HomeMy WebLinkAbout2025-03-25 - RPU Board - Agenda Packet
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Board President
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Secretary
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Rochester Public Utility Board Policy
POLICY 21:InvoluntaryDisconnection
POLICYOBJECTIVE:
The Board's objective is to ensure that residential customer accounts are protected during cold weather
periods, extreme heat conditions,and military service, as prescribed in Minnesota Statutes §§ 216B.097,
216B.0975, and 325E.028.
POLICYSTATEMENT:
1.Service Disconnections
RPU is committed to supporting customers in accordance with the Customer Relations Policy.
Management will exercise discretion to ensure the disconnect process is carriedout consistently
across all customer classes.
2.Cold Weather Rule
Minnesota Statutes, Section216B.097 states that RPU must reconnect the utility service of a
residential customer during the period between October 1 and April 30, if the disconnection affects
the primary heat source for the residential unit and all of the conditions described in the statute are
met. For the purposes of this policy, "disconnection" includes a service or load limiter or any device
that limits or interrupts electric service in any way. This protection does not prohibit RPU from
disconnecting service but requires several steps to be taken before disconnection.
A.Application: Notice to Residential Customer
RPU will not disconnect or will reconnect the utility service of a residential customer if the
disconnection affects the primary heat source for the residential unit and all ofthefollowing
conditionsare met:
1.The household income of the customer is at or below 50 percent of the state
median household income. RPU may verify incomeon forms it provides or obtain
verification of incomefrom the local energy assistance provider. A customer is
deemed to meet the income requirements of this clause if the customer receives
any form of public assistance, including energy assistance, that uses an income
eligibility threshold set at or below 50 percent of the state median household
income.
2.A customer enters into and makes reasonably timely payments under a payment
Reasonably
-upon due
dates.
3.A customer receives referrals to energy assistance, weatherization, conservation,
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Rochester Public Utility Board Policy
4.RPU willnotify all residential customers between August 15 and October 1 each
year of the provisions of this policy and Minnesota Statute Section 216B.097.
B.Notice to Residential Customer Facing Involuntary Disconnection
1.Before disconnecting service to a residentialcustomer during the period between
October 1 and April 30, RPU will provide the following information to a customer:
a)a notice of proposed disconnection;
b)
c)a list of local energy assistance providers;
d)a form on which to declare inability to pay; and
e)astatement explaining available time payment plans and other
opportunities to secure continued utility service.
2.At the same time that notice is given under paragraph one (1), RPU must also give
written or electronic notice of proposed disconnection(s) to the local energy
assistance provider and the Minnesota Department of Commerce.
C.Restrictions, if Involuntary Disconnection is Necessary
1.If a residential customer must be involuntarily disconnected between October 1
and April 30 for failure to comply with Section 2Aof this policy, the disconnection
will not occur:
a)on a Friday,
b)on a weekend, holiday, or the day before a holiday,
c)when RPU offices are closed, or
d) after the close of business.
e) when the forecast low temperature on the day of disconnect is projected
to be lower than 32 degrees Fahrenheit.
f) during the months of November, December, January or February.
2.Further, the disconnection will not occur until at least 30 days after the notice
required in section 2B of this policy,has been mailed to the customer, or 15 days
after the notice has been personally delivered to the customer.
3.The customer will not be disconnected until RPU attempts to confirm whether the
residential unit is occupied, which RPU may accomplish by:
a)visiting the residential unit;
b)examining energy usage data obtained through AMIto determine whether
there is energy usage over at least a 24-hour period that indicates
occupancy.
4.RPU will not disconnect a residential customer who is in compliance with
Minnesota Statute Section 216B.098, Subd. 5inregards to medically necessary
equipment. P
5.If prior to disconnection, a customer appeals a notice of involuntary disconnection,
disconnect until the appeal is resolved.
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Rochester Public Utility Board Policy
3.Disconnection During Extreme Heat Conditions
Minnesota Statute,Section 216B.0975 states that RPU may not disconnect a residential service
when an excessive heat watch, heat advisory, or excessive heat warning has been issued by the
National Weather Service.
4. Permissible Service Disconnection with Notice
Per guidance from Minnesota Administrative Rule 7820.1000, RPU will perform disconnections of
service with notice to any customer for any reason stated below:
a.for failure of the customer to pay a bill for utility service;
b.for failure of the customer to meet the utility'sdeposit and credit requirements;
c.
d.for failure of the customer to provide the utility reasonable access to its equipment and
property;
e.or for other situations listed in Minnesota statutes and rules.
5.Permissible Service Disconnection without Notice
Per guidance from Minnesota Administrative Rule 7820.1100, RPU will perform disconnections for
service without notice to any customer for any reason stated below:
a.in the event of an unauthorized use of or tampering with the utility's equipment;
b.in the event of a condition determined to be hazardous to the customer, to other customers
,or to the public.
6.Appeals Process
A residential customer has the right to dispute or appeal in the event RPU and the residential
customer are unable to agree on the establishment, reasonableness, or modification of a payment
illing, Credit and Collections
Policy. RPU will not disconnect service while a payment schedule is pending appeal.
