadmap are (1) we announced that we plan to ile this summer a pilot tariff for the heat
pump pilot program with the Public Utility Commission pending some vendor negotiations. The
Commission has already reviewed that, but we need to bring it to the PUC and we are waiting to
make sure that we have as long a runway as possible on our 18-month pilot once they approve
it. Once approved, we'll be able to sign up customers for the Building GIANTS program and get
them enrolled. We also announced that we're going to be piloting a process for certain rebate
programs (including induction stoves) to provide a bill credit instead of a paper check in the
mail, making it a smoother process. These smaller rebate bill credits will be rolled out this
summer. Another program offering that went live today is the Moduly residential battery
storage pilot program. Customers can express their interest and sign up to be part of that pilot.
The 10 pilot batteries are due to arrive in the next month or so. BED is looking for a mix of
customers, including rental properties and single-family homes in different locations.

BED also announced a Dynamic EV Charging Rate Option for EV rate customers. BED has
dramatically expanded the number of hours where somebody with an EV or a plug-in hybrid
can charge at the most affordable bene icial rate without contributing to peak demand. BED will
proactively alert you and then interrupt you during the peaks only. This could be around ive to
ten times a month and typically three to ive hours per duration. This option is available online
for all customers.


 2
 On Monday evening BED received a nice shout out in the Mayor’s State of the City address for
 the work we're doing around the revenue bond, electri ication incentives, and making McNeil
 more ef icient and reducing the environmental footprint. Climate continues to be among the top
 three priorities for the Mayor, as she said today during the press conference here on the Net
 Zero Roadmap.

 Commissioner Vota asked General Manager Springer to talk a little bit more about how the
 electric charging grant has been impacted by recent federal actions. General Manager Springer
 shared that BED won a competitive EV charging grant for just under $5 million through the
 Department of Transportation’s Charging & Fueling Infrastructure program. BED’s was the only
 Vermont entity to be selected for an award. The BED team worked right up until the change in
 administration to try to get the award obligated, including completing NEPA review, but it was
 not obligated prior to the transition to the new administration. That only has some relevance,
 however, because even grants that were obligated were also frozen. An executive order and an
 Of ice of Management & Budget memo have been issued essentially freezing these grants and
 establishing review periods. The terms “EV” or “EV charging” have been identi ied by the
 administration as triggering review. There was litigation and there was an injunction at one
 point from the district court to unfreeze these types of grants. The latest that we know is that
 there was a memo from the administration saying that they were pausing these grants for 90
 days while they reviewed to see if they needed to change any of the criteria related to the grants
 to match administration priorities. We are currently in that 90-day window. From a pure legal
 standpoint, it's not clear to me they can simply rescind grants that were awarded under
 Congressional appropriations legislation, absent the Supreme Court ruling that, which hasn't
 happened. Whether you could say an EV charging grant can't be used for EV charging is
 questionable in my mind. Narrowing the parameters or making it more dif icult to administer
 might be something that they'll look to do.

 Commissioner Vota asked for an update on the energy ef iciency charge and related legislative
 activity. General Manager Springer explained that the S65 bill in the legislature is tabled in the
 Senate and was complicated because there was a Clean Heat Standard repeal attached to it. The
 bill went through various committees with some consternation, not over our piece of it, but over
 broader aspects and it's been pulled back into the Senate committee. I don't know if anything
 will happen with it this year or whether a study will emerge, but it does not seem to be moving
 forward at this point. Separate from that, we’ve had a PUC proceeding related to the de icit in
 the energy ef iciency charge account related to an under-collection based on rates dating back
 to the 2020 pandemic timeframe. Ms Stebbins-Wheelock shared that in that PUC proceeding,
 the Department provided an initial set of documents to the PUC and the Public Service
 Department, there was a workshop scheduled three weeks later to answer any questions, and
 that went well. The Department of Public Service did not have any questions for us,

but the PUC hearing of icer handling the case had some questions, which we talked through, and we
agreed to supplement the record with some additional information and analysis which we just iled
last Friday. At this point, the schedule that remains in the docket is that the PSD has three weeks to
review and comment, and BED has two weeks to comment on the PSD's comments. At this point,
that's all that's scheduled or contemplated in terms of process. It's going well in terms of providing

 3
the information requested and answering all the questions. If we have done all of that satisfactorily,
I think the Commission will be able to resolve the docket in whatever way it sees it.