Minnesota Statute, Section 216B.097
RELEVANT LEGAL AUTHORITY:
Minnesota Statute, Section 216B.0975
Minnesota Statute, Section 216B.098, Subd. 5
Minnesota Statute, Section 325E.028
Minnesota Administrative Rule 7820.1000
Minnesota Administrative Rule 7820.1100
September 10, 1991
EFFECTIVE DATE OF POLICY:
March 25, 2025
DATE OF POLICY REVIEW:
POLICY APPROVAL:
Board PresidentDate
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R E S O L U T I O N
BE IT RESOLVED by the Public Utility Board of the City of Rochester to approve the
revised Involuntary Disconnection policy.
PASSED AND ADOPTED BY THE PUBLIC UTILITY BOARD OF THE CITY OF
ROCHESTER, MINNESOTA, THIS 25th DAY OF MARCH 2025.
___________________________________
PRESIDENT
___________________________________
SECRETARY
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R E S O L U T I O N
BE IT RESOLVED by the Public Utility Board of the City of Rochester to approve the
2024 RPU Distributed Energy Resource Report.
PASSED AND ADOPTED BY THE PUBLIC UTILITY BOARD OF THE CITY OF
ROCHESTER, MINNESOTA, THIS 25th DAY OF March 2025.
___________________________________
PRESIDENT
___________________________________
SECRETARY
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SCHEDULE 1RULES GOVERNING COGENERATION AND SMALL POWER PRODUCTION
SHEET 1 OF 1
SCHEDULE 1RULES GOVERNING COGENERATION AND SMALL POWER PRODUCTION
20242023
(rates used in 2025)(rates used in 2024)
RESIDENTIAL
Total revenues$ 66,161,624.04$63,527,467.42
Less fixed revenues (customer charge) $14,783,294.10$13,274,087.42
Net revenues $51,378,329.94$50,253,380.00
kWh369,450,757376,655,543
Average retail energy rate$0.13907$0.13342
4.23%
COMMERCIAL
SGS
Total revenues$ 11,885,985.77$ 11,611,777.24
Less fixed revenues (customer charge)$1,677,955.13$1,843,096.12
Net revenues$10,208,030.64$9,768,681.12
kWh 71,582,853 73,864,861
Average retail energy rate$0.14260$0.13225 7.83%
MGS
Total revenues$ 54,485,901.70$ 52,007,530.01
Less fixed revenues (customer charge) $ 23,606,251.13 $ 22,798,142.43
Net revenues$30,879,650.57$29,209,387.58
kWh 401,948,724 404,695,568
Average retail energy rate$0.07682$0.07218 6.44%
LGS
Total revenues$ 21,807,787.36$ 20,722,536.09
Less fixed revenues (customer charge) $ 7,537,139.76 $ 7,423,841.15
Net revenues$14,270,647.60$13,298,694.94
kWh187,220,478185,878,673
Average retail energy rate$0.07622$0.07155 6.54%
INDUSTRIAL
Total revenues$ 11,687,191.40$ 11,044,299.29
Less fixed revenues (customer charge) $ 5,090,975.65 $ 4,601,635.01
Net revenues$ 6,596,215.75$6,442,934.28
kWh90,802,09793,382,661
Average retail energy rate$0.07264$0.06899
5.29%
Approved by Rochester Public Utility Board:March 25, 2025
Effective Date:April1, 2025
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SCHEDULE 2 AVERAGE INCREMENTAL COST
9ƭƷźƒğƷĻķ ağƩŭźƓğƌ 9ƓĻƩŭǤ /ƚƭƷƭ ΛυΉaŷΜ
2025 2026 2027 2028 2029
hƓ tĻğƉ ЍЋ͵ЋЉ ЍЌ͵ВА ЍА͵ЋВ ЍБ͵ЎБ ЎЉ͵ЊБ
{ǒƒƒĻƩ Off Peak 25.13 26.83 26.25 28.57 29.86
All Hours 32.98 34.71 35.93 37.78 39.21
hƓ tĻğƉ 38.73 44.69 47.81 47.81 48.44
Winter Off Peak 28.94 33.73 37.73 39.35 41.85
All Hours 33.44 38.77 42.37 43.53 45.97
hƓ tĻğƉ 40.46 44.33 47.55 48.51 50.49
Annual Off Peak 27.04 30.28 31.99 33.96 35.85
All Hours 33.21 36.74 39.15 40.65 42.59
Annual # hours on-peak:
5ĻƭĭƩźƦƷźƚƓ ƚŅ ƭĻğƭƚƓ ğƓķ ƚƓΏƦĻğƉ ğƓķ ƚŅŅΏƦĻğƉ ƦĻƩźƚķƭ
April through September
Summer:
October through March
Winter:
On-peak period: 6 am to 10 pm Monday through Friday except holiday (New Years, Memorial Day, Fourth of July, Labor Day,
Thanksgiving Day, Christmas Day)
Off-peak period: All other hours
Estimated Marginal Energy Costs
The estimated system average incremental energy costs are calculated by seasonal peak and off-peak
periods for each of the next five years. For each seasonal period, system incremental energy costs are
averaged during system daily peak hours, system daily off-peak hours, and all hours in the season. The
energy costs are increased by a factor equal to 50 percent of the line losses.
The energy needs of Rochester Public Utilities are served through its membership in Southern Minnesota
Municipal Power Agency (SMMPA). SMMPA, in turn, is a member of the Midcontinent ISO (MISO).