FY25 February Financials
Ms. Stebbins-Wheelock presented the February financial results.

In February, we had a net loss of $2,000 compared to a budgeted net income of $846,000, a variance
of $848,000 compared to budget.

Sales to customers had a positive variance of $214,000 this month. Other revenues were down
modestly, by $111k, most of which is EEU reimbursement. The biggest revenue variance is power
supply revenues or REC revenues, which were not delivered when budgeted resulting in a 100%
negative variance for the month . We expect that variance to be resolved or made up later in the
 iscal year.

Net power supply expense had a modest positive variance of $38,000, with fuel expense favorable
because McNeil production was 19% under budget, transmission slightly favorable, and purchased
power was modestly over budget. Energy prices were higher than budget and higher production
from some of our wind resources helped to offset lower McNeil production.

Other operating and maintenance expense had a positive variance of $221,000. There was a
favorable variance of $290,000 in other income and deductions due to the timing of grant proceeds
and customer contributions to capital projects.

Overall, for the year to date, as of February, the Department has an actual net income of $3 million
as compared to the budget of $4 million at this point in the year. Capital spending as of February
was $5.8 million, which is about 50% of the full-year budget. We are seeing some distribution
projects start to get installed this spring, and McNeil is currently performing their annual
maintenance outage.

Total operating cash was $11.2 million as of the end of February, $800,000 less than budget. The
debt service coverage ratio was at 5.14, the adjusted debt service ratio was 1.34, and there were
156 days cash on hand, including the line of credit.

Commissioner Vota asked if it’s a good sign that the capital budget is catching up and how
projected final net income for the year compares to the budgeted net income of $3.3
million. Ms. Stebbins-Wheelock stated that the current year-end forecast is showing that
we'll be slightly under budget for total net income, but probably not as large a variance as
exists as of February results. The REC revenues will settle out and we are also starting to
see the FEMA grant reimbursement come in for the Winooski Dam replacement, which
currently is contributing to a large variance in other income and deductions. We received
the first FEMA payment of about $900,000 a couple weeks ago, and there'll be another
$300,000 payment coming in the next couple of weeks. .
 4
FY26 Draft Budget Presentation
General Manager Springer and Ms. Stebbins-Wheelock presented the following:

The Department is still in the budget development process but we wanted to provide the
Commission with an update of where we started, where we are, and the work we still have to do to
get to a sustainable budget.

We're seeing signi icant purchase power and transmission cost increases for next iscal year, a cost
of living adjustment of 3% per the IBEW contract, and increases in health insurance and bene its
costs, as are most organizations in Vermont. Our Renewable Energy Standard (RES) obligations are
becoming more expensive by design. Our Tier 3 obligation grows each year and FY26 will be the
 irst year that the revisions to the RES that were passed last legislative session come into effect and
we will have to comply with being 100% renewable for load growth over a baseline. There will be
new expenses associated with what is called “Tier 5” in the statute, which consists of obtaining or
retiring RECs for new renewables to cover that load growth segment.

There are positives tied to this upward budget pressure. For example, the FY26 budget contains
funds to cover 50% of the expenses of the Building GIANTS program, with the other 50% grant
funded. We are in our irst year of paying for new software systems that are 100% BED-funded, but
we will be paying for the old systems as well during the transition.

The Customer Information System, Distributed Energy Resources Management System, and Outage
Management System are all new maintenance contracts budgeted in FY26. Because of the additional
federal grant income we have received in recent years, we anticipate being over the threshold in
FY25 for requiring a “single audit” our Uniform Guidance audit of our grant program activity, which
is also an added expense.

BED plans to issue the Net Zero Energy & Grid Reliability Revenue Bond in FY26 and has included
those issuance costs in the budget as an expense.