Marginal Price (LMP). Actual hourly LMP will vary significantly based on several parameters such as
weather, energy demand, and generation availability. The table above represents a forecast of the MISO
hourly LMP values averaged over each specific time period at the MISO Minnesota Hub.
Capacity Payment for Firm Power (Net annual avoided capacity cost)
A capacity payment will be made for energy delivered by the qualifying facility to the utility with at least
a 65 percent on-peak capacity factor in the month. The capacity factor is based upon the qualifying
facility's maximum on-peak metered capacity delivered to the utility during the month. The capacity
component applies only to deliveries during on-peak hours.
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SCHEDULE 3
Rules Governing the Interconnection of Cogeneration and Small Power Production
Facilities with Rochester Public Utilities, List of documents
The following documents are publically available and document Rochester Public
Utilities electric interconnection process for Distributed Energy Resources. This is not a
list of all documents related and required for interconnection but the major ones.
1) Minnesota Municipal Interconnection Process (M-MIP) Booklet #1 Process
Overview
2) Minnesota Municipal Interconnection Process (M-MIP) Booklet #2 Simplified
Process
3) Minnesota Municipal Interconnection Process (M-MIP) Booklet #3 Fast Track
Process
4) Minnesota Municipal Interconnection Process (M-MIP) Booklet #4 Study
Process
5) Pre-Application Report
6) Interconnection Application
7) Minnesota Municipal Interconnection Process (M-MIP) - System Impact Study
Agreement
8) Minnesota Municipal Interconnection Process (M-MIP) Facilities Study
Agreement
9) Minnesota Municipal Interconnection Process (M-MIP) Transmission System
Impact Study Agreement
10) Minnesota Municipal Interconnection Process - Minnesota Municipal
Interconnection Agreement
11) Schedule 1, 2, and 3
12) Rochester Public Utilities - Rules Governing the Interconnection of
Cogeneration and Small Power Production Facilities with Rochester Public
Utilities
13) Rochester Public Utilities - Technical Specification Manual (TSM)
14) State of Minnesota - Technical Interconnection & Interoperability Requirements
(TIRR)
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R E S O L U T I O N
BE IT RESOLVED by the Public Utility Board of the City of Rochester to approve the
Distributed Energy Resource Tariff Schedules.
PASSED AND ADOPTED BY THE PUBLIC UTILITY BOARD OF THE CITY OF
ROCHESTER, MINNESOTA, THIS 25th DAY OF March 2025.
___________________________________
PRESIDENT
___________________________________
SECRETARY
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R E S O L U T I O N
BE IT RESOLVED by the Public Utility Board of the City of Rochester to approve the
designation of all per- and polyfluoroalkyls (PFAS) funds received by the Water Utility
through settlement or judgment award to a Special Capital Reserve.
BE IT FURTHER RESOLVED by the Public Utility Board of the City of Rochester that
these funds may be used for the purpose of monitoring or mitigating PFAS elements.
PASSED AND ADOPTED BY THE PUBLIC UTILITY BOARD OF THE CITY OF
ROCHESTER, MINNESOTA, THIS 25th DAY OF March 2025.
___________________________________
PRESIDENT
___________________________________
SECRETARY
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RESOLUTION RELATING TO THE FINANCING OF ADVANCED METERING INFRUSTRUCTURE
PROJECTS; ESTABLISHING COMPLIANCE WITH REIMBURSEMENT BOND REGULATIONS
UNDER THE INTERNAL REVENUE CODE
BE IT RESOLVED by the Utility Board of the City of Rochester, that the Common Council of
the said City is requested to approve, as follows:
1. Recitals.
(a) The Internal Revenue Service has issued Section 1.150-2 of the Income Tax Regulations
(the "Regulations") dealing with the issuance of bonds, all or a portion of the proceeds of
which are to be used to reimburse the Utility for project expenditures made by the Utility
prior to the date of issuance.
(b) The Regulations generally require that the Utility make a declaration of its official intent
to reimburse itself for such prior expenditures out of the proceeds of a subsequently issued
series of bonds within 60 days after payment of the expenditures, that the bonds be issued
and the reimbursement allocation be made from the proceeds of such bonds within the
reimbursement period (as defined in the Regulations), and that the expenditures
reimbursed be capital expenditures or costs of issuance of the bonds.
(c) The Utility desires to comply with requirements of the Regulations with respect to certain
projects hereinafter identified.
2. Official Intent Declaration.
(a)The Utility proposes to research, design, construct and or acquire, commission and equip
the replacement of water meters with advance water metering infrastructure, and to make
original expenditures with respect thereto prior to the issuance of reimbursement bonds,
and reasonably expects to issue reimbursement bonds, in one or more series, at one time
or from time to time, for the project up to the amount of $6,000,000 plus issuance costs.
Other than (i) de minimis amounts permitted to be reimbursed pursuant to Section 1.150-
2(f)(1) of the Regulations or (ii) expenditures constituting preliminary expenditures as
defined in Section 1.150-2(f)(2) of the Regulations, the Utility will not seek reimbursement
for any original expenditures with respect to the foregoing projects paid more than 60 days
prior to the date of adoption of this resolution. All original expenditures for which
reimbursement is sought will be capital expenditures or costs of issuance of the
reimbursement bonds.