We have materials, supplies, and other expenses that are subject to in lation. Luckily, we are not
seeing high rates of in lation like we saw three years ago, but there are still in lationary pressures in
the budget.

Commissioner Whitaker asked about the retirement fund and pension investments and with the
current stock market status whether there will be enough money in the fund. Ms. Stebbins-
Wheelock explained that BED’s contribution to the pension fund is based on an actuarial valuation
that was done as of last June 30th and is based on a 5-year average so what's happening in the stock
market right now won't affect us until a year from now. The City also has lowered its assumptions
around pension investment returns over the past several years to make up for previously higher
assumptions, although there is still a gap between the pension liability and plan’s funding. To
address the stock market volatility, we assume a year-end pension expense adjustment equal to the
previous three-year average.

 5
Commissioner Bonn asked what is being done to plan for future tariff impacts. Ms. Stebbins-
Wheelock stated that BED has seen the irst invoices listing “shipping tariffs” as a line item, but
there haven't been many and expenses from new tariffs have not been budgeted for in any speci ic
way.

Ms. Stebbins-Wheelock continued with the presentation, stating that another line item helping the
budget, albeit modestly, is growth in kilowatt hour sales of about 1.5%, which translates to a 1.4%
revenue increase. REC markets are strong right now, which also increases budgeted FY26 revenue.

All together, we had an initil budget gap of about $5.5 million to get to a net income that gives us
healthy Moody's rating metrics.

Ms. Stebbins-Wheelock then reviewed highlights from the preliminary FY26 capital budget.
Distribution system investments to support reliability and Net Zero Energy, leet electri ication, and
replacing essential vehicles continue to be part of the capital budget. One of the largest new capital
items is the FERC relicensing of Winooski One, which we can capitalize because the license is good
for 30 years and the costs of relicensing can be amortized over the period. We've been working on
this project for about 18 months, with BED staff, lawyers, and consulting engineers preparing FERC
 ilings and planning for relicensing. We are now in the stage of conducting FERC-ordered natural
resource studies, for example on eels and other ish species, which will be the biggest capital
expenditure. This is a major project consisting of two study seasons, the irst beginning this spring
and the other to follow next summer.

The second signi icant new item is the wood chip dryer at McNeil. The irst phase in FY26 will
consist of design and engineering, the second phase is the installation, which is planned for FY27.

In FY26 the customer information system, portal, outage management system, and distribution
management system IT Forward projects will be completed and the plan is to also begin replacing
the inancial system in FY26. The CIS, FIS, and Work Asset Management system replacemetns need
to happen close together because they're replacing a uni ied legacy system.

Two uncertainties affecting the capital budget are the status of federal EV charging grant funds and
timing of issuance of the next revenue bond.

Ms. Stebbins-Wheelock then presented key assumptions in the preliminary FY26 budget:
  Currently, the Department is projecting a 4.5% rate increase to support the FY26 budget. We
 had hoped to limit the increase to 3%, but with the $5.5 million gap, we needed to move to
 the 4.5%.
  Energy price assumptions are higher than FY25.
 
  Modest increase in the price per ton of wood fuel
  3% cost of living adjustment
  Tier 3 electri ication above our compliance requirement by 20%
  $222,000 investment in VELCO Equity


 6
  continued capital investments using the remaining proceeds of the 2022 revenue bond,
 proceeds from the new 2025 Revenue Bond, as well as our annual $3 million general
 obligation bond.