3. Budgetary Matters. As of the date hereof, there are no Utility funds reserved, pledged,
allocated on a long term basis or otherwise set aside (or reasonably expected to be
reserved, pledged, allocated on a long term basis or otherwise set aside) to provide
permanent financing for the original expenditures related to the projects, other than
pursuant to the issuance of the reimbursement bonds. Consequently, it is not expected that
the issuance of the reimbursement bonds will result in the creation of any replacement
proceeds.
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4. Reimbursement Allocations. The Utilities financial officer shall be responsible for making
the "reimbursement allocations" described in the Regulations, being generally the transfer
of the appropriate amount of proceeds of the reimbursement bonds to reimburse the source
of temporary financing used by the Utility to make payment of the original expenditures
relating to the projects. Each reimbursement allocation shall be made within 30 days of the
date of issuance of the reimbursement bonds, shall be evidenced by an entry on the official
books and records of the Utility maintained for the reimbursement bonds and shall
specifically identify the original expenditures being reimbursed.
Adopted this 25th day of March, 2025.
_______________________________ _______________________________
City of Rochester - Director of Finance RPU - Board President
_______________________________ _______________________________
Date Date
_______________________________
RPU - Board Secretary
_______________________________
Date
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RESOLUTION RELATING TO THE FINANCING OF POWER SUPPLY RESOURCE PLAN
GENERATION, SUBSTATION, DISTRIBUTION AND TRANSMISSION PROJECTS;
ESTABLISHING COMPLIANCE WITH REIMBURSEMENT BOND REGULATIONS UNDER THE
INTERNAL REVENUE CODE
BE IT RESOLVED by the Utility Board of the City of Rochester, that the Common Council of
the said City is requested to approve, as follows:
1. Recitals.
(a) The Internal Revenue Service has issued Section 1.150-2 of the Income Tax Regulations
(the "Regulations") dealing with the issuance of bonds, all or a portion of the proceeds of
which are to be used to reimburse the Utility for project expenditures made by the Utility
prior to the date of issuance.
(b) The Regulations generally require that the Utility make a declaration of its official intent
to reimburse itself for such prior expenditures out of the proceeds of a subsequently issued
series of bonds within 60 days after payment of the expenditures, that the bonds be issued
and the reimbursement allocation be made from the proceeds of such bonds within the
reimbursement period (as defined in the Regulations), and that the expenditures
reimbursed be capital expenditures or costs of issuance of the bonds.
(c) The Utility desires to comply with requirements of the Regulations with respect to certain
projects hereinafter identified.
2. Official Intent Declaration.
(a)The Utility proposes to research, design, construct and or acquire, commission and equip
wind, solar, and firm dispatchable power generation facilities, battery storage, substations,
distribution and transmission projects, including without limitation the Mount Simon Energy
Station project, and to make original expenditures with respect thereto prior to the issuance
of reimbursement bonds, and reasonably expects to issue reimbursement bonds, in one or
more series, at one time or from time to time, for the project up to the amount of
$457,800,000 plus issuance costs.
Other than (i) de minimis amounts permitted to be reimbursed pursuant to Section 1.150-
2(f)(1) of the Regulations or (ii) expenditures constituting preliminary expenditures as
defined in Section 1.150-2(f)(2) of the Regulations, the Utility will not seek reimbursement
for any original expenditures with respect to the foregoing projects paid more than 60 days
prior to the date of adoption of this resolution. All original expenditures for which
reimbursement is sought will be capital expenditures or costs of issuance of the
reimbursement bonds.
3. Budgetary Matters. As of the date hereof, there are no Utility funds reserved, pledged,
allocated on a long term basis or otherwise set aside (or reasonably expected to be
reserved, pledged, allocated on a long term basis or otherwise set aside) to provide
permanent financing for the original expenditures related to the projects, other than
pursuant to the issuance of the reimbursement bonds. Consequently, it is not expected that
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the issuance of the reimbursement bonds will result in the creation of any replacement
proceeds.
4. Reimbursement Allocations. The Utilities financial officer shall be responsible for making
the "reimbursement allocations" described in the Regulations, being generally the transfer
of the appropriate amount of proceeds of the reimbursement bonds to reimburse the source
of temporary financing used by the Utility to make payment of the original expenditures
relating to the projects. Each reimbursement allocation shall be made within 30 days of the
date of issuance of the reimbursement bonds, shall be evidenced by an entry on the official
books and records of the Utility maintained for the reimbursement bonds and shall
specifically identify the original expenditures being reimbursed.
Adopted this 25th day of March, 2025.
_______________________________
_______________________________
RPU - Board President
City of Rochester - Director of Finance
_______________________________
Date
_______________________________
_______________________________
Date
RPU - Board Secretary
_______________________________
Date
4:
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R E S O L U T I O N
BE IT RESOLVED by the Public Utility Board of the City of Rochester to approve a
resolution authorizing management to enter into a Memorandum of Understanding
(MOU) defining cost reimbursements and project responsibilities with the Mayo Clinic to
support the Bold Forward Unbound initiative, subject to final review and approval of the
General Manager and City Attorney.
PASSED AND ADOPTED BY THE PUBLIC UTILITY BOARD OF THE CITY OF
ROCHESTER, MINNESOTA, THIS 25th DAY OF March 2025.