Ms. Stebbins-Wheelock then reviewed preliminary line-item changes from the 2025 budget:

  Sales to customers, between the load growth and a 4.5% rate increase, would increase by
 5% or $2.8 million.
  REC revenues are budgeted to be up 19% from last year.
  Fuel, a modest increase of around 5%.
  Transmission expense is budgeted to increase even more than last year, by 14%.
  Purchased power is also up signi icantly at 14%. $360,000 of the $2.2 million purchased
 power expense increase is related to load growth. Tier 1 VT RES compliance is up $400,000
 due to the cost of the VT Tier 1 replacement RECs that we purchase for arbitrage. The Hydro
 Quebec contract price is up, adding just over $250,000 of expense. (Hydro Quebec has an
 index to the wholesale electric prices which have increased 27%.) In the forward reserve
 market, we are budgeting conservatively for a brand-new set of market rules that Took
 effect on March 1. The new market rules do open up the possibility for additional revenues
 for McNeil. Capacity charges are also up, and the new Tier 5 compliance requirement is
 adding $120,000 of cost. Our First Light contract that we signed last summer will expire at
 the end of December 2025, which means BED will have to enter a new power supply
 contract to replace that renewable energy. As you saw, energy prices are quite high. If we
 simply replaced that contract for the rest of a budget year we would expect no savings
 compared to market price because the seller and BED are aware of those market prices and
 there is not a lot of motivation for differentiating them. If we can do something creative like
 signing a longer-term contract or switching to another supplier we might improve the
 budget but not drastically. BED has reached out to potential renewable energy suppliers, but
 has not had a lot of response.
  Labor and labor and overhead (bene its & pension) is up a combined 9%.
  Maintenance contracts are up 34%, in part due to the new software systems.
  Materials and supplies are up 21%.
  Tier 3/tier 5 compliance are increasing by $191k.
  Revenue bond issuance costs of $150k.
  Interest rates have fallen, which means we're going to make less on our interest on
 investments in the bank.
  Grants and capital contributions are projected to be $346k less than FY25.
  Interest expense is predicted to drop by 4%.

Commissioner Bonn asked if BED has done a deep dive into where costs can be cut. Ms. Stebbins-
Wheelock responded that since March 17, the management team has made adjustments and cuts to
reduce the $5.5 million gap to a $2 million gap. The team will continue to review this week to see
what additional cost savings can be found.

Ms. Stebbins-Wheelock then summarized that the current budget draft shows an operating loss of
$3.2 million with net income of only $500k. Net income should be closer to $2.5 million to achieve
 7
our targeted Moody's metrics. FY26 year-ending operating cash is currently projected at $12
million. The Department is continuing to re ine the capital budget. The non-revenue bond funded
portion is just under $3 million, which with the funding of our Tier 3 incentivesuses the $3 million
general obligation bond that we receive annually. The revenue bond-funded amount is high and
even higher than our FY25 budget. The BED team has had conversations about how much of this
spending is supported by internal labor versus how much involves consultants – such as the
Winooski One environmental studies, which are a capital outlay, but not necessarily expending a lot
of resources internally.

As would be expected, the current draft budget does not support adequate Moody's metrics. Days
cash on hand is okay at 125 and the debt service coverage ratio is okay at 4.17, but the adjusted
debt service coverage ratio is way too low at 0.97. The Department needs to close the $2 million net
income gap to get the ADSCR in the 1.2 range. Commission Whitaker asked if BED needed to have
the 1.2 ADSCR in order to issue the new revenue bond or inance projects. General Manager
Springer con irmed that, no, we do not. The ADSCR is related to our Moody’s A rating. The only
bond covenant item is that the debt service coverage ratio has to be at least 1.25.

Commissioner Whitaker asked if it would be bene icial for BED to save money by delaying capital
projects and whether that has been assessed. General Manager Springer explained that the
challenge of delaying or cutting capital projects is that they are typically labor-intensive. If you defer
them, that capitalized labor expense comes back to the operating budget. The other piece is that if
something is revenue-bond funded, we can be a little bit agnostic as to the timing of it. If the total
non-revenue bond funded projects exceed the annual $3 million GO bond, then you would start to
eat into cash. The bigger concern is whether we can move that much capital work through our
system, even if some projects involve vendor and external partners. BED has typically underspent
its capital budget so we may have the ambition to do that level of work and budget for it but then
realize during the year that something doesn't advance as quickly as we want it to and it does not
get done.

Commissioner Whitaker asked if it would help to issue the bond later or postpone projects? General
Manager Springer responded that no, it would not, from the operating cash or operating expense
standpoint.