___________________________________
PRESIDENT
___________________________________
SECRETARY
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- ¸® #«¨¨¢ "®«£ &®±¶ ±£ Unbound -/5 ¶¨³§ 205 (Electric)
Background
In early 2023, Mayo Clinic (Mayo) staff began to inform Rochester Public Utilities (RPU) of a
substantial project initiative that they were considering in the vicinity of their Damon Parking
Ramp. Mayo began discussing with RPU potential electrical re-configurations that would allow
them to eliminate their existing Bus 6 at Damon Ramp and the possibility of RPU temporarily
reconfiguring parts of their system to provide support to Mayo St. Marys and Franklin that are
currently tied to Bus 6 within the Damon Ramp.
Mayo staff and a variety of engineering consultants began to meet with RPU staff on a
routine basis in July of 2023 to explore alternatives that would allow Mayo to eliminate Bus 6
with the demolition of the Damon Ramp. Mayo also began discussing the implicati
existing underground manhole and duct systems currently located in either side of the Damon
rdth
Ramp in 3 and 4 Avenues. The location of these existing facilities are in conflict with future
construction that Mayo intends to do in and around the Damon Ramp area. Mayo communicated
rdth
their desire to have the RPU facilities on 3 and 4 Av on each side of Damon Ramp to either be
relocated or removed. Mayo and RPU began to discuss re-routing options and locations of new
initiatives. At the time of this MOU, Mayo intends to relocate an existing RPU duct system in an
area which they anticipate to be vacated, from a section of 4th Av to a new location within that
th
same section of 4 Av. Mayo also plans to replace a section of RPU duct system within an
rd
anticipated vacated section of 3 Av area, with a new duct system located primarily within this
th
same 4 Av area. Mayo intends to install a significant new duct route between the Prospect
Utility Plant and their new switchgear on Lot 26, which will be a replacement for their original
Bus 6. As part of the duct route between Prospect Utility Plant and the Lot 26 switchgear, Mayo
will be installing a separate duct bank for most of this route to allow RPU to supply electrical
energy directly to the Lot 26 switchgear from RPUs Crosstown Substation.
4¤±¬² ®¥ !¦±¤¤¬¤³
Electrical re-configuration of RPU facilities dedicated for service to Mayo will be necessary for
Mayo to eliminate their existing Bus 6 electrical connection point in the Damon Ramp and build
their new medical facilities. The current proposed new duct routes are reflected in Appendix A.
Mayo also might request RPU to relocate other RPU facilities that are not dedicated to serve
Mayo only load. The below terms cover both of these scenarios.
o The relocation routes and designs shall be approved jointly by RPU and Mayo.
o 100% of the costs to perform this work will be borne by Mayo, whether RPU
performs the work or Mayo performs the work. These costs include design,
materials, labor, equipment, and overheads.
o If Mayo performs the construction, Mayo agrees to fund any inspection services
that RPU deems necessary.
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o If RPU performs the work, then all costs shall include the fully loaded labor and
material costs of RPU and their contractors and consultants.
o There will be situations where it will be in the best interests of both Mayo and RPU
for Mayo to self-perform some of the design work and construction work. These
situations will be jointly agreed to by both Mayo and RPU.
o All newly constructed RPU facilities dedicated for serving Mayo facilities will be
retained under RPU ownership and operational control and will be treated as
contributed assets by RPU.
o Due to the accelerated timeline of this project RPU may have to order material and
equipment prior to completion of scoping and design. RPU will order necessary
materials based upon POs from Mayo or other equivalent commitments by Mayo.
In the case that special material is ordered and not used, the cost of the special
material will be borne by Mayo.
o The point of ownership transfer of the RPU feeder cables will be at the cable
terminations within the Mayo switchgear.
o A future O&M agreement will be developed between RPU and Mayo to address any
future O&M responsibilities of these newly installed facilities.
o The costs to install electrical or communication facilities into the newly
constructed ducts, as required by Mayo, will be addressed by PO or other
agreements in the future.
Ώ If RPU wishes to coordinate with Mayo-funded electrical relocation projects and install
RPU facilities in addition to those required for relocations, the mutually agreed to
incremental costs of the additional RPU facilities will be borne by RPU.
Ώ This agreement will also cover all present and future projects asso
multi-year Bold Forward plan that were not envisioned at the time of the signing of this
agreement.
Ώ This agreement will terminate at the end of the
Unbound project at a date to be determined in the future that Mayo and RPU mutually
agree to. If a date is not agreed to, this agreement will terminate on 12/31/2032.
Ώ Appendix A reflects the areas and details of duct routes that were known at the time of
the signing of this agreement that Mayo will pay for and install. These duct and manhole
assets will become an RPU contributed asset ownership and
control.
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!¯¯¤£¨· !
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CITY OF ROCHESTER MAYO CLINIC, a Minnesota
nonprofit corporation
By:_____________________________________ By:___________________________________
Kim Norton, Mayor
Date:____________________________
Attest:_________________________________
Kelly Geistler, City Clerk
Approved
As to Form:_________________________________
Michael Spindler-Krage, City Attorney
ROCHESTER PUBLIC UTILITIES
By:_____________________________________
Tim McCollough, General Manager
Date:________________________
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DIVISION REPORTS AND METRICS
MARCH2025
MARCH2025
DIVISION REPORTS
AND METRICS
SAFETY
WATERDIVISION
POWER DELIVERY
POWER RESOURCES
CUSTOMER RELATIONS
CORPORATE SERVICES
INFORMATION TECHNOLOGY
247
DIVISION REPORTS AND METRICS MARCH 2025
248
DIVISION REPORTS AND METRICS MARCH 2025
249
DIVISION REPORTS AND METRICS MARCH 2025
1. Water Outage Calculations for the month and year to date(February 2025 Data)
99.99722119
Performed 175 Gopher State water utility locates during the month for a total of 451 for the
year.