Commissioner Vota asked if the prior bonds still have money left on them; Ms. Stebbins-Wheelock
responded that no, funds from all prior bonds except the 2022 revenue bond have been expended.
Commissioner Vota asked, when a new bond is issued, how does a bond show up in the inancials?
Ms. Stebbins-Wheelock explained that the bond is a liability, like an outstanding mortgage that you
still have to pay off. All of the previously issued bonds are listed on the balance sheet under long-
term liabilities, which shows the total outstanding debt we are paying off. The interest owed on the
debt appears as interest expense on the income statement. The principal on the bonds appears on
the cash low statement.

Commissioner Vota asked how the bond funds are issued. Ms. Stebbins-Wheelock explained that
after the bonds are issued, the monies go to the bond trustee, Zions Bancorp, who holds the money
in a construction fund. As the Department spends money on projects designated for the revenue
bond, we issue a requisition with an itemized list of projects and expenditures to the bond trustee
 8
once a month and they transfer money from the construction fund to BED to cover those expenses
that have already been paid. Mr. Gibbons added that when we ile a cost of service for a rate
increase, we ile to recover our expenses, which include the interest but not the principal payment.
We recover principal expenses through having depreciation expense.

Ms. Stebbins-Wheelock stated that the slides will be shared with the Commission and by the full
FY26 proposed budget in detail, including the income statement, cash low statement, and
supporting detail will be included in the Commission packet for the May meeting.

Commissioner Vota inquired if the BED team is doing any budgeting scenarios around tariff
increases. It seems prudent to do some level of analysis of what a bad tariff scenario could look like
and whether there are areas of risk in BED purchasing where tariffs are imposed. Ms. Stebbins-
Wheelock stated that while one could do scenario analysis around the speci ic tariff issue, one could
also approach it by building in a contingency for unknowns. It could be tariffs, energy prices, or
some other thing that happens, so ideally you would budget for the net income you need with a
contingency, which would help deal with the unexpected. The trade off, however, is that the
contingency would not meet the test to be included in a cost of service for a rate request and we are
already stripping out everything that we can in order to keep the requested rate increase to a
minimum. Mr. Springer added that we have done analysis on the potential impacts to our Hydro
Quebec purchased power contract if a tariff applied and was passed through appropriately. We have
not put a contingency in the budget based on that, but we do know the parameters. BED does
import some materials from China; it is not the bulk of what we typically import, but may affect
certain purchases such as battery storage systems.

Commissioner Bonn stated that if BED could rank risks or uncertainties such as Hydro Quebec,
semiconductors, battery storage, or even reliance on anticipated load growth based on heat pump
installations, we could plan what we might need to do to buffer against them. General Manager
Springer stated that if tariffs end up impacting us in a signi icant way, it's not that it's anticipated or
unanticipated; it's not fully knowable right now. If it became more concrete, we would likely adjust
our plans because we meet every month to review the progress on the budget, the current
projections, and we manage it actively during the year, adjusting and prioritizizing as needed.


FY26 Projected Rate Change
Ms. Stebbins-Wheelock stated that the Department is currently projecting a 4.5% rate change in
FY26 to take effect on bills rendered September 1, 2025. She presented a slide showing all BED rate
changes since 1980 as well as historical rate changes by a few other Vermont utilities.
Mr. Springer added that this is BED’s second-lowest rate increase since the pandemic and that the
Department has shared the 4.5% estimate with large customers (including UVM, UVMMC, and the
Water Department) whose budgets are signi icantly affected by these rate changes and need to do
budget planning in advance of when our budgets are completed.

Ms. Stebbins-Wheelock then showed the requested rate changes for the past ive years versus the
rate change we believe we could have justi ied assuming a net income equal to twice our interest
expense. In 2024 we asked for essentially what we needed, but in 2023, 2022, and 2021 we asked

 9
for signi icantly less than what we could hav justi ied. The accounting and policy and planning
teams are working now on developing the cost of service for 2025.