There are currently 150 Water ERTs that were unable to be read in the system. We are
experiencing approximately 18-19 new non-reads per week. The stockroom has the
following products available:
Repaired water distribution system failures or maintenance at the following locations during
the month:
24:
DIVISION REPORTS AND METRICS MARCH2025
Actual vs. Projected Pumpage: 2025
Core Services -Water Maintenance & Construction
700,000,000
650,000,000
600,000,000
550,000,000
500,000,000
450,000,000
400,000,000
350,000,000
300,000,000
250,000,000
200,000,000
150,000,000
100,000,000
50,000,000
-
JanFebMarAprMayJunJulAugSepOctNovDec
Month
Actual PumpageProjected Pumpage
Actual vs. Projected Power Cost for Wells: 2025
Core Services -Water Maintenance & Construction
$170,000
$160,000
$150,000
$140,000
$130,000
$120,000
$110,000
$100,000
$90,000
$80,000
$70,000
$60,000
$50,000
$40,000
$30,000
$20,000
$10,000
$0
JanFebMarAprMayJunJulAugSepOctNovDec
Month
Actual PowerProjected Power
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DIVISION REPORTS AND METRICS MARCH2025
2025 Valve Operations Program
Core Services -Water Maintenance & Construction
6,000
5,500
5,000
4,500
4,000
2025 Goal = 3,500
3,500
3,000
2,500
2,000
1,500
1,000
500
0
JanFebMarAprMayJunJulAugSepOctNovDec
Month
2025202220232024Goal
2025 Hydrant Operations Program
Core Services -Water Maintenance & Construction
5,500
5,000
4,500
4,000
2025 Goal = 3,650
3,500
3,000
2,500
2,000
1,500
1,000
500
0
JanFebMarAprMayJunJulAugSepOctNovDec
Month
2025202220232024Goal
252
DIVISION REPORTS AND METRICS MARCH 2025
1. Electric Outage Calculations for the month and year to date (February 2025 Data)
2. Electric Utility Operations T&D, Engineering, System Ops, GIS, Tech Services:
Number of Outages
by Select Cause Code
60
50
48
40
30
22
20
18
11
9
10
2
0
Squirrel OutagesVegetation Outages
253
DIVISION REPORTS AND METRICS MARCH 2025
254
DIVISION REPORTS AND METRICS MARCH2025
2025 RPU Renewables Production
1,600
1,400
Annual
1,200
Production to
date:
1,000
2835 MWh
800
Enough energy
to power:
600
315 homes
400
200
0
HydroValleyhigh SolarWES SolarService Center SolarOWEF (RPU Purchase)
255
DIVISION REPORTS AND METRICS MARCH 2025
256
DIVISION REPORTS AND METRICS MARCH 2025
1. Marketing & Energy Services attended Rochester's Electrify Everything MN class titled
Electrification and Energy Rating for Housing Developers on Tuesday, March 4. The session
provided Rochester area housing developers, builders, and architects insights into energy
ratings, opportunities for incorporating electrification and energy efficiency into new home
construction, and the available certifications and incentives.
2. Marketing & Energy Services attended the Drive Electric MN Steering Committee meeting on
March 6, where discussions focused on the 2025 membership campaign, steering committee
recruitment, and the annual membership meeting.
1. The Benchmarking, MyMeter, software implementation went live February 28, in conjunction
with the MN Department of Energy launching their informational website and outreach to the
impacted commercial customers.
2. RPU once again collected holiday lights from customers for recycling this year. The event ran
from November 1 through January 31. This year, RPU recycled 3,876 pounds of holiday lights,
bringing the total to 36,960 pounds recycled since 2011.
3. Customer Care and Collections continue to make outreach calls to customers with past due
balances on their accounts. The intent is to be proactive and connect these customers with
outside resources for financial assistance. In February, a total of 1,220 customers were
contacted.
4. Marketing & Energy Services will host a Neighborhood Energy Challenge (NEC) workshop on
Saturday, March 15. To date, 16 households have registered. The NEC is a collaborative
initiative between RPU, Minnesota Energy Resources, and the Center for Energy and
Environment, designed to offer a comprehensive energy audit program to residential customers.
1. The Communications Coordinator collaborated with local media outlets ahead of the early
March snowstorm to inform the public about RPU's storm response plans, actions to take in the
2. The Communications Coordinator participated in a city-wide Code Red training led by the
Emergency Management Director, which covered Code Red procedures and expectations
during an emergency.
257
DIVISION REPORTS AND METRICS MARCH 2025
258
259
25:
261
03/12/25
1 ROCHESTER PUBLIC UTILITIES
2 STATEMENT OF CASH FLOWS
3 ELECTRIC UTILITY
4 FOR
5 JANUARY, 2025
6 YEAR-TO-DATE
PRELIMINARYPRELIMINARYPRELIMINARY
7 Actual YTDLast Yr Actual YTD
8 CASH FLOWS FROM OPERATING ACTIVITIES
9 Cash Received From Customers 13,028,772 13,248,789
10 Cash Received From Wholesale & Steam Customer 841,115 617,440
11 Cash Paid for:
12 Purchased Power (8,284,561) (8,424,890)
13 Operations and Maintenance (3,186,115) (3,717,610)
14 Fuel (411,903) (93,011)
15 Payment in Lieu of Taxes (911,891) (782,447)
16 Net Cash Provided by(Used in) Utility
17 Operating Activities 1,075,417 848,271
18 Sewer, Storm Water, Sales Tax & MN Water Fee Collections
19 Receipts from Customers 4,156,182 3,927,836
20 Remittances to Government Agencies (3,811,807) (3,654,444)
21 Net Cash Provided by(Used in) Non-Utility
22 Operating Activities 344,375 273,392
23NET CASH PROVIDED BY(USED IN)
24OPERATING ACTIVITIES 1,419,792 1,121,663
25 CASH FLOWS FROM CAPITAL & RELATED
26 FINANCING ACTIVITIES
27 Additions to Utility Plant & Other Assets (2,231,383) (1,859,750)
28 Payments related to Service Territory Acquisition (20,098) (15,834)
29 Payment on Long-Term Debt - -
30 Net Bond/Loan Receipts - -
31 Cash Paid for Interest & Commissions - (696)
32 NET CASH PROVIDED BY(USED IN)
33CAPITAL & RELATED ACTIVITIES (2,251,481) (1,876,280)
34 CASH FLOWS FROM INVESTING ACTIVITIES
35 Interest Earnings on Investments (622,974) (345,855)
36 Construction Fund (Deposits)Draws - -
37 Bond Reserve Account (1,140,645) (1,142,697)
38Escrow/Trust Account Activity - -
39 NET CASH PROVIDED BY(USED IN)
40INVESTING ACTIVITIES (1,763,619) (1,488,552)
41Net Increase(Decrease) in Cash & Investments (2,595,308) (2,243,169)
42Cash & Investments, Beginning of Period 130,383,324 117,149,059
43CASH & INVESTMENTS, END OF PERIOD 127,788,016 114,905,890
44Externally Restricted Funds 14,747,772 14,868,185
45Grand Total 142,535,788 129,774,075
262
263
264
265
266
267
268
269
26:
271
03/12/25
1 ROCHESTER PUBLIC UTILITIES
2 STATEMENT OF CASH FLOWS
3 WATER UTILITY
4 FOR
5 JANUARY, 2025
6 YEAR-TO-DATE
PRELIMINARYPRELIMINARYPRELIMINARY
7 Actual YTDLast Yr Actual YTD
8 CASH FLOWS FROM OPERATING ACTIVITIES
9 Cash Received From Customers 2,353,146 2,290,017
10 Cash Paid for:
11 Operations and Maintenance (1,669,285) (277,365)
12 Payment in Lieu of Taxes (32,934) (30,181)
13 Net Cash Provided by(Used in) Utility
14 Operating Activities 650,927 1,982,471
15 Sales Tax & MN Water Fee Collections
16 Receipts from Customers 50,916 50,233
17 Remittances to Government Agencies (17,390) (15,464)
18 Net Cash Provided by(Used in) Non-Utility
19 Operating Activities 33,526 34,769
20NET CASH PROVIDED BY(USED IN)
21OPERATING ACTIVITIES 684,453 2,017,240
22 CASH FLOWS FROM CAPITAL & RELATED
23 FINANCING ACTIVITIES
24 Additions to Utility Plant & Other Assets (282,798) (1,369,939)
25 Payment on Long-Term Debt - -
26 Net Loan Receipts - -
27 Cash Paid for Interest & Commissions - -
28 NET CASH PROVIDED BY(USED IN)
29 CAPITAL & RELATED ACTIVITIES (282,798) (1,369,939)
30 CASH FLOWS FROM INVESTING ACTIVITIES
31 Interest Earnings on Investments 77,882 67,033
32 NET CASH PROVIDED BY(USED IN)
33 INVESTING ACTIVITIES 77,882 67,033
34Net Increase(Decrease) in Cash & Investments 479,537 714,334
35Cash & Investments, Beginning of Period 15,518,760 14,773,753
36CASH & INVESTMENTS, END OF PERIOD 15,998,297 15,488,087
272
273
274
275
276
277
278
279
27:
03/14/25
1 ROCHESTER PUBLIC UTILITIES
2 STATEMENT OF CASH FLOWS
3 ELECTRIC UTILITY
4 FOR
5 FEBRUARY, 2025
PRELIMINARYPRELIMINARYPRELIMINARY
6 YEAR-TO-DATE
7 Actual YTDLast Yr Actual YTD
8 CASH FLOWS FROM OPERATING ACTIVITIES
9 Cash Received From Customers 27,301,177 28,601,299
10 Cash Received From Wholesale & Steam Customer 1,542,655 1,287,010
11 Cash Paid for:
12 Purchased Power (16,260,818) (16,232,951)