Wholesale energy prices, as you saw in our budget, are projected to be higher for FY26 not only in
Vermont and New England but everywhere around the country. An EIA projection from this January,
shows that the Southwest and California are looking at 30-35% increases in wholesale power. New
England’s projected increase is 16% compared to last year.

General Manager Springer discussed some recent news articles reporting increased energy prices
and electric bill for utilities in Rhode Island and Massachusetts, where they are more subject to the
volatility of the natural gas markets. and saw natural gas and electric prices rising over 30% over a
two-year period. BED is not seeing that kind of volatility due to our 100% renewable portfolio,
including McNeil. Mr. Springer stated that while the Department is not happy to have a 4.5% rate
increase, cost pressures in the electric utility space are broader than BED. Because Vermont is a
fully vertically integrated and regulated state versus deregulated, the utilities have long-term power
planning, and stably priced contracts that protect us against some of these market spikes and we
also have our own resources that we can rely on to some extent. The context doesn't make it any
easier for anybody in Burlington who's seeing any type of cost increase to bear the rate change, but
we are trying to keep rate changes to the low single digits and as stable and predictable as possible,
without dramatic spikes that nobody can afford or manage. Vermont’s mandates for the
diversi ication of energy sources and long-term, stably priced renewable energy contracts or owned
resources may sometimes look like we're not saving as much money as other states, but when
prices spike, we have a lot of upside protection relative to what you would see when you are more
exposed. McNeil is a big part of that for BED because we can control when it operates. The plant ran
pretty steadily in December, January, and February this past winter, insulating us from the impacts
that southern New England experienced and earning BED money for being available and producing
power during that period. In addition, BED is in the market for hydro resources and have found it
hard to come by.

Mr. Gibbons made the point that, if the energy prices are up 27%, our energy cost costs aren't up
27% because of our resource portfolio. Some contracts, like Hydro Quebec, do move up. It's not
perfect insulation and none of our resources insulate us against transmission, which is very hard to
control unless you can reduce your coincident peak and do so at a cost less than paying for your
coincident peak.

Mr. Springer stated that apart from this power supply dynamic, larger entities in New England are
proposing some very expensive projects that they say are needed for reliability or to connect
resources. BED is only 4% of the region, so we're not the big player. There are some larger utilities
that are signi icantly resourced that can earn a signi icant return on building transmission, some of
which is going to be looked at on a national regulatory level more than a state regulatory level if it’s
interstate transmission. The amount of leverage or control that individual states or even a group of
states have over that buildout can be limited. There's a guaranteed rate of return on those
transmission projects if they're done under certain provisions, and the difference between that
buildout and what we build in Vermont and receive from the region is driving the $1.5 million
increase in transmission expense this year. We have no control over it because we have to be
connected to the grid and BED is paying a lot as a relatively small utility. That raises the challenge
 10
for VELCO to determine what projects need to be done and how will they be covered, which in turn
drives equity calls by VELCO because they need to inance those projects a mix of equity and debt.
The equity is good, contributing $4.5 million annually to our net income in dividends, but the ability
to come up with the cash to pay for that equity in order to get that return has become a signi icant
challenge. We are working with VPPSA and looking at a variety of inancing options. Battery storage,
if it's cost effective, could also help mitigate it. VELCO is aware of the regional challenge and to some
extent the state is looking at these issues as well. We'd love to see aggressive advocacy from
Vermont at the regional level to scrutinize these costs and make sure that we're not overbuilding
multibillion dollar projects that are adding cost to all of our customers. Motivation is critical here,
which is if you're a transmission company, you must make investments.

Ms. Stebbins-Wheelock showed graphs, comparing BED rates including the projected increase as
compared to the change in housing prices, core in lation, and health care costs. BED is continuing to
track below in lation since 2010. The next slide showed BED’s residential rate compared to New
England, And Vermont (as represented by GMP and Vermont Electric Coop). The next slide showed
BED’s commercial rates as being higher than the rest of Vermont but still well below the rest of New
England. BED’s total cost to serve is still lower than New England and the rest of Vermont. Ms.
Stebbins-Wheelock shared that for the average residential customer who uses 419 kilowatt hours a
month, a 4.5% across-the-board rate increase would increase their bill by $3.78 per month. A small
general service commercial customer would see an increase of $4.81 per month. Energy assistance
program customers would see an estimated bill impact of $3.74 a month on average.