13 Operations and Maintenance (5,886,328) (7,450,727)
14 Fuel (760,789) (638,707)
15 Payment in Lieu of Taxes (1,881,234) (1,622,651)
16 Net Cash Provided by(Used in) Utility
17 Operating Activities 4,054,663 3,943,273
18 Sewer, Storm Water, Sales Tax & MN Water Fee Collections
19 Receipts from Customers 8,235,384 7,831,829
20 Remittances to Government Agencies (7,968,807) (7,585,382)
21 Net Cash Provided by(Used in) Non-Utility
22 Operating Activities 266,577 246,447
23NET CASH PROVIDED BY(USED IN)
24OPERATING ACTIVITIES 4,321,240 4,189,720
25 CASH FLOWS FROM CAPITAL & RELATED
26 FINANCING ACTIVITIES
27 Additions to Utility Plant & Other Assets (4,094,928) (2,918,244)
28 Payments related to Service Territory Acquisition (36,451) (31,017)
29 Payment on Long-Term Debt - -
30 Net Bond/Loan Receipts - -
31 Cash Paid for Interest & Commissions - (1,392)
32 NET CASH PROVIDED BY(USED IN)
33CAPITAL & RELATED ACTIVITIES (4,131,379) (2,950,653)
34 CASH FLOWS FROM INVESTING ACTIVITIES
35 Interest Earnings on Investments (522,473) (253,527)
36 Construction Fund (Deposits)Draws - -
37 Bond Reserve Account (2,281,283) (2,285,323)
38Escrow/Trust Account Activity - -
39 NET CASH PROVIDED BY(USED IN)
40INVESTING ACTIVITIES (2,803,756) (2,538,850)
41Net Increase(Decrease) in Cash & Investments (2,613,895) (1,299,783)
42Cash & Investments, Beginning of Period 130,383,324 117,149,059
43CASH & INVESTMENTS, END OF PERIOD 127,769,429 115,849,276
44Externally Restricted Funds 15,888,409 16,010,811
45Grand Total 143,657,838 131,860,087
281
282
283
284
285
286
287
288
289
28:
03/14/25
1 ROCHESTER PUBLIC UTILITIES
2 STATEMENT OF CASH FLOWS
3 WATER UTILITY
4 FOR
5 FEBRUARY, 2025
PRELIMINARYPRELIMINARYPRELIMINARY
6 YEAR-TO-DATE
7 Actual YTDLast Yr Actual YTD
8 CASH FLOWS FROM OPERATING ACTIVITIES
9 Cash Received From Customers 3,467,806 3,339,600
10 Cash Paid for:
11 Operations and Maintenance (1,669,546) (1,194,426)
12 Payment in Lieu of Taxes (67,948) (63,312)
13 Net Cash Provided by(Used in) Utility
14 Operating Activities 1,730,312 2,081,862
15 Sales Tax & MN Water Fee Collections
16 Receipts from Customers 102,254 100,223
17 Remittances to Government Agencies (34,686) (32,319)
18 Net Cash Provided by(Used in) Non-Utility
19 Operating Activities 67,568 67,904
20NET CASH PROVIDED BY(USED IN)
21OPERATING ACTIVITIES 1,797,880 2,149,766
22 CASH FLOWS FROM CAPITAL & RELATED
23 FINANCING ACTIVITIES
24 Additions to Utility Plant & Other Assets (1,339,324) (1,524,833)
25 Payment on Long-Term Debt - -
26 Net Loan Receipts - -
27 Cash Paid for Interest & Commissions - -
28 NET CASH PROVIDED BY(USED IN)
29 CAPITAL & RELATED ACTIVITIES (1,339,324) (1,524,833)
30 CASH FLOWS FROM INVESTING ACTIVITIES
31 Interest Earnings on Investments 153,675 132,955
32 NET CASH PROVIDED BY(USED IN)
33 INVESTING ACTIVITIES 153,675 132,955
34Net Increase(Decrease) in Cash & Investments 612,231 757,888
35Cash & Investments, Beginning of Period 15,518,760 14,773,753
36CASH & INVESTMENTS, END OF PERIOD 16,130,991 15,531,641
291
292
293
294
295
296
TO: Bill Bullock, Director of Power Resources
FROM: Tina Livingston, Senior Financial Analyst
SUBJECT: LOAD FORECAST SUMMARY FOR 2025
SYSTEM ENERGYPEAK SYSTEM DATA
MONTHACTUALFORECAST% DIFFACTUALFORECAST% DIFF
MWHMWHMWMW
JAN102,113104,514-2.3%174.2177.1-1.7%
FEB90,75791,061-0.3%170.6160.26.5%
MAR150.1
APR146.8
MAY205.9
JUN257.7
JUL284.2
AUG253.4
SEP252.6
OCT165.0
NOV146.6
DEC169.4
YTD192,871195,575-1.4
HISTORICAL SYSTEM PEAK 294.8 MW 08/23/2023
% DIFF = (ACTUAL / FORECAST X 100) - 100
MWH = MEGAWATT HOUR = 1000 KILOWATT HOURS
MW = MEGAWATT = 1000 KILOWATTS
297
2025 YTD System Requirements
Energy Required for the Month (MWH
130,000
120,000
110,000
100,000
90,000
80,000
70,000
60,000
JANFEBMARAPRMAYJUNJULAUGSEPOCTNOVDEC
2025 ACTUAL2025 FORECAST2024 ACTUAL
Peak Demand for the Month (MW)
350
300
250
200
150
100
50
0
JANFEBMARAPRMAYJUNJULAUGSEPOCTNOVDEC
2025 ACTUAL2025 FORECAST2024 ACTUAL
298