Also in May, the Department anticipates proposing to the Commission a revision to the Energy
Assistance Program tariff that would allow nonpro it residential shelters to qualify for the rate as
well as certain nonpro it housing providers that have low-income tenants who would otherwise
qualify, if the housing provider pays the electric bill but promises to pass the savings to the tenants.
Commissioner Whitaker asked how many providers there are who would qualify for this proposed
change and Ms. Stebbins-Wheelock replied that BED is in the process of gathering this information
and will have it for the May meeting. Mr. Springer stated that the impetus for this that one of the
shelter providers was facing a fairly signi icant demand charge as a large general service customer.
This proposal is one of the ways BED could help without changing our rate structure.

Commissioner Bonn asked if BED attended the Better Buildings by Design event. General Manager
Springer responded that Director of Energy Services Chris Burns was in attendance and was able to
bring back some useful information. Commissioner Bonn stated that she could put BED in touch
with Dr. Hansen, a Columbia professor who has been studying energy burden and brand design to
provide more information and serve as a great resource.

General Manager noted that the inalized FY26 budget and rate proposal will be presented to the
Commission in May where it will be voted on and then presented to the Board of Finance. Due to
scheduling, the Department will be giving its initial presentation to the Board of Finance on May 7,
which is ahead of our next Commission meeting. The Electric Commission will vote irst, however, to
approve and recommend the budget as well as the rate case, after which both items will go to the
Board of Finance later that month and then to the City Council in June.

Net Zero Road Map Update
 11
Commissioners’ Check-In
No topics discussed.

Executive Session - McNeil Commercial Items
Commissioner Whitaker made the motion that premature general public knowledge regarding
McNeil commercial items would clearly place the Burlington Electric Department at a substantial
disadvantage per Title 1, Section 313 (a)(1) of the Vermont Statutes; Commissioner Vota seconded
motion. Commission vote; 4 ayes 0 nays.

Commissioner Whitaker made a motion to enter into Executive Session at 6:45pm to discuss the
McNeil commercial items under the provisions of Title 1, Section 313(a) (1)(A) of the Vermont
Statutes; Commissioner Bonn seconded the motion. Commission vote; 4 ayes 0 nays.
Commissioner Hobbs made a motion to exit Executive Session at 6:05pm; Commission Vota
seconded the motion. Commission vote; 4 ayes 0 nays

Commissioner Vota made a motion to exit Executive Session at 7:25pm; Commission Whitaker
seconded the motion. Commission vote; 4 ayes 0 nays

Executive Session - Personnel Matters
Commissioner Whitaker made the motion that premature general public knowledge regarding
personnel matters would clearly place the Burlington Electric Department at a substantial
disadvantage per Title 1, Section 313 (a)(1) of the Vermont Statutes; Commissioner Bonn seconded
motion. Commission vote; 4 ayes 0 nays.

Commissioner Whitaker made a motion to enter into Executive Session at 7:25pm to discuss
personnel matters under the provisions of Title 1, Section 313(a) (1)(A) of the Vermont Statutes;
Commissioner Bonn seconded the motion. Commission vote; 4 ayes 0 nays.

Commissioner Vota made a motion to exit Executive Session at 7:42pm; Commission Whitaker
seconded the motion. Commission vote; 4 ayes 0 nays

Adjourn
Commissioner Vota made a motion to adjourn; the motion was seconded by Commissioner Hobbs,
Commission vote; 4 ayes 0 nays.

The meeting of the Burlington Electric Commission adjourned at 7:42p.m.

Microsoft Teams transcript used to create minutes drafted by Elena Alexander, Board Clerk, edited by
Emily Stebbins-Wheelock, CFO & Manager of Strategy and Innovation.
 12
Attest: _______________________________________________
Elena Alexander, Board Clerk




 13